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Home My WebLink About190-087 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. t ~(~"' O~F 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 various kinds [] Other Complete COMMENTS: Scanned b~ TO RE-SCAN Notes: Bran Vincent Nathan Lowell Date:5~"--~)~,-,~ Is/ ~ Re-Scanned by: Beverly Bran Vincent Nathan Lowell Date: /si NOTScanned.wpd Re: MPK-34 (196-169) e e Subject: Re: MPK-34 (196-169) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 14 May 2007 11 :42:20 -0800 To: "MPU, Well Operations Supervisor" <welloperationssupervisor@BP.com> CC: Steve Davies <steve_davies@admin.state.~.us>, Dave Roby <dave_roby@admin.state.ak.us>, Jim Regg <jim _ regg@admin.state.ak.us> Mark, Thanks much. It seemed strange to read the workover report and sèe the pressure values and that they were bleeding gas. It makes sense since it is the Ugnu which does have heavy oil, gas and water in it. I'd appreciate if you would share the gas analysis when completed. Call or message with questions or further info. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 5/14/2007 11:35 AM: Tom, Our source well does develop a gas head on the annulus. I know when the well was new we actually had a permanent bleed line plumbed into the production header. Since the well has been in production over time the gas accumulation is allot slower. We no longer use this system. During this completion we did see some corrosion in the tubing and replaced most of the string. We plan to get gas samples once the well stabilizes.. ~ If you are interested in UGNU gas our wel~MPH-02/cs a producer in the ~ \~C>-CJ~~ UGNU that accumulates a gas head. This wel1-wl~~ be used as part of our HOTT heavy oil project. We have plans of sampling that gas as well. I will follow through and audit our daily read sheets in order to get you a build rate on K-34 IA. I'll also try to get a few fluid level shot to quantify the increase in the annulus. This may take some time due to the slower build up rate. Hopefully this is what you were looking for. John returns May 23rd. Thanks, Mark O'Malley ACT! , MPU Well Ops Supervisor Phone : 670-3330 Cell : 943-1047 E-Mail: omallemd@bp.com &;AHNED MAY 1 5 2007 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@aàmin.state.ak.us] Sent: Monday, May 14, 2007 10:00 AM To: MPU, Well Operations Supervisor Subject: MPK-34 (196-169) John, I was just reviewing the 404 report for the April workover on this well and it is mentioned of having to bleed down the IA from 1500 psi and that it was "...all gas...". I spoke with Dave Reem and he indicated that since this is an Ugnu water supply well that over time the annulus does develop a gas head. I was wondering if you could provide a little further information on this. I am curious about the development of the gas head, how much pressure develops, what the normal fluid level is and if it is necessary to bleed the IA. Does this only affect Ugnu water supply wells? Thanks in advance for the information. I look forward to your reply. Tom Maunder, PE AOGCC lof2 5/14/200711:44 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of well OIL [] GAS ~] SUSPENDED [~ ABANDONED E~ SERVICE Classification of Service Well 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2484' FNL, 1226' FWL, Sec. 34, T13N, R10E, UM At Top Producing Interval 1746' FSL, 1213' FEL, Sec. 34, T13N, R10E, UM At Total Depth 1639' FSL, 784' FEL, Sec. 34, T13N, R10E, UM (asp's 556593, 6009947) (asp's 559442,6008920) (asp's 559872,6008816) J7. Permit Number 190-087 8. APl Number 50-029-22062 9. Unit or Lease Name Miline Point Unit 10. Well Number MPH-02 11. Field and Pool Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. I Milne Point Field RKB 72 feet I ADL 25906 I Ugnu Oil Pool 12. Date Spudded J13. Date T.D. Reached J 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 116. No. of Completions September25, 1990 I October2, 1990 I 12/01/2001 Recomp I N/A feetMSL I 1 17. Total Depth (MD + TVD) 118. Plug,Back Depth (,M.D + TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 6230' MD / 4466' TVD I 5580 MD/3937 TVD lYES I-~ No [--1 I noSSSV feetMD I 1900'(approx) 22. Type Electric or Other Logs Run ~DIL/LDT/CNL/NGT/DTE, PDK/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM CASING SIZE WT. PER FT. GRADE HOLE SIZE 13-3/8" 72# K-55 30" 9-5/8" 36# K-55 12-1/4" 35' 106' 35' 2562' 35' 62O6' 7" 26# L~80 8-1/2" 24. Perforations interval, size and number) I CEMENTING RECORD I AMOUNT PULLED 500 SXS PerrmaFrost C 102 sxs Arctic Set IV, 260 sxs 'G' 386 sxs 'G' o3en to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 4805' no packer--- ESP pump 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED I Ugnu Peds TVD Gun Size SPF 4910'-4970' 3437'-3473' 3-3/8" 6 5008'-5042' 3498'-3521' 3-3/8" 6 5104'-5138' 3564'-3589' 3-3/8" 6 5158'-5173' 3603'-3614' 3-3/8" 6 5210'-5270' 3643'-3689' 3-3/8" 6 5320'-5373' 3728'-3769' 3-3/8" 6 5400'-5432' 3791'-3816' 3-3/8" 6 5465'-5490' 3843'-3864' 3-3/8" 6 5530'-5555' 3895'-3916' 3-3/8" 6 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 12/01/2001 I ESP Date of Test Hours Tested IProduction for OIL-BBL IGAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/01/01 4 hrs JTest Period -> 0 J 1400 0 128/64 infinite Flow Tubing Casing Pressure ICalculated OIL-BBL IGAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 1000 ESP pump 124-Hour Rate > I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE ~S~(~I 0il & Gas Cons. Comlmssi~ ':- ' ' ' !,.RBOlq$ BFL JAN 7 2_002 29. 30. NAME Top of Ugnu Top of "N" Sands Top of "O" Sands GEOLOGIC MARKERS MEAS. DEPTH 4910' 5606' 5796' TRUE VERT. DEPTH 8436' 3954' 4109' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed . . ~'. engineer INSTRUCTIONS Prepared by DeWayne R. Schnorr 564-; General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: If no.. cores taken, indicate "none". Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Form 10-407 ' Coos Commissior,, ~Itla0it&Gas · 10/31/2001 11/02/2001 11/03/2001 11/04/2001 11/05/2001 11/06/2001 11/07/2001 11/08/2001 11/09/2001 11/10/2001 11/29/2001 12/02/2001 10/31/01 MPH-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PREP FOR RWO MIRU, ND TREE, NU BOPE. CIRCULATE WELL WITH KILL FLUIDS. DRIFT FOR CHEMICAL CUTTER. CHEMICAL CUTTER & PACKER RECOVERY - DECOMPLETION FISH RECOVERY- DECOMPLETION SET EZSV, SQUEEZE CEMENT & PERFORATE INSTALLED PACKER & SCREEN ASSEMBLY ACROSS UGNU MAKE UP ESP PUMP & TRIP INTO WELL CONTINUE TRIP INTO WELL & FREEZE PROTECT WELL. PULL BACK PRESSURE VALVE AND PRESSURE TEST FLOWLINES. FREEZE PROTECT IA. EVENT SUMMARY PULLED DPSOV, SET DGLV IN TOP SPM. PULLED SHEARED SHEAR VALVE FROM BOTTOM MANDREL, LEFT OPEN. SET BPV WITH 1300# UNDERNEATH. 11/02/01 11/03/01 11/04/01 SPOT HIGH ViS GEL PILL TO PERFS. ATTEMPTED TO LOAD ANNULUS WITH SEAWATER. STILL UNABLE TO FILL HOLE. SET BPV. BREAK DOWN HARD LINES. ND TREE. NU ADAPTOR FLANGE. SET BOP STACK ON WELLHEAD. NU BOP STACK. RU LUBRICATOR. CONDUCT BOP TEST. AOGCC WAIVED WITNESSING. BLEED GAS FROM ANNULUS (100 PSI). GAS PRESSURE STILL BUILDING. PUMP 35 BBL SIZED PILL @ 3 BPM 300 PSI. MONITOR WELL. PUMP 30 BBL. SI MONITOR. MIX 45 BBL "SCHRADER BLUFF" LCM PILL. (N VIS, BARAFIBRE, NDRILL HT, BARACARB, OM SEAL). PUMP 3 BPM 150 PSI TO 650 PSI. SLOWED RATE WHEN "PILL" REACHED TOP OF PACKER AT 5177'. 400 PSI, 1.5 BPM. DISPLACED UNTIL END OF PILL CLEARED ESP ASSEMBLY AND SHUT DOWN. 120 PSI ISIP DECREASED TO ZERO. SCREWED IN LANDING JOINT TO HANGER. LINE UP TO CIRCULATE DOWN TUBING WITH RETURNS TO PITS. PUMPING 3 BPM 300 PSI. CIRCULATE & PUMP HOLE CLEAN AND CRUDE OUT TO TIGER TANK. 3 BPM 400 PSI. LOST 13 BBLS TO WELLBORE DURING CIRCULATION. RU DOUBLE SHEAVE AND TRUCK FOR SPOOLING ESP CABLE. TAGGED UP AT 5647' WLM. STICKY BOTTOM. BELOW WHERE E-LINE NEEDS TO CUT. NO PROBLEMS IN OR OUT OF WELL ONCE TOOL STRING WAS CHANGED. 11/07/01 CONTINUED 11/08/01 11/09/01 11/10/01 11/29/01 12/02/01 MPH-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS TEST 7" CASING DOWN TO CDT RETAINER 3000 PSI FOR 30 MINS RECORDED. MU DRILL PIPE CONVEYED PERFORATING ASSEMBLY. TIH WITH 3-1/2" DRILL PIPE. RU SCHLUMBERGER WlRELINE. RIH W/GR/CCL & CORRELATE PERF DEPTH TO DIL-SFL (03-OCT-90). PERFORATED UGNU 4910- 4970, 5008-5042, 5104-5138, 5158-5173, 5210-5270, 5320-5373, 5400-5432, 5465- 5490, 5530-5555. OPEN ANNULAR. MONITOR WELL. CLOSE ANNULAR AND REVERSE CIRCULATE 2X TBG VOLUME. START TOOH. DP TOO GASSY. SD & CIRCULATED THE LONG WAY. ANNULUS SIGNIFICANTLY GAS CUT. CONTINUE CIRCULATING 4 BPM, 500 PSI RAISING BRINE WT TO 9.3 PPG UNTIL WE GAIN WELLBORE STABILITY. THEN PLAN TO TOOH. RAISED BRINE WEIGHT FROM 9.0 TO 9.3 PPG. POOH W/3-1/2" DP & LAID DOWN PERFORATING GUNS. ALL SHOTS FIRED. MAKE-UP BAKER F-1 PACKER TO SCREEN ASSEMBLY. TIH W/SCREENS ASSY ON DP. TAG CMT RETAINER @ 5577'. SPACE OUT TO 5561'. DROP 1.565" STEEL BALL. SET BAKER F1 PACKER. PRESSURED UP DOWN DP TO 2000 PSI. TOOL STROKED. PULL 35K OVER THEN SLACK OFF. PU TO NEUTRAL. BLED OFF DP PRESSURE. TESTED ANNULUS TO 1500 PSI. ROTATED OUT OF PACKER W/ RUNNING TOOL. BLOW OUT BALL SEAT IN RUNNING TOOL. POOH & LDDP & RUNNING TOOL. CHANGE OVER TOOLS TO RIH W/2-7/8" TUBULARS. MOUNT DOUBLE SHEAVE IN DERRICK FOR CABLE SPOOLING. MU & SERVICED MOTOR, SEAL, & PUMP ASSEMBLY. TEST ESP EQUIPMENT & MU ELECTRIC CABLE. TIH W/ ESP ASSEMBLY, HEAT TRACING W/FLAT GUARD, & CABLE. CONTINUED TO RIH WITH ESP COMPLETION. MAKE UP HANGER & LAND HANGER & TEST SAME & SET TWC. NIPPLE DN BOP. NIPPLE UP TREE & TEST TO 5000 PSI. PULL TWC & SET BPV & RIG HB&R & FREEZE PROTECT WELL WITH DEAD CRUDE IN ANNULUS AND DIESEL IN TBG TO 2000' & SECURE TREE AREA. RELEASED RIG @ 2300 HRS. RIG DN. WELL SUPPORT RIGGED UP AND PULLED BPV, THEN RIGGED UP AND PRESSURE TESTED FLOWLINES TO 1150 PSI. JOB WAS COMPLETED WITH NO PROBLEMS AND TEST WAS GOOD. NOTE: BACK PRESSURE VALVE WAS LEFT OUT! FLUSH INNER ANNULUS WITH DEAD CRUDE TO ELIMINATE POSSIBILITY OF HYDRATES IN PRODUCTION TUBING. PUMP 100 BBLS DEAD CRUDE DOWN INNER ANNULUS @ 1.0 BPM @ 1100 TO 1225 PSI. JOB PUMPED SUCCESSFULLY. STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMisSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging I~I Perforate I~! Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development RKB = 72' [] 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 2484' SNL, 4053' WEL, SEC. 34, T13N, R10E, UM MPH-02 At top of productive interval 9. Permit190.~l[gNumber~/"~~i~val No. 1746' NSL, 1213' WEL, SEC. 34, T13N, R10E, UM 10. APl Numb--~' At effective depth 50-029-22062-00 1639' NSL, 784' WEL, SEC. 34, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / °chrader Bl,,ff 1525' NSL, 423' WEL, SEC. 34, T13N, R10E, UM 12. Present well condition summary Total depth: measured 6230 feet Plugs (measured) Bull Plug at 5556' true vertical 4466 feet HES EZSV at 5580' Effective depth: measured 5580 feet Junk (measured) true vertical 3937 feet Casing Length Size Cemented M D TVD Structural Conductor 71' 13-3/8" 500 sx Permafrost 'C' 106' 106' Surface 3073' 9-5/8" 1102 sx Arctic Set IV 260 sx Class 'G' 3108' 2475' Intermediate Production 6169' 7" 386 sx Class 'G' 6204' 4443' Liner Perforation depth: measured Open Perfs behind Gravel Pack: 4910' - 4970; 5008' - 5042'; 5104' - 5138'; 5158' - 5173'; 5210' - 5270'; 5320' - 5373'; 5400' - 5432'; 5465' - 5490'; 5530' - 5555'; Abandon Schrader Bluff Perfs: 5606' - 5904' true vertical Open Perfs behind Gravel Pack: 3438' - 3476', 3500' - 3523', 3566' - 3590', 3605' - 3616', 3644' - 3690', 3729' - 3771 ', 3792' - 3818', 3844' - 3864', 3897' - 3917'; Abandon Schrader Bluff Perfs: 3954' - 4197' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 TO 4884'. Packers and SSSV (type and measured depth) Baker 'F' Packer at 4896', 7", Baker 'D' Sump Packer at 5746' 13. Stimulation or cement squeeze summary ~'~,~--~,~..,! V Intervals treated (measured) DEC 0 4 2001 Treatment description including volumes used and final pressure Alaska 011 & Gas Co~s. Commission 14. Representative Daily Averaqe 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: ASCANNED SF.P 1 2, 2002 [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended :service - [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Son ~.%~¥~ .... _~,tle Technical Assistant Date Prepared By Name/Nurnbec Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate" Legal Well Name: MPH-02 Common Well Name: MPH-02 Spud Date: 11/2/2001 Event Name: RECOMPLETION Start: 11/2/2001 End: 11/10/2001 Contractor Name: NABORS Rig Release: 11/10/2001 Rig Name: NABORS 4ES Rig Number: 11/2/2001 00:00 - 04:00 4.00 RIGU 3 ~PRE SCOPE DOWN AND LOWER DERRICK. M~VE RIG FROM MPF-06 TO MPH-02. MOVE CAMP, PITS, SUB, & PIPE SHED. 04:00 - 06:00 2.00 RIGU 3 PRE SPOT RIG OVER WELLHEAD AND BERM RIG. 06:00 - 07:00 1.00 RIGU 3 PRE ~ISE AND SCOPE DERRICK. ACCEPT NABORS 4ES AT 0700 HRS 11/2/2001. 07:00 - 08:00 1.00 RIGU 3 DECOMP BERM AND SET TIGER TANK. RUN LINES FROM TANK TO BLOOEY LINE CONNECTION. 08:00 - 09:00 1.00 RIGU ~ DECOMP INSTALL HCR VALVE TO ANNULUS AND CONNECT HARDLINES. 09:00 - 10:00 1.00 RIGU 3 DECOMP MU LUBRICATOR. PULL BPV(1400 PSI ON TUBING). 10:00 - 10:30 0.50 RIGU DECOMP TEST HARD LINES. TAKE ON 500 BBLS SEAWATER INTO PITS. 10:30 - 14:00 3.50 KILL DECOMP PRE JOB SAFE~ AND P~NNING MEETING WITH CO. MAN AND TOOLPUSHER. CP 1240 PSI. TP 1260 PSI. KILL WELL BY PUMPING SEAWATER DOWN TUBING AT 3 BPM 200 PSI. NO RETURNS UP ANNULUS TO TIGER TANK. 14:00 - 17:00 3.00 KILL 3 DECOMP SPOT HIGH VIS GEL PILL TO PERFS. A~EMPTED TO LOAD ANNULUS W/SEAWATER. STILL UNABLE TO FILL HOLE. 17:00- 17:30 0.50 BOPSUF.P DECOMP SET BPV. BREAK DOWN HARD LINES. 17:30- 19:00 1.50 BOPSUF.P DECOMP NDTREE. 19:00 - 20:00 1,00 BOPSUF~P DECOMP NU ADAPTOR F~NGE. SET BOP STACK ON WELLHEAD. 20:00 - 20:30 0.50 BOPSUF.N DECOMP CHANGE OUT SEALS ON ANNU~R PREVENTER. 20:30- 00:00 3.50 BOPSUF.P DECOMP NU BOP STACK. RU LUBRICATOR. 11/3/2001 00:00 - 01:30 1.50 BOPSUF.P DECOMP RU LUBRICATOR. PULL BPV & SET ~C. RU TEST EQUIPMENT. 01:30 - 08:30 7.00 BOPSUF P DECOMP CONDUCT BOP TEST. AOGCC WAIVED WITNESSING. ~C LEAKING. PULL ~C, REDRESS, RE-INSTALL AND PROCEED W/BOP TEST. TUBING HANGE~C LEAKING. RE-TORQUE LOCK DOWN SCREWS. D~IN BOP STACK. 08:30 - 09:00 0.50 KILL P DECOMP BLEED GAS FROM ANNULUS(100 PSI). GAS PRESSURE STILL BUILDING. 09:00 - 12:00 3.00 KILL P DECOMP PUMP 35 BBL SIZED SALT PILL AT 3 BPM 300 PSI. MONITOR WELL. 12:00- 14:00 2.00 KILL P DECOMP PUMP 30 BBL. SI MONITOR. 14:00 - 16:00 2.00 KILL P DECOMP RIG MAINTENANCE WHILE WAITING ON LCM PRODUCTS. 16:00 - 22:00 6.00 KILL P DECOMP MIX 45 BBL "SCH~DER BLUFF" LCM PILL.(N VIS, BA~FIBRE, NDRILL HT, BA~CARB, OM SEAL). PUMP 3BPM 150 PSI TO 650 PSI. SLOWED ~TE WHEN "PILL" REACHED TOP OF PACKER AT 5177', 400 PSI, 1.5 BPM. DISP~CED UNTIL END OF PILL CLEARED ESP ASSEMBLY AND SHUT DOWN. 120 PSI ISIP DECREASED TO ZERO. 22:00 - 23:00 1.00 KILL P DECOMP SCREW IN ~NDING JOINT TO HANGER. LINE UP TO CIRCU~TE DOWN TUBING WITH RETURNS TO PITS. PUMPING 3 BPM 300 PSI. CIRCU~TE & PUMP HOLE CLEAN AND CRUDE OUT TO TIGER TANK. 3 BPM 400 PSI. LOST 13 BBLS TO WELLBORE DURING CIRCU~TION. 23:00 - 00:00 1.00 PULL P DECOMP RU DOUBLE SHEAVE AND TRUNK FOR SPOOLING ESP CABLE. ,CANN D SEP 1 2002 Printed: 11/30/2001 10:39:45AM Legal Well Name: MPH-02 Common Well Name: MPH-02 Spud Date: 11/2/2001 Event Name: RECOMPLETION Start: t 1/2/2001 End: 11/10/2001 Contractor Name: NABORS Rig Release: 11/10/2001 Rig Name: NABORS 4ES Rig Number: i ~i: ~'"'~ :'"~: ~i~ ~ ~ ~e i DescriPtion of oPeratiOns 11/4/2001 00:00 - 01:00 1.00 PULL P DECOMP MONITOR WELL. RU DOUBLE SHEAVE & TRUNK FOR ELECTRIC CABLE AND HEAT TRACE SPOOLING. 01:00 - 02:00 1.00 PULL P DECOMP BACK-OUT LOCK DOWN SCREWS. PULL HANGER LOOSE WITH 42K PUVV. LD HANGER. 02:00 - 08:30 6.50 PULL P DECOMP TOOH VV/ 2 7/8" TUBING, E-CABLE, AND HEAT TRACE. SLM. 08:30 - 10:30 2.00 PULL P DECOMP RECOVERED ALL CABLE BANDS. DISCONNECT CABLE HEAD. INSPECT PUMP ASSEMBLY AND LAY DOWN SAME. 10:30 - 11:00 0.50 PULL P DECOMP CLEAR RIG FLOOR. RU TOOLS FOR TIH. 11:00 - 13:30 2.50 PULL P DECOMP RIH W/BAKER LOCATER SUB ON 2 7/8" TUBING. PUW 33K, SOW 25K 13:30 - 14:00 0.50 PULL P DECOMP TAG TOP OF PACKER AT 5171 FT.(4ES RT). SPACE OUT W/2 PUP JOINTS. VERIFY TAG W/130 PSI, 2 BPM DOWN TUBING. 14:00- 17:00 3.00 PULL P DECOMP WAIT ON HES SLICKLINE UNIT. RIG MAINTENANCE. 17:00 - 18:00 1.00 PULL P DECOMP RU SLICKLINE. 18:00 - 20:30 2.50 PULL P DECOMP RIH W/BAILER, 2.3" OD, SWAGE, SPANG JARS, OIL JARS ON SLICKLINE. SET DOWN TIGHT AT 240 FT. POH. RIH W/2.1" OD ASSEMBLY AND SET DOWN AT 5659 FT. (74 FT PAST PROPOSED LOWER CHEMICAL CUT DEPTH). POOH & FOUND 1/2" PIECE OF RUBBER DEBRIS IN BAILER. RD HES SLICKLINE UNIT. 20:30 - 23:00 2.50 PULL P DECOMP we SCHLUMBERGER E-LINE UNIT FOR CHEMICAL CUTTER. 23:00 - 00:00 1.00 PULL P DECOMP RU SCHLUMBERGER E-LINE UNIT. 11/5/2001 00:00 - 00:30 0.50 PULL DECOMP CONTINUE RIGGING UP WlRELINE FOR CHEMICAL CUT RUN #1. 00:30 - 06:00 5.50 PULL DECOMP CONDUCT PRE-JOB SAFETY MEETING ON CHEMICAL CUTTER & PENDING OPERATIONS. RIH, CORRELATE, AND CUT 2 7~8" "BLANK PIPE" AT 5591'. POOH AND RIG UP FOR 2ND CHEMICAL CUT. 06:00 - 07:00 1.00 DECOMP RIH W/CHEMICAL CUTTER. CORRELATE TO CCL AND SEVER "BLANK PIPE" AT 5220'. 07:00 - 08:30 1.50 PULL DECOMP POOH W/E-LINE. CONDUCT SAFETY MEETING AT 200'. RIG DOWN CHEMICAL CUTTER ASSEMBLY 08:30 - 11:30 3.00 PULL DECOMP MONITOR WELL. TOOH W/2 7~8" TUBING AND LOCATOR SUB. PULLED 7K OVER, (WEIGHT INDICATOR 40K LBF). 11:30 - 12:00 0.50 PULL DECOMP CLEAR RIG FLOOR AND RU TO PU 3 1/2' SINGLES FROM PIPE SHED. 12:00 - 13:00 1.00 PULL DECOMP MU PACKER RETRIEVAL TOOL, XO, BUMPER SUB, HYD JARS, 9 EA 4 3/4" DC'S. 13:00- 17:00 4.00 PULL DECOMP TIHW/3 1/2" DP. SOW43K, PUW75K. TAGGED PKRW/ 10K DOWN WIGHT, PU 25K. PULLED PACKER FREE W/ 47K OVER STRING WEIGHT(WEIGHT INDICATOR 122K). 17:00 - 18:00 1.00 PULL DECOMP MONITOR WELL. FILL ANNULUS W/18 BBLS SEAWATER. 18:00 - 21:00 3.00 PULL DECOMP TOOH W/"SC-1 GRAVELPACK" PACKER. LAY-OUT FISH & RETRIEVING TOOL. FULL RECOVERY. GOOD CHEMICAL CUT. 21:00 - 00:00 3.00 PULL DECOMP MU WASH SHOE, BOOT BASKET. 11/6/2001 00:00 - 03:00 3.00 PULL DECOMP CONT RIH W/6" WASHOVER PIPE ASSEMBLY. TAG TOP OF FISH (~5217 FT. 03:00 - 06:30 3.50 PULL DECOMP WASHDOWN WITH KELLY, IN SINGLES, FROM 5217 TO SF.'P Z 2, 2002 Printed: 11/3o/2ool 10:39:45AM Legal Well Name: MPH-02 Common Well Name: MPH-02 Spud Date: 11/2/2001 Event Name: RECOMPLETION Start: 11/2/2001 End: 11/10/2001 Contractor Name: NABORS Rig Release: 11/10/2001 Rig Name: NABORS 4ES Rig Number: 'il iii~~ili!i~~:ilT~iii: 'i~~!i~ ~,:~a~ ~: :i: .:i Description of operationS 11/6/2001 03:00 - 06:30 3.50 PULL DECOMP 5584 FT. 4-5 BPM, 50 RPM, 550 PSI, 80K PUW, 55K SOW, RO'I'VV 65K. TAKING WEIGHT WHILE MILLING EA MID-JT CENTRALIZER. 3-4000 FT-LBF TORQUE. 06:30 - 07:30 1.00 PULL DECOMP PUMP HIGH VIS SWEEP. 07:30 - 11:00 3.50 PULL DECOMP MONITOR WELL. SET BACK KELLY. TOOH. LD WASH-PIPE ASSEMBLY. 11:00 - 14:00 3.00 PULL DECOMP CLEAR FLOOR. PU BHA#3: CUT LIP GUIDE, HOLLOW MILL CONTAINER, OVERSHOT BOWL W/2 7~8" PACK-OFF MILL CONTROL, GRAPPLE, EXTENSION, TOP SUB, BUMPER JAR, OIL JARS, 9 4 3~4" DC'S, ACCELERATOR JARS, & PUMP OUT SUB. TIH W/3 1/2" DRILLPIPE. 14:00 - 14:30 0.50 PULL DECOMP WORK DOWN TO 5221'. PUW 80K, SOW 56K, LATCH FISH. MONITOR WELL 14:30 - 18:00 3.50 PULL DECOMP TOOH. DID NOT RECOVER FISH. 18:00 - 20:00 2.00 PULL DECOMP REMOVED HOLLOW MILL CONTAINER FROM FISHING ASSEMBLY AND TRIPPED BACK IN HOLE W/BHA #3. 20:00 - 23:00 3.00 PULL DECOMP TAG TOP OF FISH. PUW 84K, SOW 57K. SET DOWN 5217-5223, 2BPM 150 PSI. LATCH FISH. PICKED UP AND HAD ADDITIONAL 3000 LBF WEIGHT. TOOH W/ BHA #3 & FISH. 23:00 - 00:00 1.00 PULL DECOMP LD 371 FT OF 2 7~8" FISH. LD 9EA 4 314" DCS. 11/7/2001 00:00 - 01:00 1.00 PULL P DECOMP RIH & LAY DN DRILL COLLARS. 01:00 - 02:00 1.00 REST P COMP CLEAN & CLEAR RIG FLOOR 02:00 - 02:30 0.50 REST P COMP LOAD PIPE SHED WITH 3.5" DP & TALLY & DRIFT. 02:30 - 06:00 3.50 RUNCOI~ COMP MU HES EZSV PLUG & RIH WITH SAME & SET @ 5580' TOP 06:00 - 08:00 2.00 RUNCOI~ COMP SET EZSV AT 5580 FT(TOP OF RETAINER). BREAK CIRCULATION AROUND CMT RETAINER AT 3 BPM, 425 PSI. SD RIG PUMPS. ROTATE 38 ROUNDS & SET RETAINER. SHEAR OFF W/TH 55K OVER STRING WT. STING IN AND ESTABLISH INJECTION RATE AT 2.5 BPM, 400 PSI. STING OUT. CLOSE ANNULAR TEST CASING TO 2500 PSI.OK. 08:00 - 08:30 0.50 RUNCOr~ COMP SPOT 4 BBLS CL G CMT, STING INTO RETAINER, AND PUMP CMTAT 2 BPM, 100 PSI. 08:30 - 10:30 2.00 RUNCOI~ COMP STING OUT & BLOW DOWN CMT LINES. REVERSE OUT DP. TRACE OF CMT AT BTMS UP. DISPLACE WELL TO 9.1 PPG BRINE. 10:30 - 11:00 0.50 RUNCOI~!3 COMP TEST 7" CASING DOWN TO CMT RETAINER 3000 PSI, 30 MINS RECORDED. 11:00 - 13:30 2.50 RUNCOItP COMP LAY DOWN 24 SINGLES & STAND BACK 52 STDS. 13:30 - 14:00 0.50l RUNCOklP COMP LOAD PIPSED WI HES 3 3/8" PERF GUNS. RE-STRAP LENGTHS. 14:00 - 15:30 1.50 RUNCOr P COMP MU DRILL PIPE CONVEYED PERFORATING ASSEMBLY. 15:30 - 18:00 2.50 RUNCOr F) COMP TIH W/3 1/2" DRILL PIPE. 18:00 - 21:30 3.50 RUNCO~ I:) COMP RU SCHLUMBERGER WIRELINE. RIH W/GPJCCL & CORRELATE PERF DEPTH TO DIL-SFL(03-OCT-90). PERFORATE UGNU 4910-4970', 5008'-5042', 5104'-5138', 5158'-5173', 5210'-5270', 5320-5373', 5400'-5432', 5465'-5490', 5530'-5555'. 21:30 - 22:30 1.00 RUNCO~P COMP OPEN ANNULAR. MONITOR WELL. CLOSE ANNULAR AND REVERSE CIRCULATE 2X TBG VOLUME. 22:30 - 00:00 1.50 RUNCOI~ COMP START TOOH. DP TOO GASSY. SD & CIRCULATED THE 2002 Printed: 11/30/2001 10:39:45AM Legal Well Name: MPH-02 Common Well Name: MPH-02 Spud Date: 11/2/2001 Event Name: RECOMPLETION Start: 11/2/2001 End: 11/10/2001 Contractor Name: NABORS Rig Release: 11/10/2001 Rig Name: NABORS 4ES Rig Number: 11/7/2001 22:30 - 00:00 1.50 RUNCOI~ COMP LONG WAY. ANNULUS SIGNIFICANTLY GAS CUT. CONTINUE CIRCULATING 4 BPM, 500 PSI RAISING BRINE ~ TO 9.3 PPG UNTIL WE GAIN WELLBORE STABILITY. THEN PLAN TO TOOH. 11/8/2001 00:00 - 01:30 1.50 RUNCOI~ COMP RAISED BRINE WEIGHT FROM 9.0 TO 9.3 PPG. 01:30 - 05:00 3.50 RUNCOr~F~ COMP POOH WI 3 1/2" DP & LAID DOWN PERFORATING GUNS. ALL SHOTS FIRED. 05:00 - 06:00 1.00 RUNCOr~P COMP CLEAR AND CLEAN RIG FLOOR. 06:00 - 08:00 2.00 RUNCOr~!3 COMP LOAD PIPE SHED W/4 1/2" SCREENED PIPE ASSEMBLY. RU FLOOR TO RUN SCREENS. 08:00 - 12:00 4.00 RUNCOr~P COMP MAKE-UP SCREEN ASSEMBLY. 12:00 - 13:00 1.00 RUNCOr F~ COMP CLEAR FLOOR AND RIG UP TO RUN DRILL PIPE. MAKE-UP BAKER F-1 PACKER TO SCREEN ASSEMBLY. 13:00 - 18:00 5.00 RUNCOt P COMP TIH W/SCREENS ASSY ON DP. TAG CMT RETAINER AT 5577' MD. SPACE OUT TO 5561'. DROP 1.565" STEEL BALL. 18:00 - 19:30 1.50 RUNCO~ COMP SET BAKER F1 PACKER. PRESSURED UP DOWN DP TO 2000PSI. TOOL STROKED. PULL 35K OVER THEN SLACK OFF. PU TO NEUTRAL. BLED OFF DP PRESSURE. TESTED ANNULUS TO 1500 PSI. ROTATED OUT OF PACKER W/RUNNING TOOL. BLOW OUT BALL SEAT IN RUNNING TOOL. 19:30 - 00:00 4.50 RUNCOI~ COMP POOH & LDDP & RUNNING TOOL. CLEAR RIG FLOOR. 11/9/2001 00:00 - 01:00 1.00 RUNCOI~ COMP CLEAR & CLEAN RIG FLOOR. CHANGE OVER TOOLS TO RIH W/2 7~8" TUBULARS. MOUNT DOUBLE SHEAVE IN DERRICK FOR CABLE SPOOLING. 01:00 - 03:00 2.00 RUNCOI~I COMP MU & SERVICED MOTOR, SEAL, & PUMP ASSEMBLY. 03:00 - 05:00 2.00 RUNCOI~ COMP TEST ESP EQUIPMENT & MU ELECTRIC CABLE. 05:00 - 00:00 19.00 RUNCOr~I COMP TIH W/ESP ASSEMBLY, HEAT TRACING W/FLAT GUARD, & CABLE. 11/10/2001 00:00 - 04:00 4.00 RUNCOI~ COMP CONTINUE TO RIH WITH ESP COMPLETION. 04:00 - 04:30 0.50 RUNCOI~F~ COMP MAKE UP HANGER & IDENTIFIED THAT IT WAS INCORRECT HANGER. 04:30 - 16:00 11.50 RUNCOK~ COMP BACK OUT HANGER & REMOVE PENETRATORS & INSTALL CORRECT HANGER. & MAKE EFT CONNECTOR & ATTEMPT TO LAND FOUND THAT TBG. SUMMARY UNCORRECT PICK UP & TAKE OUT 10' PUT & RE-DO CONNECTOR & LAND HANGER & TEST SAME & SET TWC. 16:00 - 18:00 2.00 BOPSUF P COMP NIPPLE DN BOP 18:00 - 20:00 2.00 WHSUR P COMP NIPPLE UP TREE & TEST TO 5000 PSI. 20:00 - 23:00 3.00 RUNCOI~ COMP PULL TWC & SET BPV & RIG HB&R & FREEZE PROTECT WELL WITH DEAD CRUDE IN ANNULUS AND DIESEL IN TBG. TO 2000' & SECURE TREE AREA. & RELEASE RIG @ 2300 HRS. 11/10/2001 23:00 - 00:00 1.00 MOB P PRE RIG DN Printed: 11/30/2001 10:39:45AM SCANNED SEP 1 g 2002 iVlllne i--OlFl[ unl[ ~3t-,m-u/{,r i u luu-uo~ ) oul ~u~ y ~,o~J ~-~u ~ I Subject: Date: From' To: CC: BCC: Milne Point Unit MPH-02 (PTD 190-087) Sundry (301-301) Tue, 06 Nov 2001 15:46:07 -0900 Tom Maunder <tom_maunder@admin.state.ak. us> Bill Mathews <mathewwi@bp.com> John D Hartz <jack_hartz@admin.state.ak. us>, Bob Crandall <bob_crandall@admin.state.ak. us>, Steve Davies <steve_davies@admin.state.ak. us>, Jane Williamson <Jane_Williamson@admin.state.ak. us> Cammy Oechsli <Cammy_Oechsli@admin.state.ak. us>, Daniel T Seamount JR <dan_seamount@admin.state.ak. us>, Julie Heusser <julie_heusser@admin.state.ak. us> Bill, We have received your sundry application for MPH-02 where you propose to abandon the Schrader intervals in the well and complete shallower in the Ugnu to test the potential productivity. According to the records we have consulted, there is an Ugnu undefined pool at Milne Point. Assessing the potential of oil bearing formations is an activity that the Commission supports. By copy of this email, you have approval to proceed with the mechanical work you proposed in you application. Prior to initiating test production from the well, you should make contact with Jack Hartz to review the proposed testing program for the well and interval(s). It will also be necessary to have a plan for allocating the well's production to proper pool. Jack's number is 793-1232. We look forward to reviewing your plans in the near future. Good luck. Tom Maunder, PE Sr. Petroleum Engineer AOGCC Tom Maunder <tom maunderL'~.admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I of I 11/6/01 3:46 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operationalshutdown_ Re-enter suspended well _ __~ _ AbandSchrader ~ I Plugging_ Time extension_ Stimulate _'"'~'-~R~complete Ugnu Pull tubing _ Variance _ P - ~'"~erforate _ 1. Type of request: Abandon Schrader Recomplete in Ugnu Abandon_ Suspend_ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2484' FNL, 1226' FWL, Sec. 34, T13N, R10E, UM At top of productive interval 1634' FSL, 769' FEL, SEC 34, T13N, R10E, UM At effective depth 1610' FSL, 688' FEL, Sec. 34, T13N, R10E, UM At total depth 1525' FSL, 423' FEL, Sec 34 T13N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 556593, 6009947) (asp's 559887, 6008812) (asp's 559969, 6008788) (asp's 560234, 6008706) 6. Datum elevation (DF or KB feet) RKB 72.0 feet 7. Unit or Property name Milne Point Unit 8. Well number MPH-02 9. Permitnumber/approvalnumber 190-087 10. APInumber 50-029-22062 11. Field / Pool Milne Point Unit / Schrader 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 106' Surface 2527' Production 6171' 6230 feet Plugs (measured) Tubing Plug Stuck in 'XN' Nipple @ 5753'. 4466 feet Attempted to cut tailpipe. 5753 feet Junk (measured) 4078 feet Size Cemented Measured Depth True vertical Depth 20" Back to Surface 141' 141' 9-5/8" Back to Surface 2562' 2176' 7" TOC @ 4500' (Approx) 6206' 4446' Perforation depth: Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 13. Attachments measured Open Perfs Behind Gravel Pack 5606' - 5622', 5640' - 5666', 5677' - 5684', 5705' - 5728'. Open Perfs Below Stuck Plug 5796' - 5834', 5874' - 5904'. true vertical Open Perfs Behind Gravel Pack 3954' - 3967', 3982' - 4003', 4012' - 4017', 4035' - 4053'. Open Perfs Below Stuck Plug 4109' - 4140', 4172' - 4197'. 2-7/8", 6.4#, L-80 TBG @ 5079' MD. Bottom of ESP Pump @ 5120'. ~ 7" x 2-7/8" Baker SC-IL PKR @ 5177', 7" x 2-7/8" Baker 'D' Sump PKR @ 5746'. ~J,-~-J 2-7/8" Camco KBMG GLM with 1" sidepocket @ 220' MD. _ Description summary of proposal __X Detailed operations program __ BOP sketch __ J ~ J 14. Estimated date for commencing operation October 30, 2001 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ X Gas __ Service Suspended __ ~h~J~ing is t/.t.t~e and correct to the best of my knowledge. ,~~~,--~- Title: Milne Point Petroleum Engineer FOR COMMISSION USE ONLY Questions? Call William Mathews @ 564-5476. Date October 22, 2001 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance -- Mechanical Integrity Test__ Subsequent form required 10- i,~ Original Signed By Approved by order of the Commission Cammy 0echsli Commissioner Approval no. ,,~O[ - Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 19, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for MPH-02: Abandon Recomplete in Ugnu Formation Schrader Bluff and BP Exploration Alaska, Inc. proposes to abandon the Schrader Bluff interval in well MPH-02 and recomplete the well in the Ugnu sands. MPH-02 was initially drilled in 1991 as a Schrader producer. The O sands were frac'd and the N sands gravel packed. The well was damaged following a rig workover in 1994 and produced at Iow rates until pump failure in July 1998. The well has remained shut in since. MPH-13 was drilled to a bottom-hole location in the Schrader formation within 300 ft of MPH-02, essentially replacing the wellbore. MPH-02 has no future utility as a Schrader producer and is too close to MPH-13 to be an effective injector. There is however, production potential from the Ugnu interval in this well. The Schrader interval will be abandoned by setting a cement retainer in the casing at approximately 5580'md and down squeezing approximately 10 bbls cement below the retainer and into the N sand perforations. Due to the limited clearance between the proposed Ugnu perforations and the retainer setting depth, plans will not include placing a cement cap on top of the retainer. Perforations will be shot in the Ugnu sands at various intervals from 4910-5555' md and the well will be recompleted as shown in the attached schematic. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5476 or e-mail me at mailto:mathcwwl@bp.com. Sincerely, William L Mathews Milne Point Unit/Schrader Bluff Completion Engineer Well MPH-02 Current Status · Pump failed in July 1998. · Well has been shut in and freeze protected. BPV set. · Wellhouse has been removed. Plan Forward: 1. MIRU. Kill well if necessary 2. Pull existing completion 3. Clean out to TD 4. RIH and cut the blank section of 2-7/8" tubing at -5590' md 5. RIH and set an cement retainer at -5580' md and squeeze N sands 6. Perforate the Ugnu sands using TCP guns (see schematic for intervals) 7. Run proposed 2-7/8" completion with screens across perforations 8. Put well on production Tree: 2-9/16"-5M WKM Wellhead:l 1" 5M WKM w/11" x 2 7/8" tbg. hng, 2.5" 'H' BPV profile and 8 rd. threads top and btm. !KOP @ 4OO' Max. hole angle: 56 to 60 deg. f/2400' to 4850' Hole angle through perfs = 35 deg. DLS > 4 de(]. / 100' f/4800' to 5150' MP H-02 Proposed Orig. RKB = 72' (Nabors 27E) GL = 37' Camco 2 7/8" KBMG GLM I 120' md w/1" sidepocket Raychem Heat-Trace to 2500' MD 9 5/8", 36 ppf, K-55 12562' mdlJ Btrc. 7", 26 ppf, L-80, Btrc. production casing (cap. = 0.0383 bpf, ID = 6.276') 2-7/8", 6.5 ppf, L-80, 8rd EUE, tbg. (cap. = 0.0058 bpf, ID = 2.441") Radioactive marker in collar at 4941' md Camco 2 7/8" KBMG GLM w/1" sidepocket ESPCP set @ -4850' md Pumpmate gage Stimulation Summary: Perforation Summary: Guns: 3-3/8" HSD (34BHJ11) 4 spf, 180 deg phasing Size ISPF/ Interval 9-3/8" ~4 spf ~4910-4970 3-3/8" ~4 spf ~5008-5042 ~'3/8'~ spf p32~5373 ..... r- - (TVD) 2 7/8" HES 'X' Npl. (2.313" PB) 7" x 4.5" Packer @ -4900' md 4.5" blank pipe to space out to 4910' 4.5" Low profile pro-pack 0.020 ga. (4910-4970', 5010-5040', 5104-5134', 5151-5181', 5211-5271'md) with 4-1/2" blank pipe to space out intervals 3.5" 125 micron Poroplus screens (5341-5371 ',5401-5431 'md) with 3-1/2" blank pipe to space out intervals 3.5" Wire wrap screens 0.012 Ga. (5464-5494',5529-5549'md) with 3-1/2" blank pipe to space out intervals Bull plug on bottom of assembly EZSV set @ -5580' md with cement below. new 2 7/8" blank pipe stub@ -5590' md old 2 7/8" Bakerweld 12 ga. screen @ 5601' PBR (2.062" ID) @ 5733' md 2 7/8" Bakerweld 12 ga.screen @ 5735' 7" Baker 'D' sump pkr. @ 5746' md Otis 'XN' Npl. (1.791" no-go) @ 5753' md WLEG @ 5755' md 7" Float collar I 6125' md 7" Csg. shoe [ 6206' md DATE 10/04/90 REV. BY JBF COMMENTS D & C by Nabors 27E 12/24/90 JBF iravel Pack and initial ESP Compl. 09/05/94 JBF !SP Replacement by Nabors 4ES MILNE POINT UNIT WELL H-02 APl NO: 50-029-22062 BP Tree: 2-9/16"-5M WKM P Wellhead:Il" 5M WKM w/11" x 2 IVI n-u~' Orig. RKB = 72' (Nabors 27E) 7/8" tbg. hng, 2.5" 'H' BPV profile GL = 37' and 8 rd. threads top and btm. KOP @ 400' Camco 2 7/8" KBMG GLM I 220' md Max. hole angle: 56 to 60 deg. w/1" sidepocket f/2400' to 4850' Hole angle through perfs = 35 deg. Raychem Heat-Trace to 2285' MD DLS > 4 deo./ 100' f/4800' to 5150' 95/8", 36 ppf, K-55 12562' mdll Btrc. 7", 26 ppf, L-80, Btrc. production casing (cap. = 0.0383 bpf, ID = 6.276') Radioactive marker in collar at 4941' 2-7/8", 6.5 ppf, L-80, 8rd RUE, tbg. md (cap. = 0.0058 bpf, ID = 2.441") Camco 2 7/8" KBMG GLM 14931' md #4 CEE ESP power cable w/1" sidepocket 2 7/8" HES 'X' NpI. (2.313" PB) Min. tbg. restriction = 2.313" @ 'X' npl. I Centrilift dart check valve Min. gravel pack ID = 1.791" in 'XN npl. Centrilift FC 925 ESP, I5079' md FPLT ARC, 178 Stg. Stimulation Summary: Centdlift GST DB N Sands FracPacked w/120.6 M# of seal section 20/40 Sand I Centrilift KME1 motor, 82 hp., Perforation Summary: 1230v./38 amp. I Ref. Log: 10/3/90SWSCybedook Centrilift PHD Size SPF Interval ('I'VD) 'N! Sands 4.5" 24 5606' - 5622' (3954'- 3967') ~;~, ~ 7' Baker SC-IL Pkr. @ 5177'md 2 7/8" blank pipe @ 5211' md 4.5" 24 5640'-5666'(3982'-4003') ~~[~~ 2 7/8" Bakerweld12 ga. screen @ 5601' 4.5" 24 5677' - 5684' (4012'- 4017') PBR (2.062" ID) @ 5733' md 4.5" 24 5705' - 5728' (4035'- 4053') 2 7/8" Bakerweld 12 ga.screen @ 5735' 'O' sands ~ 7" Baker 'D' sump pkr. @ 5746' md 4.5"__.. _-5 .......... 5796' - 5834' ,(4109' ............ - 4140') Istuck plug ~ .............. Otis 'XN' Npl. (1.791" no-go) @ 5753' md SandSperfed w/24 gm. EH 43C IAttempted 'O' Sands perfed w/37 gm. HyperJet II (END = 0.49",TTP = 30.25") w/72 deg. ~ ~ k 7" Csg. shoe /L 6206' md Dhasina L DATE REV. BY COMMENTS MILNE POINT UNIT 10/04/90 JBF D & C by Nabors 27E WELL I-I-02 12/24/90 JBF iravel Pack and initial ESP Compl. APl NO: 50-029-22062 09/05/94 JBF ~SP Replacement by Nabors 4ES BP EXPLORATION (AK THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 20.00 E P M L E W A T E R IA L U N D ER TH IS M ARK ER C:LO~LM.DOC ALASKA OIL & GAS CONSERVATION COMMISSION Date: 31 August 1994 Attn. LARRY GRANT RE: Transmittal of Data 3001 PORCUPINE DR. ~ ECC ~: 6263.00 ANCHORAGE ~f~ Sent by: ANCHORAGE EXPRS AK, 99501. USA ~J~ ~0~ ~~ ~0~/k~ata: NONE Prints/Fil~i~a 1 dpDK/GRAVEL FINAL BL Run #' i 1 ~# 1 / ~:r;;;, AK 99518 / Received by STATE OF ALASKA ALA,...,A OIL AND GAS CONSERVATION COMMISS,,..,; REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing x Alter casing Repair well x Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2484' SNL, 4053' WEL, SEC. 34, T13N, RIOE At top of productive interval 3627' SNL, 828' WEL, SEC. 34, T13N, RIOE At effective depth At total depth 3730' SNL, 491' WEL, SEC. 34, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED OCT 1 7 1994 Alaska 0il & Gas Cons. Commission ~ch0ra~o 6. Datum elevation (DF or KB) KBE = 35' feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPH-2 9. Permit number/approval number 90-87/94-141 10. APl number 50- 029-22062 11. Field/Pool Kuparuk River/Schrader Bluff 6230 feet Plugs (measured) 4464 feet 6123 feet Junk (measured) 4393 feet ORIGINAL Casing Length Structural Conductor 71' Surface 3073' Intermediate Production 6169' Liner Perforation depth: Size Cemented Measured depth True vertical depth 13-3/8" Surface 106' 106' 9-5/8" Surface 3108' 2475' 7" TOC @ 4500' (Approx.) 6204' 4443' measured 5606'-5622', 5640'-5666', 5677'-5684', 5705'-5728', 5796'-5834', 5874'-5904' true vertical 3954'-3967', 3982'-4003', 4012'-4017', 4035'-4053', 4109'-4140', 4172'-4197' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 5120' MD Packers and SSSV (type and measured depth) Baker 'SC-IL' Gravel Pack Packer @ 5177' MD, Screens & Model 'D' Packer @ 5746' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify_that the f.oregoing is true and correct to the best of my knowledge. Signed /,/F~ ~~ Title Drillin~En~ineerSupervisor Form 10-404'"Rev 06/15/88 SUBMIT IN DUPLICATE MP H-02 08123194 6,204' MOVE RIG FROM C-14 AND RIG UP. CHECK ANNULUS AND TBG. RIG DOWN TREE. NIPPLE UP BOPS AND CHANGE PIPE RAMS TO 2 7/8". PULL BPV SET TWO WAY CHECK. RIG UP TO TEST BOPS. CHANGE STEM PKG. ON STD PIPE VALVE AND CHANGE OUT CHOKE MANIFOLD VALVE. GOING TO TIGER TANK. TEST BOPS. PULL'TWO WAY CHECK. RIG UP TO CIRC WELL BORE WITH SOURCE H20. 08/24/94 6,204' CIRC DN TBG. RETURNS TO TIGER TANK. JUNKING CRUDE RETURNS. CIRC BACK TO PITS W/CLEAN SOURCE H20. WELL DEAD. BOLDS. PULL HGR TO FLOOR. LD HANGER AND LANDING JOINT. FILL HOLE W/10 BBL. POH AND STAND TBG IN DERRICK. REMOVING ESP CABLE AND BANDS. RU CAMCO AND RIH. CENTRALIZER UNABLE TO ENTER PACKER @5177' ADD BULL NOSE KNUCKLE JT AND RIH. TAG FILL @5670' RIG DN CAMCO. LOAD PIPE SHED W/3 1/2" DP AND 1" CS HYDRIL AND 1 1/2" CS HYDRIL. RIH AND PU 12 JTS. TAG PACKER @5170'. CIRCULATE. CHANGE OUT SHOCK HOSE BETWEEN PITS AND SUB. 08/25/94 6,204' SERVICE RIG, CHANGE OUT SHOCK HOSE BETWEEN SUB AND PITS, REBUILD FILL UP LINE, STING INTO PACKER @5177', CONTINUE IN HOLE, TAG FILL @5670', CBU, REVERSE CIRC AND WASH F/5670-5840', CLEAN RETURNS, PRESS INCREASED WHILE REVERSE CIRC,, REVERSE CIRC @5840', WO XANVIS PILL AND MORE SOURCE WATER, MIX AND PUMP 10 BBL XANVIS PILL W, BREAKER, REV CIRC OUT, SMALL AMOUNT OF FORM SAND, REVERSE CIRC, REV CIRC AND WASH F/5840-5815', RECOVERING FORMATION SAND, PUMP 10 BBL PILL AND CONTINUE WASHING, 08/26/94 6,204' REVERSE CIRC AND WASH, F/5865-5897', PUMP 10 BBL XANVIS PILL, LOST RETURNS WITH PILL @ SURFACE, .PUMP 20 BBL XANVIS PILL, PARTIAL RETURNS, PUMP 25 BBL PILL, NO RETURNS, PUMP 12 BBL PILL. SAME. PUMP 20 BBL PILL. SAME. SHUT DOWN PUMP. FLOW BACK 40 BBL'S TBG AND ANNULUS, WELL STABLE, PULL 1 STAND AND 2 SINGLES, REV, CIRC, BLEED PRESSURE, FLOWED BACK 38 BBL'S, WELL STABLE, OPEN ANNULAR, CIRC DOWN TBG, SPOT 20 BBL XANVIS PILL ON BOTTOM. CIRC 30 BBL'S DN TBG, REVERSE CIRC, RIH TO 5866', PUMP 30 BBL XANVIS PILL. POH. LD 1.5" AND 1" CS TBG. RU ATLAS WIRELINE TO LOG GRAVEL PACK SCREEN. 08/27/94 6,204' RIH W. ATLAS PDK-100/GR/CCL. TIE IN TO SCHLUMBERGER DIL/SFL DATED 10/03/90. LOG F/5750-5150'. SHOWED TOP OF GRAVEL TOP @5480'.. SCHLUMBERGER TDT-P DATED 12/21/90 SHOWED TOP @5459'. NO OBVIOUS VOIDS. WO CAMCO. RU SL. RIH. WORK INTO TOP PACKER. SET DOWN AND WORK PAST SEVERAL SPOTS IN GRAVEL PACK STRING. UNABLE TO GET PAST XN NIPPLE @5741'. POH. RIH. TAG PBTD @5892'. POH. RIH. WORK THROUGH TIGHT SPOTS IN SCREEN. TAG XN NIPPLE. RIH. TAG PBTD. POH. RIH W/SSN PLUG. SET IN NIPPLE. POH. RD ATLAS. RU FLOOR FOR 3/5" DP. SET WEAR RING. STRAP AND MU SNAP LATCH AND JET PUMP. RIH ON 3.5" DP F/PIPE SHED. SLM AND RABBIT PIPE. 08/28/94 6,204' FINISH RIH W/SNAP LATCH AND JET PUMP ON 3.5" DP. STING IN AND SNAP OUT TO VERIFY POSITION. RU BJ F/ACID JOB. TEST ALL LINES, CHOKE AND MANIFOLD. PICKLE SURFACE LINES AND DP W/12 BBL 15% HCL 10% XYLENE DISPLACED TO JET PUMP W/3% NH4CL. REVERSE OUT. PUMP ACID TREATMENT. RD BJ. FLOWED N2 HEAD OFF WELL. WELL DIED. PUMPED .5 BPM DOWN ANNULUS TO KICK WELL OFF. FLOWED WELL. WELL DIED. JET PUMP. 08/29/94 6,204' JET PUMP WELL. BLOW DOWN TEST LINES AND MANIFOLD. LOAD SOURCE WATER IN PITS. UNSTING F/PKR. REVERSE CIRC WELL TO CLEAT TBG. RD TEST LINES. POH AND LD DP. 08/30/94 6,204' FINISH POH & LD 3.5" DP. LD JET PUMP AND SNAP LATCH ASSEMBLY. CHANGE PIPE RAMS TO 2 7/8". TEST. WO CAMCO UNIT. UNIT TIED UP ON 18E. WHILE WAITING; RIG DOWN TEST CHOKE AND MANIFOLD; RU ESP EQUIPMENT RUNNING TOOLS; LOAD AND STRAP COMPLETION EQUIPMENT; AND ADJUST BRAKES ON DRAWWORKS. 08/31/94 6,204' RU CAMCO. RIH W/GS PULLING TOOL. TAG FILL @5731'. POH. RIH W/ HYDROSTATIC BAILER. UNABLE TO WORK INTO PKR. POH AND ADD KNUCKLE JT. RIH AND WORK INTO TOP PACKER. WORK BAILER AND POH. NO RECOVERY. MAKE 8 MORE RUNS W/PUMP BAILER, WITH SOME RECOVERY EACH TRIP. RECOVERED FINES W/SOME FRAC SAND. ATTEMPT HYD BAILER AGAIN. NO RECOVERY. MAKE 8 MORE RUNS W/ PUMP BAILER. RECOVERY ON EACH TRIP. ON EIGHT TRIP, RECOVERED FINES, SOME FRAC SAND, AND SMALL AMOUNT RUBBER. ~,1~~1~~ OCT 1 7 1994 Alaska 0il.& Gas Cons. CommissJor~ Anchora~.,~ PUMP BAILER AND APPEARED FAIRLY CLEAN. BALLED F/5731-5742'. RIH W! GS PULLING TOOL AND EQUALIZING PRONG. 09/01/94 6,204' UNABLE TO LATCH PLUG. POH. RIH W/1.5" PUMP BAILER/ WORK BAILER. POH. NO RECOVERY. RIH W/GS TOOL AND EQ, PRONG. UNABLE TO LATCH. POH. MAKE TWO RUNS W/GS TOOL. UNABLE TO LATCH PRONG. RD CAMCO. WO SCHLUMBERGER E-LINE. RU SOS. RIH W/1 13/16" JET CUTTER/CCL. UNABLE TO GET INTO PACKER TOP @5172' WLM. POH. LOST CHARGE FROM END OF CUTTER. RIH W/BULL NOSE GUIDE ON WT BAR TO 5728' WLM. POH. RIG SOS TO SIDE. PU BAKER SNAP LATCH SEAL ASSEMBLY. RIH ON 2 7/8" TUBING. STING INTO PKR @5170' RKB. VERIFY POSITION. RU SOS. RIH W/ST BAR AND BULL NOSE. HUNG UP @5730'. TRY TO WORK LOOSE. 09/02/94 6,204' WORK W/STUCK WT BAR & BULL NOSE GUIDE. INSTALL LINE CLAMP AND PULL LOOSE W/BLOCKS. POH. RD SOS. WAIT ON SLICK LINE. RU CAMCO. RIH W/1 9" BLIND BOX. BEAT DOWN F/5733-5738'. POH. RIH W/ 1.75" LIB TO 5742'. POH. HAD SMALL CERAMIC PIECES AND DEBRIS. RIH W/1.9" BLIND BOX TO 5745'. POH. RIH W/1.5" BLIND BOX AND WORK DOWN F/5745-5751'. POH. RU ATLAS WL. RIH W/1 13/16" JET CUTTER. TIE INTO SOS TDT-P LOG DATED 12/21/90. STUCK TOOLS @5740'. WORK FREE. STUCK AGAIN @ 5739'. WORK FREE. POH. NO TOOLS LOST. RIH W/1 11/16" TOOL STRING TO 5748'. POH. RIH W/11/16" JET CUTTER. CUT PIPE @ 5748'. ATTEMPT TP BEAT TAILPIPE LOOSE. POH. HOLE FILL STEADY. RIH W/1 13/16" JET CUTTER. CUT PIPE @5748'. ATTEMPT TO BEAT TAILPIPE LOOSE. POH. HOLE FILL INCREASED. PU 2 ADDITIONAL SINKER BARS FOR TOTAL OF THREE. RIH. BEAT ON TAILPIPE. 09/03/94 6,204' POH W/SINKER BARS. RIH W/1 13/16" JET CUTTER. CUT PIPE @5748'. POH. RD ATLAS. RU CAMCO. RIH W/1.5" BLIND BOX TO 5743' WLM. ATTEMPT TO BEAT TBG OFF. POH. RIH W/1.5" BAILER. WORK F/5743- 5745'. POH. BAILER HALF FULL OF SAND, CERAMIC DEBRIS AND RUBBER. RERUN TOOL TO 5745'. POH. TOOL 1/4 FULL OF SAME. RERUN TOOL. POH. DEBRIS UNDER BALL SEAT. NO RECOVERY. RIH W/1.75" BAILER TO 5746'. POH. RECOVERED BRASS, RUBBER AND COPPER. RERUN BAILER TO 5747'. POH. SAME RECOVERY. MAKE 4 ADDITIONAL RUNS TO 5747' W/MINIMAL OR NO RECOVERY. NO INDICATION OF BEING ON PLUG. RIH W/1.5" BLIND BOX TO 5747'. POH. RD CAMCO. RU ATLAS. RIH W/MODIFIED 1 11/16" SILVER JET. TIE IN TO SOS TDT-P DATED 12/21/90. SET DOWN @5756'. PERF 5753.5-5745.5'. POH. RD ATLAS. UNSTING SNAP LATCH. CIRC TO WARM UP WELLBORE. POH W/A2 7/8" TBG. RECEIVED OCT 1 7 1994 Alask~ Oil & Gas Cons. Commissior, Anchora,, ~., 09/04/94 6,204' FINISH POH W/2 7/8" TBG. LS NAP LATCH. PULL WEAR RING. RU TO RUN ESP AND TEST FLUID. CONNECT ELECTRIC CABLES AND TEST CONDUCTIVITY. RIH W/ESP COMPLETION ON 88 JTS 2 7/8" TBG. RU TO TUN RAYCHEM HEAT TRACE. TEST HEAT TRACE. RIH W/ESP COMPLETION. 5 STDS REMAINING. 09/05/94 6,204' SERVICE RIG. FINISH RIH W/2 7/8" ESP COMPLETION. SPACE OUT FOR HEAT TRACE. PU HANGER. MAKE PIGTAIL SPLICE. TEST ESP LINE AND HEAT TRACE. INSTALL TWC. LAND TBG HANGER. RILDS. TEST HANGER. LD LANDING JT. ND BOPE. INSTALL TBG HD ADAPTER. TEST. TEST ESP CONNECTION. NU WKM TREE. TEST. OK. PULLTWC. FREEZE PROTECT ANNULUS W/60 BBL'S DIESEL AND TBG W/12 BBL'S DIESEL. SET BPV. SECURE TREE. FINISH CLEANING PITS. RELEASE RIG @2359 09/04/94. ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 8 September 1994 RE: Transmittal of Data ECC #: 6263.01 Sent by: U.S. MAIL Data: NONE Dear Sir/Madam, Reference: BP MPH-02 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 CCL/TUBCUTR FINAL BL Run # 1 1 CCL/TUBCUTR RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage~ A~99518 · · Received e: Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99508 Meceived by ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 9 September 1994 RE: Transmittal of Data ECC #: 6263.02 Sent by: ANCHORAGE EXPRS Data: NONE Dear Sir/Madam, Reference: BP MPH-02 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: 1 CCL/PERF. FINAL BL Run # 1 1 CCL/PERF. RF SEPIA Run ~ 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorag~AK 99518 Attn ~ney D. Paulson / Receive Date: Pleas~ o~gn and return to: Petrotechnical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99508 ~eeeived by STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operation Shutdown Re-enter suspended well' Plugging Time extension ___ Stimulate ~ Pull tubing x Vadance Perforate _ __ Other _ 6. Datum elevation (DF or KBE = 35~ feet 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Abandon __ Suspend __ Alter casing __ Repair well x Change approved program __ 5. Type of Well: Development x 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2484' SNL, 4053' WEL, SEC. 34, T13N, RIOE At top of productive interval 3627' SNL, 828' WEL, SEC. 34, T13N, R10E At effective depth Exploratory __ Stratigraphic __ Service RECEIVED At total depth 3730' SNL, 491' WEL, SEC. 34, T13N, RIOE MAY 2 7 1994 Alaska 0it & Gas Cons. Commission Anchorage 7. Unit or Property name Milne Point Unit 8. Well number MPH-2 9. Permit number 90-87 10. APl number 50- 029-22062 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured true vertical 6230 feet Plugs (measured) 4464 feet Effective depth: measured true vertical 6123 feet Junk (measured) 4393 feet Casing Length Structural Conductor 71' Surface 3073' Intermediate Production 6169' Liner Perforation depth: Size Cemented Measured depth 13-3/8" 9-5/8" Surface 106' Surface 3108' 7" TOC @ 4500'(Approx.) 6204' measured 5606'-5622', 5640'-5666', 5677'-5684', 5705'-5728', 5796'-5834' 5874'-5904' True vertical depth 106' 2475' 4443' true vertical 3954'-3967', 3982'-4003', 4012'-4017', 4035'-4053', 4109'-4140', 4172'-4197' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 5121'MD Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 6/15/94 16. If proposal was verbally approved Name of app?,~.er Date approved 17. I hereb~hat~/~__)~oi? is ~e and correct to the best of Signed 15. Status of well classification as: Oil x Gas Suspended Service my knowledge. Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so re Plug integrity BO ~r~ Mechanical I~ubs~~._ Approved by order of the Commiss~o Commissioner Form 10-403 Rev 06/15/88 ~oved Copy Returned Date I Approval No.~ ¥._/, ~ I Date SUBMIT~IN ~'RIPLICATE Milne Point H-02 RWO OPERATIONS SUMMARY Obiective: Pull failed electrical submersible pump from well. Perform acid stimulation and flowback with rig and recomplete with new electric submersible pump. , Pre- rig: Pull dummy valve from lower GLM. Circulate crude from tubing with source water. Install BPV. . MIRU Nabors 4ES workover rig. Pull existing 2 7/8" tubing and ESP assembly. . Check PBTD with slickline (a fill cleanout may be performed if excessive fill covers lower perfs). Set plug in XN nipple at 5753'. . Run seal assembly and jet pump on work string. Sting into packer at 5177'. . Pump foamed acid stimulation. Flowback well using rig to pump power fluid (heated source water) to jet pump. 6. Pull work string and L/D seal assembly and jet pump. 7. Recomplete well with new ESP and heat trace on 2-7/8" tubing. 8. RDMO Nabors 4ES. Place well on production. RECEIVED MAY 2_ 7 '~t)~,a ^!aska 0ii & flas Cons. Com[niss,on Anchorage September 23, 1993 Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine DriVe Anchorage, Alaska 99501 RE: MPU H-2; REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Johnston, Attached are duplicate copies of the Report of Sundry Well Operations, Form 10-404, for an acid stimulation job on Milne Point Unit Well H-2, Approval No. 93-211. Please direct any questions or concerns regarding this form to me at 564-7660. Sincerely, SHEAR Specialist Att: cc: BGA, TJY Chevron Occidental H-2 Well File STATE OF ALASKA ALASi~,~ OIL AND GAS CONSERVATION COMMI~..,ON REPORT OF SUNDRY WELL OPERATIONS Operations Performed: Operation shutdown Pull tubing m Nter casing Name of Operator Conoco Inc. Stimulate X Plugging__ Repair well __ Other Address 3201 C Street, Suite 305 Anchorage, AK 99503 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 2484' FNL, 4053' FEL, Sec. 34, T13N, R10E, U.M. NSB AK At top of productive interval 3627' FNL, 828' FEL, Sec. 34, T13N, R10E, U.M. NSB AK At effective depth At total depth 3730' FNL, 491' FEL, Sec. 34, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KI~( KB 35 AGL ~feet 7. Unit or Property name Milne Point Unit 8. Well number H-2 9. Permit number/approval number 90-87 10. APl number 50-029-22062 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured 6230 feet Plugs (measured) true vertical 4464 feet None Effective depth: measured 6123 feet Junk (measured) true vertical 4393 feet None Casing Length Size Cemented Measured depth Structural Conductor 71' 13-3/8" Surface 106' Surface 3073' 9-5/8" Surface 3108' Intermediate Production 6169' 7" TOC@ ± 4500' 6204' Uner Perforation Depth: measured 5606'-5622', 5640'-5666', 5677'-5684', 5705'-5728', 5796'-5834, 5874'-5904' True vertical depth 106' 2475' 4443' true vertical 3954'-3967', 3982'-4003', 4012'-4017', 4035'-4053', 4109'-4140', 4172'-4197' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 5096' MD Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated(measured) 5606'-5904' (Gross) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or InJection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 280 ~-"290 70 200 Tubing Pressure 2OO 2OO 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended 17. I hereby certify that the f~ue and correct to the best of my knowledge. Signed ' ~ /,.b B.G. Auqustine Title Sr. Production En,qineer Form 10-404 Rev 06/15/88 ' Date ~/,~./~' ..~ SUBMR' IN DUPLICATE H-2 ACID STIMULATION 9/2/93: 9/3/93: 9/4/93: ACTIVITY MIRU slickline unit. RIH with kickover tool and locate in mandrel at 4971'. Latch dummy valve and POOH. RDMO slickline unit. Held pre-job safety meeting. MIRU nitrogen unit, acid transports, pump unit, and vac. trucks. Pressure test surface lines to 2500 psi. Pickle the tubing with 15 bbls. of 80:20 DAD with 15% HC1. Reverse out pickle acid with 3% NH4Cl and diesel. Pump the following treatment: 120 bbls. 80:20 DAD with 15% HCL 15% HCL contained: 10 gals./1000 gals. F-75N non-ionic surfactant 5 gals./1000 gals. W-54 demulsifier 20 lbs./1000 gals. L-58 iron stabilizer 3 gals./1000 gals. A-260 corrosion inhibitor 5 gals./1000 gals. W-35 anti-sludging agent 185 gals./1000 gals. xylene 15 gals./1000 gals. U-74 emulsifier 120 bbls. 12% HCl/3% HF 3 gals./1000 gals. F-75N non-ionic surfactant 10 gals./1000 gals. W-54 demulsifier 5 gals./1000 gals. W-35 demulsifier 20 lbs./1000 gals. L-58 iron stabilizer 3 gals./1000 gals. A-260 corrosion inhibitor 50 gals./1000 gals. U-100 mutual solvent The above volumes were pumped in 5 stages with foam diversion between each stage. Final treating pressure was 300 psi. RDMO treating equipment. MIRU slickline unit. RIH with dummy valve and locate in mandrel at 4971'. Set dummy valve and POOH. RDMO slickline unit. Return well to production. Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 August 3, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU H-2; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for an acid stimulation of Milne Point Unit well H-2. Please direct any questions or concerns regarding this application to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Attachment CC: BGA, TJY Chevron Occidental H-2 Well File Alaska Oil & ..... Anchorage STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMMIS,~,,JN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing Repair well Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extention Stimulate X Pull tubing __ Variance Perforate Other__ Name of Operator Conoco Inc. Address 3201 C Street, Suite 305 Anchorage, AK 99503 Location of well at surface 2484' FNL, 4053' FEL, Sec. 34, T13N, R10E, U.M. At top of productive interval 3627' FNL, 828' FEL, Sec. 34, T13N, R10E, U.M. At effective depth 5. Type of Well: Development X Exploratory Stratigraphic Service NSB AK NSB AK At total depth 3730' FNL, 491' FEL, Sec. 34, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35' 7. Unit or Property name Milne Point Unit 8. Well number H-2 9. Permit number 90-87 10. APl number 50-029-22062 11. Field/Pool Kuparuk River/Schrader Bluff feet 12. Present well condition summary Total depth: measured 6230 feet true vertical 4464 feet Plugs (measured) None Effective depth: measured 6123 feet true vertical 4393 feet Junk (measured) Casing Length Size Structural Conductor 71' 13-3/8" Surface 3073' 9-5/8" Intermediate Production 6169' 7" Uner Perforation Depth: Cemented Measured depth True vertical depth Surface 106' 106' Surface 3108' 2475' TOC @ + 4500' 6204' 4443' measured 5606'-5622', 5640'-5666', 5677'-5684', 5705'-5728', 5796'-5834', 5874'-5904' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 5096' MD true vertical 3954'-3967', 3982'-4003', 4012'-4017', 4035'-4053', 4109'-4140', 4172'-4197' RECEIVED Packers and SSSV (type and measured depth) None AU G - G 1993 Alaska Oil & 13. Attachments Description summary of proposal X Detailed operations program BOP sk~l~h~age 14. Estimated date for commencing operation August 15, 1993 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .- B.G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Suspended Date August 3, 1993 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Original Signed By Approved by order of the Commission David W. Johnston Commissioner LApproval No. Approved ,_:opy Returned Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UNIT H-2: ACID STIMULATION SUMMARY PROCEDURE 1 MIRU CTU on well 2 NU BOPE. Test BOPE and surface equipment. 3 RIH to 4970'. 4 Pump acid stimulation Acid Treatment: 120 bbls. 15% HCL (80%) and xylene (20%) with additives 120 bbls. 12% HCL/3% HF with additives 5 Displace acid treatment with 3% NH4CL water 6 POOH coiled tubing 7 RDMO CTU and equipment 8 Return well to production MILNE POINT UNIT H-2 FINAL DRILLING REPORT OPERATOR: CONOCO, INC. WELL: MPU H-2 ~ ~ '~ ~'j FIELD: KUPARUK CASING: 13 3/8" @ 115' 9 5/8"@ 3108 '~1~ Oil 7" ~ 6204' ~lac~'or~C°°s,. MD CURRENT TD: 6230 '"' ~t$810/7 PROGRESS: 0 DATE: Description of Operations: 09-27-90: Move rig from H-1 to H-2. Rig Up. PU rig @ 1000 hrs 09-26-90. MU Steerable BHA. Orient MWD. Drill 115 to 362. 09-28-90: Drill 362 {o 500. Orient 500 to 576. Drill to 1312. Short trip. Drill to 1416. 09-29-90: Drill 1416 to 1880. Short trip. Drill to 2671. Short trip. Drill to 2798. 09-30-90: Drill 2798 to 3126. Circ. Short trip. Circ. POOH. Run caliper survey on E/L to 2288. Unable to get deeper. Rng 9 5/8" csg. 10-01-90: Ran 79 jts, 3065', 36#, K-55, 9 5/8" Butt csg. FS at 3108'. Cmt w/365 BBL Arctic set cmt & 57 BBL G cmt. Disp & bump plug. ND diverter. NU BOP's. Test same. PU 8 1/2" bit & steerable BHA. 10-02-90: RIH. Test csg to 1500 psi. Drill out float equip, cmt, and 10' form to 3136. Run LOT to 12.4 PPG. Drill to 3464. Lost circ. Spot pill. Drill to 4189. Short trip. Drill to 4883. 10-03-90: DRLG from 4883-5138. Pump pill, blow down kelly, short trip 22 stds. DRLG. from 5138-5232. Circulate and condition mud wt. up from 9.0 ppg to 9.3 ppg. DRLG. 5232-6150. Circ. and condition mud trip to shoe (no hole problems) Circulate and condition for logs. POOH. RU Schlumberger. Ran DIL/LDT/CNT/NGT from TD to shoe at 3108. 10-04-90: DRLG from 6150-6230. Circulate and condition mud. POOH for sidewall cores. RU Schlumberger RIH could not get below 3720. POOH with sidewall core gun RD loggers. RIH break circulation at shoe. RIH no fill. Circ bottoms up. POOH laydown drill pipe. Prepare to run 7" csg. 10-05-90: Run 154 jts 7", 26#, L-80, BUTT CSG, total of 6163'. FS ~ 6204'. FC @ 6123'. Cmt w/ 80 BBI G cmt. Bump plug. Test csg to 1500 psi. Install packoff. Test OK. ND BOP's. NU tree. Test OK. Release rig @ 2100 hrs 10-04-90 to H-3. Operations suspended. RIG RECEIVED: 09-26-90 SPUD DATE: 09-26-90 RIG: NABORS 27 ,' DAYS: 9 / 10 FOREMAN: POLYA DATE: 10-05-90 Unoco Inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed Jcord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 June 10, 1993 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Quantity Contents Core Analysis Report Sidewall Descriptions C~OI-~? .~.-2 Final Drilling Report C~1,-_~ --~!-3 Final Drilling Report ¢~ 1-'~'"'I ~.~1-4 Final Drilling Report ~ ~C~i~'!-I Final Drilling Report ¢~1~-~ I ~/~-2 Final Drilling Report C~,,~ ~I-3 Final Drilling Report ~1-3 No Whole Core or Sidewall Cores taken as noted on completion report. ~ 1-~.f~!-4 Final Drilling Report 1 ~!-4A Core Analysis Report 1 , ~'J-1 Final Drilling Report c~01~5 ~.-'I Core Analysis Report Core Description Report ~l.~q/,~-2 Final Drilling Report R E ¢ E IV E ,-, Completion History Final Drilling Report JUN ¢~1~--~J~ Final Drilling Report ~.-~. ~~ Final Drilling & Completion Report ~aS~ Oil & Gas Cons. Commission ~--¢C~'E-8 Final Drilling & Completion Report Anchorage 1 { ~9 Final Drilling & Completion Report C~ .1, JO I ~9 Core Description Report 1 /~ E-9 Core Analysis Report Transmittal Approved By Date Instructions: Please ack. ledge rece~mptly by signing and returning second copy. Received By~~~.~~._ Date Remarks '"June 1b;-Tg~3 Transmittal Copy Only To Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 March 10, 1993 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: Enclosed are magnetic tapes in LIS format for Milne Point Unit wells H-2, H-3, H-4 and I-1. Verification lists for the tapes are also enclosed. The well locations, APl numbers and tapes enclosed are as follows: Well# APl# Location Tape Tape Date Depths H-2 50-029-22062 Sec 34, T13N, R10E OH EDIT 10/25/90 3082.0 - 6208.5 H-3 50-029-22063 Sec 34, T13N, R10E OH EDIT 03/17/91 2825.0 - 5680.5 H-4 50-029-22064 Sec 34, T13N, R10E OH EDIT 03/17/91 2493.5 - 4543.5 I-1 50-029-22065 Sec 33, T13N, R10E OH EDIT 11/14/90 3222.0 - 6248.0 90 -~7 You had also requested two logs for Well No. H-3, titled "4-Arm Caliper" and "Gamma Ray-CCL". We didn't run logs with these specific titles, however, the "Borehole Geometry Log" was run using a 4-Arm caliper tool, and the Gamma Ray curve and CCL may be found on the "Completion Record" Icg. Both of these logs have previously bben provided to AOGCC. To confirm arrival of these data, please sign the second copy of the letter and return it to me at the letterhead address. Should you have any questions, please phone me at 564-7614. Sincerely, Linda M. Starr Technical Assistant cc: SFD ECEIVED Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 December 21, 1992 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Wondzell, Attached are the Reports of Sundry Well Operations, Form 10-404, for recently completed work on Milne Point Unit Wells H-2, G-4 and I-4A. Please note there are two seperate 404 forms for well H-2. Please direct any questions or concerns regarding this form to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Att: cc: CVL, JLA, TJY GDF/FWG, WCD/HDS Chevron Occidental Well Files STATE OF ALASKA ' ALAS. OIL AND GAS CONSERVATION COMMi,..~,ON REPORT OF SUNDRY WELL OPERATIONS ORIGINAL 1. TYI:? of Request: Operation shutdown Stimulate __ Pull Tubing X Alter casing 2. Name of Operator Conoco Inc. 4. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Alter casing Repair well Repair well __ Other ~ ~ 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ KB 35' Exploratory ~ 7. Unit or Property name Stratigraphic__ Milne Point Unit Location of well at surface 2484' FNL, 4053' FEL, Sec.34, T13N, R10E, U.M. NSB AK At top of productive interval 3627' FNL, 828' FEL, Sec. 34, T13N, R10E, U.M. NSB AK At effective depth At total depth 3730' FNL, 491' FEL, Sec. 34, T13N, R10E, U.M. NSB AK 8. Well number H-2 9. Permit number 90-87/92-240 10. APl number 50-029-22062 11. Field/Pool Kuparuk River/Schrader Bluff feet 12. Present well condition summary Total depth: measured true vertical 6230' feet 4464' feet Plugs (measured) Effective depth: measured 6123' feet tr. ue vertical 4393' feet Junk (measured) Casing Length Size Structural Conductor 71' 13-3/8" Surface 3073' 9-5/8" Intermediate Production 6169' 7" Uner Perforation Depth: measured Cemented Measured depth True vertical depth Surface 106' 106' Surface 3108' 2475' TO0@+4500' 6204' ~3' 5606-5622'; 5640-5666'; 5677-5684'; 5705-5728'; 5796-5834'; 5874'-5904' true vertical 3954-3967'; 3982-4003'; 4012-4017'; 4035-4053'; 4109-4140'; 4172'-4197' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 5121' MD Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) None Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation RECEIVED DEC 2 9 1992 /~ias_ka~ Oil .& Gas Cons. ~;~em~~ Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 465 195 33 245 221 238 ~"/ 48 33 210 190 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas, .. Suspended Service 17. I Signed Form 10-404' that ~._~ng is true and correct to the best of my knowledge. Title~'~'~,. Date J. Milne Point Unit H-02 ........ AP' ~'o.: 50-029-22062 Location: Milne Point ield - H-02 Replace Inopez~cive ESP S~Y OF OPERATIONS: 10/25/92: Mob rig from I-4A to H-02. Rig up to kill well: Tbg pressure 300 psi; csg pressure 500 psi. Pump 31 bbls brine down tbg, bullhead 15 bbls, then circulate 269 bbls around. Recovered 139 bbls of oil. N/D tree, N/U BOP's. Pull BPV, install 2-way check and test BOPE to 250/3000 psi. Pull 2-way check and POOH with tubing and ESP. Flat cable damaged 6' above pothead. ESP shaft broke and full of sand. 10/26/92." L/D ESP. Install wear bushing. P/U and TIH with 1" pipe/2- 7/8'' tubing and seal assembly to 5129' MD. Reverse circulate source water and HEC pills to wash sand from 5129' to 5917' - plugged off. POOH with tubing/l" pipe. 1" pipe and 4 joints of 2-7/8" tubing were filled with formation sand. 10/27/92: Clean sand from 1". Found piece of rubber plugging bottom joint of 1". TIH with 1" and tubing to 5908'. Stage HEC pills at a 4/40-bbl rate with brine (reverse circ.) while RIH on singles. Lost returns at 5908' - standpipe and reverse circ. hose plugged with hose lining. Clean-out hoses and attempt to circ. down tubing - no success. Drop ball and shear-out circ. sub and establish circulation - 1" plugged. POOH and clean 1" (found piece of rubber). M/U circ. sub on bottom of 1" and TIH with same. 10/28/92: Finish TIH with tubing to 2 joints above top perfs. Establish reverse circ. at 1BPM (returns at 0.5 BPM). Wash sand to 5920' MD - lost circulation (plugged tubing several times prior but able to regain circ' ). S/O to 5994' with 5K WOB. Drop ball and attempt to shear circ. sub - no success. POOH and clean sand/frac sand from 1" and tubing. TIH with 1" and tubing. 10/29/92: Finish TIH with 1" & 2-7/8" tubing to 5177' (above pkr). Pump pill and CBU at 2.5 - 3 BPM losing ±20-30% returns. TIH to 5845' and wash sand to 5985'. Sting into packer with seal assembly, pressure test backside to 500 psi. Drop ball and shear out circulating sub. Pump 50 bbls "SafeClean", 35 bbl HEC pill and CBU at 4.5 BPM to clean casing. POOH and L/D 1". Pull wear bushing. M/U ESP assembly and RIH with same. 10/30/92: Finish RIH with ESP assembly. Splice pigtail from penetrator to cable. Land hanger and install BPV. N/D BOP's and attempt to N/U tree - alignment pin will not line up with new slot cut in hanger. P/U hanger and line up with alignment pin. N.U tree and test to 5000 psi for 30 min. Freeze protect annulus of H-1 & H-2 wells. Check continuity of ESP penetrator, install cap. Close all tree valves. L/D tubing in derrick. Release rig from H-2 (AFE No. 1477) to G-4 (AFE 1475) at 2100 hrs on 10/29/92. Wait on'winds to lower derrick for rig move. Move rig from H-2 to G-4. RECEIVED DEC Oil & ~a~, Ancho~a~je WELL No. H-2 COMPLETION SKETCH MILNE POINT UNIT (P) APl No.: 50-029-22062 PERMIT No.: 90--87 COMPLETED: 12/24/90 LAST WORKOVER: 10/29/92 WKM 2 7/8" TUBING HANGER W/ "H" PROFILE BPV NOTES: ALL DEPTHS MEASURED RKB = 35' KDB-SL = 37' KDB-GL = 34' RKB = 29.1' POOL 102 2. MAX. ANGLE = 60.5' @ 3929' --157 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBING 3. K.O.P. = 500' 4. SLANT HOLE: YES --ESP CABLE - No. 2 REDA BLACK 5. TREE TYPE: WKM 2 9/16", 5000#, W/ 2 7/8" 8rd TREETOP CONNECTION 6. bllN ID = 1.791" @ 5753' 7. COMPLETION FLUID: 8.6 PPG N(]Cl W/ 12% METHANOL 8. STIMULATION: FRAC (5796'-5904') PUMPED 120,624# OF 16/20 MESH CARBO-LITE 9. ESP ASSEMBLY: REDA DN-800 PUMP WITH 195 STAGES, 75 HP, 1100V/41.SA MOTOR, KGB (;AS SEPARATOR, TANDEM BSLSL PROTECTOR, PSI UNIT 4971' 2 7/8" x 1.5" G/L MANDREL W/ DUMMY 2 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBING 5051' CHECK VALVE 2 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBING ~5121' TOP OF ESP 5175' BOTTOM OF ESP N SAND PERFORATION DATA MD TVD DEPTH: 5606'-5622' 3954'-5967' 5640'-5666' 5982'-4005' 5677'-5684' 4012'-4017' 5705'-5728' 4055'-4053' DENSITY: 24 SPF, 24 GM 0 SAND PERFORATION DATA M__Q TVD DEPTH: 5796'-5854' 4109'-4140' 5874'-5904' 4172'- 4197' DENSITY: 5 SPF, 57 GM 7" CASING @ 6204' 5177' BAKER SC-IL PACKER (4.0" ID) 5211' BAKER 2 7/8" BLANK PiPE (390') 5601' BAKERWELD 2 7/8" 12 ga SCREEN (137', 2.44" ID) GRAVEL PACK (N-SANDS) 20/40 MESH GRAVEL 5733' --5734' 5746' 5753' 5755' 6125' POLISHED BORE RECEPTACLE (2.062" ID) BAKERWELD 2 7/8" 12 9<] TELL-TALE SCREEN (10', 2.44" ID) BAKER MODEL "'D" PACKER (.3.25" ID) OTIS "XN" NIPPLE (1.791" ID) WIRELINE RE-ENTRY GUIDE (2.00" ID) PBTD CONOCO INC. ANCHORAGE DIVISION iAPPROVED BY: HDS/BCA DATE: 11/9/92 DRAFTED BY: CFP CAI) FtI_E: WCOtt2 .t~---., STATE OF ALASKA ALA~,,,~ OIL AND GAS CONSERVATION COMMI~,31ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation shutdown Stimulate __ Alter casing Repair well Pull Tubing __ Alter casing Repair well Other X 2. Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 2484' FNL, 4053' FEL, Sec.34, T13N, R10E, U.M. NSB AK At top of productive interval 3627' FNL, 828' FEL, Sec. 34, T13N, R10E, U.M. NSB AK At effective depth At total depth 3730' FNL, 491' FEL, Sec. 34, T13N, R10E, U.M. NSB AK 5. Type of Well: Development X Exploratory i Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KB 35' 7. Unit or Property name Milne Point Unit 8. Well number H-2 9. Permit number 90-87/92-244 10. APl number 50-029-22062 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured true vertical 6230' feet Plugs (measured) 4464' feet Effective depth: measured 6123' feet true vertical 4393' feet Casing Length Size Structural Conductor 71' 13-3/8" Surface 3073' 9-5/8" Intermediate Production 6169' 7" Liner Perforation Depth: measured Junk (measured) Cemented Measured depth True vertical depth Surface 106' 106' Surface 3108' 2475' TOC @ + 4500' 6204' 4443' 5606-5622'; 5640-5666'; 5677-5684'; 5705-5728'; 5796-5834'; 5874'-5904' true vertical 3954-3967'; 3982-4003'; 4012-4017'; 4035-4053'; 4109-4140'; 4172'-4197' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 5121' MD Packers and SSSV (type and measured depth) None (See Completion Sketch attached) 13. Stimulation or cement squeeze summary Intervals treated (measured) None Treatment description including volumes used and final pressure 14. DEC 2 9 1992 AJaska 0il & Gas Cons. Commissio[~ Representative Daily Avera.cle Production or Injection Data ~rlCJlOi~[j{~ OiI-Bbl Prior to well operation 465 Subsequent to operation 238 ~'~ Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 195 33 245 221 48 33 210 190 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby ce~qxfy that the fo~goil~g is tr~e and correct to Signed~ ev~ lv~~ ~~ Form 10-~4 R /15/~ 16. Status of well classification as: Oil X Gas Suspended the best of my knowledge. Title ~"~ll~ Service Date [ ~.. ~,[. c~ SUBMIT IN DUPLICATE feet WELL No. H-2 COMPLETION SKETCH MILNE POINT UNIT (P), AP1 No.: 50-029-22062 PERMIT No.: 90-87 COMPLETED: 12/24/90 LAST WORKOVER: 10/29/92 ------- WKM 2 7/8" TUBING HANGER W/ "H" PROFILE BPV NOTES: 1. ALL DEPTHS MEASURED RKB = 35' KDB-SL = 37' KDB-GL = .34' RKB = 29.1' POOL 102 2. MAX. ANGLE = 60.5' @ 5929' 157 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBING 3. K.O.P. = 500' 4. SLANT HOLE: YES --ESP CABLE - No. 2 REDA BLACK 5. TREE TYPE: WKM 2 9/16", 5000#, W/ 2 7/8" 8rd TREETOP CONNECTION 6. MIN ID = 1.791" @ 5753' 7. COMPLETION FLUID: 8.6 PPG NaCl W/ 12% METHANOL 8. STIMULATION: FRAC (5796'-5904') PUMPED 120,624# OF 16/20 MESH CARBO-L1TE 9. ESP ASSEMBLY: REDA DN-800 PUMP WITH 195 STAGES, 75 HP, 1100V/41.5A MOTOR, KCS GAS SEPARATOR, TANDEM BSLSL PROTECTOR, PSI UNIT 4971' 2 7/8" x 1.5" G/L MANDREL W/ DUMMY 2 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBING 5051' CHECK VALVE ~ 2 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBING 5121' TOP OF ESP RECEIVED -- 5175' BOTTOMA~/Lr~;tt~fl & Gas Cons, Commlssio Anchorage. N SAND PERFORATION DATA M_ED TVD DEPTH: 5606'-5622' `3954'-3967' 5640'-5666' 5982'-4005' 5677'-5684' 4012'-4017' 5705'-5728' 4035'-4055' DENSITY: 24 SPF, 24 GM 0 SAND PERFORATION DATA 1-VD DEPTH: 5796'-5834' 4109'-4140' 5874'- 5904' 4172'- 4197' DENSITY: 5 SPF, 57 GM 7" CASING @ 6204' 5177' BAKER SC-IL PACKER (4.0" ID) 5211' BAKER 2 7/8" BLANK PIPE (390') 5601' BAKERWEI~D 2 7/8" ,12 9(] SCREEN (137', 2.44" ID) GRAVEL PACK (N-SANDS) 20/40 MESH GRAVEL 5733' POLISHED BORE RECEPTACLE (2.062" ID) --5754' BAKERWELD 2 7/8" 12 90 TELL-TALE SCREEN (10', 2.44" ID) 5746' BAKER MODEL "D" PACKER (,3.25" ID) 5755' OTIS "XN" NIPPLE (1,791" ID) 5755' WlRELINE RE-ENTRY GUIDE (2.00" ID) 6123' PBTD (conoco) CONOCO INC. ANCHORAGE DIVISION iAPPROVED BY: HDS/BGA DATE: 11/9/92 DRAFTED BY: CFP CAD FILE: WCOH2 ~ne~ Point Unit H-02 ' A~ 17o.: 50-029-22062 ,.ocation: Milne Point r~ield - H-02 Replace Inoperative ESP Spud Date: 12/29/90 Rig: EWS #4 Rig Release Date: Drilling Days: Completion Days: Abandon Days: Planned Actual Planned Actual Depth: ' MD ' MD 6 6 Current Operations: Demobilizing EWS Rig #4 from h-2 to G-4 10/25/92: Mob rig from I-4A to H-02. Rig up to kill well: Tbg pressure 300 psi; csg pressure 500 psi. Pump 31 bbls brine down tbg, bullhead 15 bbls, then circulate 269 bbls around. Recovered 139 bbls of oil. N/D tree, N/U BOP's. Pull BPV, install 2-way check and test BOPE to 250/3000 psi. Pull 2-way check and POOH with tubing and ESP. Flat cable damaged 6' above pothead. ESP shaft broke and full of sand. 3.0/26/92." L/D ESP. Install wear bushing. P/U and TIH with 1" pipe/2- 7/8'' tubing and seal assembly to 5129' MD. Reverse circulate source water and HEC pills to wash sand from 5129' to 5917' - plugged off. POOH with tubing/l" pipe. 1" pipe and 4 joints of 2-7/8" tubing were filled with formation sand. 10/27/92: Clean sand from 1". Found piece of rubber plugging bottom joint of 1". TIH with 1" and tubing to 5908'. Stage HEC pills at a 4/40 bbl rate with brine (reverse circ.) while RIH on singles. Lost returns at 5908' - standpipe and reverse circ. hose plugged with hose lining. Clean-out hoses and attempt to circ. down tubing - no success. Drop ball and shear-out circ. sub and establish circulation - 1" plugged. POOH and clean 1" (found piece of rubber). M/U circ. sub on bottom of 1" and TIH with same. 10/28/92: Finish TIH with tubing to 2 joints above top perfs. Establish reverse circ. at 1BPM (returns at 0.5 BPM). Wash sand to 5920' MD - lost circulation (plugged tubing several times prior but able to regain circ.). S/O to 5994' with 5K WOB. Drop ball and attempt to shear circ. sub - no success. POOH and clean sand/frac sand from 1" and tubing. TIH with 1" and tubing. 10/29/92: Finish TIH with 1" & 2-7/8" tubing to 5177' (above pkr). Pump pill and CBU at 2.5 - 3 BPM losing ±20-30% returns. TIH to 5845' and wash sand to 5985'. Sting into packer with seal assembly, pressure test backside to 500 psi. Drop ball and shear out circulating sub. Pump 50 bbls "SafeClean", 35 bbl HEC pill and CBU at 4.5 BPM to clean casing. POOH and L/D 1". Pull wear bushing. M/U ESP assembly and RIH with same. 10/30/92: Finish RIH with ESP assembly. Splice pigtail from penetrator to cable. Land hanger and install BPV. N/D BOP's and attempt to N/U tree - alignment pin will not line up with new slot cut in hanger. P/U hanger and line up with alignment pin. N.U tree and test to 5000 psi for 30 min. Freeze protect annulus of H-1 & H-2 wells. Check continuity of ESP penetrator, install cap. Close all tree valves. L/D tubing in derrick. Release rig from H-2 (AFE No. 1477) to G-4 (AFE 1475) at 2100 hrs on 10/29/92. Wait on winds to lower derrick for rig move. Move rig from H-2 to G-4. Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 October 1, 1992 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached is an Application for Sundry Approval, Form 10-403, for performing a coiled tubing clean-out procedure on Milne Point Unit Well H-2. As a result of a revision to our work plan for H-2, this work supersedes our plans for pulling tubing in this well as indicated on the Application for Sundry Approval that was submitted to you on September 28, 1992. Please direct any questions regarding this applications to me at 564-7660. Tom Yeager SHEAR Specialist Attachments RECEIVED 0 CT - 2 1992 Alaska 0il & 6as Cons. C0mmissip~n ~nchorage cc: Chevron Occidental H-2 Well File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend Operation shutdown Re-enter suspended well m Alter casing __ Repair well m Plugging_ Time extention Stimulate Change approved program __ Pull tubing Variance ~ Perforate Other X Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 2484' FNL, 4053' FEL, Sec. 34, T13N, R10E, U.M. At top of productive interval 3627' FNL, 828' FEL, Sec. 34, T13N, R10E, U.M. At effective depth 5. Type of Well: Development X Exploratory Stratigraphic Service NSB AK NSB AK At total depth 3730' FNL, 491' FEL, Sec. 34, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35' 7. Unit or Property name Milne Point Unit 8, Well number H-2 9. Permit number 90 -87 10. APl number 50-029-22062 11. Field/Pool Kuparuk River/Schrader Bluff feet 12. Present well condition summary Total depth: measured 6230 feet true vertical 4464 feet Plugs (measured) None Effective depth: measured 6123 feet true vertical 4393 feet Junk (measured) Casing Length Size Structural Conductor 71' 13-3/8" Surface 3073' 9-5/8" Intermediate Production 6169' 7" Uner Perforation Depth: Cemented Measured depth True vertical depth Surface 106' 106' Surface 3108' 2475' TOC @ _+4500' 6204' 4443' measured 5606'-5622', 5640'-5666', 5677'-5684', 5705'-5728', 5796'-5834', 5874'-5904' true vertical 3954'-3967,, 3982'-4003', 4012'-4017,, 4035'-4053', 4109'-411~',~.. C2~~-E D Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 5096' MD OCT - 2 1992 Packers and SSSV (type and measured depth) None Alaska 0ii & was 01{s, 13, Attachments Description summaryof proposal X Detailed operations program m BOP sketch 14. Estimated date for commencing operation J October 12, 1992- 16. If proposal was verbally approved Oil X Gas Name of approver Date approved Service 17. I hereby certify thatthe~rue and correct to the best of my knowledge. Signed~J-,~ ~ B. G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test m Location clearance Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. johnston 15. Status of well classification as: Commissioner Suspended Date September 30, 1992 ~p~"oval Noi~ SUBMIT IN TRIPLICATE NOTES: le · · · Se · · MILNE POINT UNIT COILED TUBING CLEAN-OUT PROCEDURE a) AOGCC form 403 has been submitted and is pending approval. b) Hold pre-job meeting to discuss workover procedure and safety and environmental considerations. MIRU Nowcam coiled tubing unit. Spot slop tank and choke manifold. MIRU vacuum truck with 100 bbls. of diesel. Line up to take diesel from vac. truck to the pump on the coiled tubing unit. Pressure test surface equipment to 2000 psi. RIH with coiled tubing, displacing with diesel. Take returns from 1-1/2" x 2-7/8" annulus through choke manifold and into the slop tank. Tag sand fill (AVA assembly at 5060') and reverse circulate diesel to remove fill. Work coiled tubing to space out fill. POOH 30' after every 5' of fill. Clean out to the top of pump at 5097'. Reverse circulate bottoms up. POOH with coiled tubing. RDMO coiled tubing unit. Return well to production. OOT- 2 992 Alaska OJJ .& Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLTCAT]'ON FOR SUNDRY APPROVALS ORIGINAL 1. Type of Request: Abandon Suspend __ Alter casing __ Repair well Change approved program Operation shutdown __ Re-enter suspended well Plugging_ Time extention __ Stimulate__ Pull tubing X Variance __ Perforate Other Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 2484' FNL, 4053' FEL, Sec. 34, T13N, R10E, U.M. At top of productive interval 3627' FNL, 828' FEL, Sec. 34, T13N, R10E, U.M. At effective depth 5. Type of Well: Development X Exploratory-- Stratigraphic ~ Service __ NSB AK NSB AK Datum elevation (DF or KB) KB 35' 7. Unit or Property name Milne Point Unit Well number H-2 9. Permit number 9O-87 10. APl number 5O-O29-22O62 11. Field/Pool Kuparuk River/Schrader Bluff At total depth 3730' FNL, 491' FEL, Sec. 34, T13N, R10E, U.M. NSB AK 12. Present well condition summary Total depth: measured 6230 feet true vertical 4464 feet Plugs (measured) None Rt CEIVED S EP 3 0 ]992 Effective depth: measured 6123 feet true vertical 4393 feet Casing Length Size Structural Conductor 71' 13-3/8" Surface 3073' 9-5/8" Intermediate Production 6169' 7" Uner Perforation Depth: Junk (measured) J~JasJ(a 0ii .& Gas Cons. C0mmissio~, ~,nch0rage Cemented Measured depth True vertical depth Su~ace 106' 106' Sudace 3108' 2475' TOC@ ±4500' 6204' 4443' measured 5606'-5622', 5640'-5666', 5677'-5684', 5705'-5728', 5796'-5834', 5874'-5904' true vertical 3954'-3967', 3982'-4003', 4012'-4017', 4035'-4053', 4109'-4140', 4172'-4197' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 5096' MD Packers and SSSV (type and measured depth) None feet 13. Attachments Description summaryof proposal X Detailed operations program__ BOP sketch 14. Estimated date for commencing operation November 1, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service 17. I hereby certify that the~is true and correct to the best of my knowledge. Signed 'f~"~' ~~-~-~' G' Au~lustine FOR Title~ COMMISSIoNSr' Production Engineer USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test~ Location clearance ~ Mechanical Integrity Test Subsequent form required 10- /'/0~ · Original Signed By David W. johnston Commissioner Suspended __ Approved by order of the Commission Form 10-403 Rev 06/15/88 Date September 21, 1992 IApproval No. / 0 SUBMIT IN TRIPLICATE i · · · · · · · · · 10. MIRU EWS #4 rig. MILNE POINT UNIT H-Z REPLACE INOPERATIVE ESP SUMMARY PROCEDURE Kill well with 8.6 ppg NaCl with 12% methanol. ND production tree. NU BOPE and test. POOH with tubing, ESP, and ESP cable. LD ESP and cable. RIH with 1" CS Hydril stinger on 2-7/8" tubing and tag fill. Reverse circulate out fill, as necessary. POOH with tubing and LD CS Hydril. PU new ESP assembly and cable. bottom of pump at 5150'. ND BOPE. NU production tree and test. RDMO EWS #4 rig. Return well to production. RIH with ESP and tubing. Set ,Alaska 0il & Gas Cons. Comr~issio,~ Anchorage .... ~'-'" STATE OF ALASKA -- ALASKA - AND GAS CONSERVATION C MISSION O~ 16.i.r. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~_.:~$',~ ABANDONED I~ 2. Name of Operator CONOCO INC 3. Address Pouch 340045 Prudhoe Bay, Alaska 99734 SERVICE [] 4. Location of well at surface 2484' FNLx4053'FEL of Sec. 34,T13N,R10E, Umiat At Top Producing Interval 3627' FNLx828' FEL of Same Section A~ To~al Depth 3730' FNLx491' FEL of Same Section 6. Elevation in fee~ (indicate KB, DF, etc.) 6. Lease Designation and Serial 71 KB ~L - 25906 12. Date Spudded ~3. Date T.D. ~eached 9-25-90 10-2-90 17. Total Depth (MD+TVD) ~8.PlugBackDepth(M~D)~ 6230 + 4427 6123 + 4365 ., 22. Type Electric or O~her ho~s ~un DIL, LDT, CNT, NGT 7. Permit Number 90-87 8. APl Number ~o- 029-22062 9. Unit or Lease Name Milne Point Unit 10. Well Number H-2 11. Field and Pool Kuparuk River Field 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 12--24--90 N/A feet MSLI 2 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost YES E~ NO [] NONE feet MD ~ 1800 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13.-3/8 54.5¥~ K-55 35 106 30 NONE 9.~5/8 36~ 26¥~ J-55 L-80 35 35 3108 6204 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) N Sand (24GM) 0 Sand (37 OM) 5506-22 MD/TVD 3952, 24 SPF 5640-66 5677-84 5705-28 MD/TVD 4053, 24 SPF 5796-5834 MI)/TVD 4108, 5 SPF 5874-5904 MD/TVD 4197, 5 SPF 12-1/4 8-1/2 500 sxs Perma - Frost C l102SX8 ArcticSetIV 260 sxs G NONE 386 sxs G NONE 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8 5755 NONE 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT& KIND OF MATERIAL USED 1i9,978~/ 16-20, MESH Carbo Lite Prop. 5796-5904 27. PRODUCTION TEST Date First Production 4-21-91 Date of Test Hours Tested 4-26-91 6 Flow Tubing Casing Pressure Press. 387 0 28. IMethod of Operation (Flowing, gas lift, etc.) Submersible Pump PRODUCTION FOR OIL-BBL I GAS-MCF TEST PERIOD I~ 146 I 8 CALCULATED I~ OIL-BBL GAS-MCF 24oHOUR RATE -v 582 32 WATER-BBL 5 WATER-BBL 20 COP E DATA IHOKESIZE GAS-OIL RATIO 209 I 57 IL GRAVITY-APl (corr) NA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N ONETAKEN .~: C~'/k Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate~;~/j, NAME Top of "N" Sand Top of "0" Sand GEOLOGIC MARKERS MEAS. DEPTH 5506' 5796' TRUE VERT. DEPTH 3952' 4108' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NA 31. LIST OF ATTACHMENTS Plat, Gyro Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~'J~/_~~~ Title Sr. Prod. Foreman Date 4-28-91 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL)or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 04rD8°!7'' 82.85' '40'59" A = 58'08'45" R .-~ 954.95' T = 530.93' L "' 969,11' Y= 6,010,~.29.32 ×= 556,535.91 ~ PROPOSED PAD u_~ 'EXPANSION ° ~ H- (,'~ H-6 H--5 / .3. P~ ~ Y~ 6.009,620.7~ X= 556,~oa.a8 MiLNE PT. VICINITY MAP MILES STATE PLANE COORDINATES ARE ZONE 4. ALL GEOOI~TIC POSITIONS ARE BASED ON N,A,D. 1927, OFFSETS TO SEC'RON LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS, LEGEND EXIST[N(;' wELL 0 PROPOSED WELL AS-BUILT WELL DATA ~.oc^~ ~.,. s~c~o, ~,~ ~'. ~: ,., ,. ~o ~,, u.,,,., WELL PLANT A,S.P. ZONE 4. LATITUDE SEC. LINE NO. COORDS COORDS LONGITUDE OFFSETS -_ H-1 N 1199.75 Y 6,009,889.10 70' 26' 15,600" 254.2' FNL E 879.69 X 556,576,05 14.9' 32' 19.320" 4.070' FEL ,,, H-2 N 126(].28 Y 6,009,94-7.33 70' 26' 16.171" 24.84.' FNL E 879.92 X ' 556,592.64 14.9' ,.32' 18,820" 4.05Y FEI. IlIi -- III H-3 N 1,:t19.75 Y 6,010,004,65 70' 26' 16,734." 24.27' FNL E 879.66 X 556,608.4,6 14.9' 32' 18.343" 4.037' F-EL H-4- N 1380.11 N 6,010,062.74. 70' 26' 17.304." 2369' FNL E 879.70 F.. 556,624.81 149' 32'17.850" 4.020' F'EL iili __ . SURVEYOR'S CERTIFICATE t HEREBY CERTIFY THAT I Am PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF' ALASKA, AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIR- ECT SUPERVISION.AND THAT ALL DIMENSIONS AND c.~ OTHER DETAILS ARE CORRECT. SURVEYED FOR: -~ Cdonoco) DATE: 3-27-91 DRAWN:STOLL WELL CONDUCTOR AS-BUILTS CHECKED', HERRING ~oB No.: ~oo~. H- 1 H- 2, H- 3 &: H- 4- SCALE.; 1" = 3oo' ' I I IalI I - i ii _. I II ._ Milne Point H No. 2 COMPLETION HISTORY Kuparuk River Field - North Slope Borough, Alaska W.I. 1.0 Milne Point H No. 2 CONFIDENTIAL AFE 10-61-1260 Location: 2484' FNL, 4053' FEL, Sec 34, T13N, R10E U.M. NSB AK Location: Bottom Hole 3745' FNL, 541' FEL, Sec 34,T13N,R10E, U.M. 11-28-90: Sand blast pits while preparing location for rig. Mud wt. 9.2 ppg Viscosity: N/A Cum. Cost: $ 704,050 POOL 102 (0-9-1) Drilling Foreman: BRADY 11-29-90: Sand blast pits, coat pits while preparing location for rig move. Mud wt. 9.2 ppg Viscosity: N/A Cum. Cost: $ 709,550 POOL 102 (0-9-2) Drilling Foreman: BRADY 11-30-90: Coat pits while preparing location for rig move. Mud wt. 9.2 ppg Viscosity: N/A Cum. Cost: $ 728,800 POOL 102 (0-9-3) Drilling Foreman: BRADY 12-02-90 & 12-03-90: Allow pits to cure. Mud wt. 9.2 ppg Viscosity: N/A POOL 102 (0-9-6) Cum. Cost: $ 764,668 Drilling Foreman: BRADY 12-04-90: Allow pit coating to cure. Move rig to H-2. Mud wt. 9.2 ppg Viscosity: N/A Cum. Cost: $ 789,848 POOL 102 (0-9-7) Drilling Foreman: BRADY 12-05-90: N/D tree, N/U BOP. Rig accepted 12-04-90. Test choke manifold & pipe rams to 5000 psi. Test blind rams - found door gasket leaking. Perform accumulator test. Attempt to test annular - no success. Install new annular rubber. Mud wt. 9.2 ppg Viscosity: N/A Cum. Cost: $ 832,382 POOL 102 (0-9-8) Drilling Foreman: BRADY 12-06-90: N/U BOP (found ~ 5 gal of fist sized pieces of rubber on top of test plug). Warm new hydril rubber; test annular BOP & tested inside BOP, 500 Lo & 5000 Hi. L/D test tools, install wearbushing. P/U bit/scraper/SDC/2DP & 85 JTS of 2-7/8 TBG. RIH to 6104' - firm tag. Reverse NaCl brine & dilute w/ methanol. Mix & pump dirt magnet pills. Mud wt. 8.6+ Viscosity: N/A Cum. Cost: $ 1,106,565 POOL 102 (0-9-9) Drilling Foreman: BRADY 12-07-90: Pump dirt magnet pill (1/2 bbl dirt magnet in 20 bbl HzO). Pump 20 bbl H20, pump 2nd dirt mag. pill. Displace w/ brine, filter brine returns, junked 70 bbl (pill & contaminated brine). Filter brine in volume pit to suction pits. Blowdown lines. POOH, L/D 4-3/4" drill collars. R/U wireline. Run GCT f/ 6050' to surface. R/U lubricator. ~]~~%F~PF, 37 J K! 1 91991 Alaska Oil & Gas Cons. Commission Anchorage Milne Point H No. Completion History Page 2 gm, deep penetrating perf. guns. Tie-in w/ GR/CCL (Cyberlook logs used for correlation). Shoot f/ 5826' - 5834'. POOH. R/U for second run, found CCL not working, repair same. RIH w/ gun #2 (same specs) shoot f/ 5874' - 5904'. RIH w/ gun #3 & shoot f/ 5796' - 5826'. R/D wireline unit & R/U Dowell standpipe. P/U Baker Model FHL hydraulic set PKR w/ shear out sub & RIH rabbiting TBG. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,131,57 POOL 102 (0-9-10) Drilling Foreman: BRADY/MARTIN 12-08-90: Finish RIH w/ TBG & PKR; mix linear gel Place PKR @ 5574' drop ball & press up to 1000 psi - PKR set. Press up to 2500 psi & release shear out sub. Test annulus to 500 psi. R/U Schlumberger lubricator, flow cross & treating lines. Attempt to test lines, could not start #4 turbine (probably a bad Woodward). Press test lines to 6500 psi. RIH w/ GR/CCL/PTSA & log f/ 5600' to 6050', POOH. Perform step/rate test as per procedure, max rate: 20.2 bpm @ 3900 psi w/ WF10; possible frac @ 1880 psi, 8 bpm. Perform data frac. Pump 163 bbls of YF-140 w/ R.A. Mtl crosslinker & 5% diesel. Max Rate 10.5 bpm @ 4860 psig. Stopped RA & X-linker, 12 bpm @ 4600 psi. Switch to diesel @ 10 bpm & 4600 psi - flushed TBG. Note: BHP 2924 psi w/ TBG press 4903 psi @ 10.73 bpm indicating very high friction pressure; log perfs w/ Schl. Freeze protect, set up for frac, test gells mix OSR. Determine max treating press, inspect piping, R/D Schl. Note GR indicates R.A. Mtl went to upper lobe of "O" sand. Pump frac. Max rate 25 bpm @ 6413 psig. Final sand stage 12#; total sand 120,624#. ISIP = 832 psig. R/D D.S.; allow gels to break. 12-09-90: R/U gauge on Dowell valve; 680 psi @ 0030, 730 psi @ 0230. Bleed pressure to zero. Pull 34,000#s over string weight. PBR released. Attempt to reverse circulate. Pop-off valve washed out. Attempt to circ. Failed due to Pop-off valve. L/D PUP JT, 3 JTS 2-7/8" TBG. R/U TIW valve & hose. Attempt to reverse circ - failed. Pump down TBG holding 100 psi on backside, 200 psi on TBG @ 1.2 bbl/min (124 bbl total). Shut well in. Monitor casing press - 200 psi. R/U slickline to tag fill. RIH w/ wireline. Tag fill @ 5540'. POOH & R/D wireline. Monitor CSG press, 200 psi. Change out MI filter truck. Filter 133 bbls brine. Circ well @ 1.2 bpm. 200 psi on TBG, 100 psi on backside. Monitor open hole. Well flowing @ ±4 gal/min. Shut in well & monitor pressure. Well had 100 psi after 1 hour. Circ well @ 1.2 bpm w/ 200 psi on TBG, 100 psi on backside. RECEIVED ! 9 A!ask-a Oil & Gas Cons. Commission Anchorage Milne Point H No. 2 Completion History Page 3 12-10-90: Finish circ well @ 1.2 bpm (1 complete circulation) Monitor well. Well flowing @ 2.4 bbl/hr. Shut well in. 0 psi on gauge. Open well and attempt to bleed down. Well flowing @ 2.1 bbl/hr. Circ 1/3 of total system. MI fluids generator broke down. Observe well. Well dead. Pull Baker PKR, 2-7/8" TBG out of hole. P/U 2-7/8" bailer assby & TIH. Tag fill @ 5516'. Assby: saw-tooth collar, flapper valve, 20 JTS 2-7/8" TBG, Safety JT, Bailer, Ported PUP JT, 2-7/8" to surface. Bail sand from 5516' - 5649' Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,556,922 POOL 102 (0-9-13) Drilling Foreman: KOTARA/MARTIN 12-11-90: Bail frac sand from 5649'- 5679'. POOH. Retrieved 1 bbl frac sd (2-1/2 stands 2-7/8" TBG). Inspect bailer/float valve. TIH w/ bailer & tag fill @ 5543'. Bail frac sand from 5543'- 5733'. POOH. Retrieved 2 bbls frac sd (5-1/2 stands 2-7/8" TBG). TIH w/ bailer. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,590,584 POOL 102 (0-9-14) Drilling Foreman: KOTARA/MARTIN 12-12-90: TIH w/ bailer Tag fill @ 5600'. Bail from 5600'-5790'. Pick up and le~ sand settle 5-10 min. for each 30' JT. Short trip to 5600' & wait 30 min. RIH & tag fill @ 5790'. POOH. Retrieved 3.2 bbls sand. L/D 2-7/8" bailer. P/U 4-5/8" bailer, flapper & M/U crossovers. TIH w/ 4-5/8" bailer & 40 JTS 3-1/2" D.P. for cavity. Run in w/ 2-7/8" TBG as workstring. Tag fill @ 5674'. Bail frac sand from 5674'- 5884'. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,646,943 POOL 102 (0-9-9) Drilling Foreman: KOTARA/MARTIN Rig days corrected, subtracted 6 days for location work and cleaning pits. 12-13-90: Bailer full @ 5884'. Wait 30 min. for any sand to settle. Tag bottom @ 5884'. POOH. Retrieved ~ 8 bbls sand. Cavity was full up to bailer. Well started flowing. Shut in. Pressured up to ± 10 psi. Open well & bleed off. TIH to 190' & circ B/U (Had gotten a sample of 7.1 ppg oil back. Circ B/U at surface to see if oil had migrated to surface. Returns were 8.6 ppg brine). Well dead. Found blind rams leaking while blowing down kill line. Change out blind rams. Break bailer/flapper valve down to check seals. OK. TIH w/ 20 stds 3-1/2" D.P. Steam frozen frac sand out of some stds that had not been completely emptied. TIH. L/D 8 jts 2-7/8" TBG from galled threads. Tag sand @ 5852'. Bail from 5852'-5993'. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,672,158 POOL 102 (0-9-10) Drilling Foreman: KOTARA/MARTIN Milne Point H No. Completion History Page 4 12-14-90: Bail sand from 5993'-6100'. POOH. Retrieved 9 bbls sand. P/U bit & TIH. Tag bottom @ 6098'. R/U to reverse circ. Reverse circ & filter brine thru MI unit. Circ 1-1/2 times hole vol. P/U to ± 5700' (100' above top perforations). Circ & Filter brine. POOH. L/D 3-1/2" D.P. R/U Schlumberger Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,722,084 POOL 102 (0-9-11) Drilling Foreman: KOTARA/MARTIN 12-15-90: Finish R/U Schlumberger. P/U Baker Model "D" sump PKR. RIH on Schlumberger and set @ 5746'. POOH. P/U Baker seal assby, collet locator, perf. guns (138.18' total), firing head, HRS tools (champ PKR, safety JT, omni valve). P/U 8 DC's, 2-7/8" TBG and RIH w/ TCP assby. Tag sump PKR @ 5746'. Run seal assby thru PKR and locate collet. Space out. Set champ PKR. Test lines to 1000 psi. 12-16-90: Circ 27 bbls diesel down TBG to get 300 psi underbalance. Drop bar & fire guns. Opened well. Flowed 21 bbls diesel back in 30 min. FTP 90 psi. Shut well in. ISIP - 160 psi. In 20 min SIP rose to 270 psi. Cycle omni valve into circ position. Rev circ 65 bbls (2 TBG volumes). Got back ± 24 bbls crude oil. Unseat champ PKR. POOH w/ TCP assby. Found TCP assby parted at Otis shear sub. Wait on fishing tools. P/U 3-5/8" overshot grapple & RIH. Tag fish @ 5524'. Lower onto fish and P/U. POOH w/ fish. 12-17-90: Retrieved fish & L/D same. P/U TCP assby #2. RIH w/ TCP assby on 2-7/8" TBG. Tag sump PKR @ 5746'. Attempt to sting into sump PKR. Seal assby would not go into sump PKR. POOH w/ TCP assby. M/U wash assby - 2-3/8" stinger, seal assby, 2- 7/8" PUP JT, XO, 3 junk baskets in tandem, DC's, jars, 3-1/2" DP. TIH to wash over/thru sump PKR @ 5746'. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,800,142 POOL 102 (0-9-14) Drilling Foreman: KOTARA/BURMAN 12-18-90: Finish TIH. Tag sump PKR @ 5746'. Sting thru sump PKR. Circ on top/bottom of sump PKR. No problems getting thru PKR. POOH w/ wash assby. P/U TCP assby. TIH. Tag sump PKR @ 5746'. Sting in seals. OK. Locate w/ collet and mark spot to perforate. Set champ PKR. Test lines to 3500 psi. Pump 27 bbls diesel down TBG to get 300 psi underbalance. Pressure up on TBG to 2100 psi (pressure to activate Schlum. firing head). Bleed off. Pressure up to 3100 psi to open production valve. Bleed off pressure. Note guns were designed to fire 21 min. after 2100 psi pressure was applied. Wait 45 min. No RECE VE~ guns fired. Drop bar down TBG. No guns fired. Pump down TBG. Pressure held @ 1000 psi. Pressure up to 2000 psi on annulus to cycle omni ball valve. Press up on TBG to 1000 psi 3U~ ~ 9~ - still holding. Pressure up on annulus to 3500 psi to cycle AnChorage Comm~s~t~ Milne Point H No. 2 Completion History Page 5 omni valve - no indication of movement. Press up down TBG to 1000 psi - no bleed off. Prepare for slickline run to recover Schlum. bar. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,832,648 POOL 102 (0-9-15) Drilling Foreman: KOTARA/BURMAN 12-19-90: R/U wireline unit. GIH & retrieve firing bar @ 5458' wlm. Note: this depth correlates to omni valve depth. Attempt to open annular ports on omni valve. Cycle tool 12 times w/ 2000 psi on annulus. Ports did not open. POOH wet w/ diesel in TBG. Clear pipe shed. L/D Schlum. guns & check Baker seal assby. OK. Clean diesel from rig floor & cellar area. P/U TCP assby. Change out omni valve w/ Halliburton APR-M circ valve. P/U new champ PKR safety JT. TIH w/ 2-7/8" TBG. Fill lower 900' w/ brine & upper 4600' of TBG w/ diesel for 300 psi underbalance. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,850,692 POOL 102 (0-9-16) Drilling Foreman: KOTARA/BURMAN 12-20-90: TIH w/ TCP assby. Tag sump PKR @ 5746'. Space out. Set champ PKR @ ± 5503'. R/U surface test manifold. Test equipment to 3500 psi. Test annulus to 500 psi. Pressure up to 2100 psi on TBG to activate guns. Wait 15 minutes. PresSure up to 2800 psi to open production valve. Guns fired @ 11:50 a.m. Perf interval @ 12 SPF: 5605'-5622' 5640'-5666' 5677'-5684' 5705'-5728' Flow back 20 bbls diesel in 21 min. Shut well in. Pressure up on annulus to 2500 psi. Reverse circ w/ 8.6 ppg brine. Make 1 full circ filtering fluid. Unset champ PKR. POOH w/ TCP assby. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,882,221 POOL 102 (0-9-17) Drillinq Foreman: KOTARA/BURMAN 12-21-90: P/U gravel pack assby and TIH. Snap in the out of sump PKR; SCl setting depth = 5177'. Space out; drop ball. Test lines to 3500 psi. Pressure up to 2500 psi to set PKR. Pressure up annulus to 1500 psi & shift hydraulic release. Press up to 2800 psi to shear out ball. Pickle TBG w/ 10 bbls gel, 5 bbls Super Pickle w/ 7 bbls of 15% HCL followed by 18 bbls of brine @ 4 bpm. Reverse out acid into tank w/ caustic solution. Attempt to determine circulation press through upper circ port. 0 psi @ 1/2 bpm, 50 psi @ 1 bpm, 180 psi @ 2 bpm - formation taking fluid. Attempt injection test. 80 psi @ 1 bpm, 230 psi @ 2 bpm. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,979,035 POOL 102 (0-9-18) Drilling Foreman: BRADY/BURMAN Milne Point H No. 2 Completion History Page 6 12-22-90: Pump prepack of 5 bbl gel; 22 bbl of sand slurry; shift XO to squeeze position & pump 16 bbls of brine (slurry @ XO). Pump 29 additional bbls of brine. Pump 2.5 bbls of diesel, S/I press 509 psi. P/U & reverse out 50 bbls. Pump 5 bbls of gel; 20 bbls slurry, shift to lower circulation path - could not pump. Shift to upper circulation path - pumped 5 bbls slurry, 5 bbls postpad followed by 11 bbls of brine. Screened out @ 1800 psi. Reverse out TBG, recovered approx. 10 bbl of slurry. Inject 340 bbls of gel-diesel-brine followed by 50 bbls of diesel while waiting on gels to break. Return to squeeze position & press up to 1000 psi. Press dropped to 975 psi after 2 min. R/D Howco. Complete injection of waste into 9-5/8" x 7". POOH. L/D washpipe & gravel pack XO. R/U Schlum. & RIH w/ bullnose/spangs/CCL - break isolation disk @ 5744'; tagged soft fill @ 6050'. RIH w/ TDT-PL & CCL, attempt to log - tool failure; POOH. P/U backup tools, RIH & log f/ 5740' to 5160'. Good pack indicated across screens & upto 5458' (139' above top of screen) R/D Schlum. RIH w/ 4-3/4" DCs & drill pipe; POOH L/D pipe. 12-23-90: L/D drill pipe & excess TBG. P/U ESP. Fill pump w/ oil; splice cable @ pump. RIH w/ 2-7/8" TBG. Perform continuity check each 1200'. AVA ported nipple placed 1 jnt above pump. 12-24-90: Finish running 2-7/8" tbg. Land tbg hgr; attempt to test seals - no success. PU. Found tbg hgr seals damaged; redress hgr. Land tbg hgr; test tbg hgr. N/D BOP; N/U tree. Test tree to 5000 psi. Pump 60 bbls of diesel into annulus. Install BPV. Clean pits; inject waste & freeze protect. Rig released @ 1900 hrs to H-3. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 2,338,830 POOL 102 (0-9-21) Drilling Foreman: BRADY/BURMAN ORIGINAL SUB - S URFA CE DIRECTIONAL SURVEY ~-~ UIDANCE ~ ONTINUOUS ~'~ OOL Company CONOCO INC. Well Name MPU H-2 (2484' FNL, 4053' FELf,,SEC 34r T13Nr R10N) Field/Location SCHRADER BLUFF~ NORTH SLOPEr ALASKA Job Reference No. 74234 Loqqed By' FORMICA MICROFILMED Date 6-DEC-90 Computed By: SINES GCT DIRECTIONAL SURVEY CUSTOMER LISTING F3R CONOCO INC. MILNE POINT UNIT H-2 SCHRADER BLUFF NORTH SLOP: ALASKA SURV,EY DATE: 6 DEC 90 ENGINEER: FORMICA METHODS OF COMPUTATION TE;OL LDC~TION: TANGENTI&L- ~VER~GED DEVIATION AND AZIMUTH INTERPOLATION: LINE&R VERTICAL SECTION: HORIZ. OIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH TO DEG ~1 MIN E~ST CgMPUTATI3N CONOCO INC. MZLNE POINT UNIT H-Z SCHRADER BLUFF NORTH SLOPE~ ALASKA INTERPOLATED VALUES FOR TRUE SUB-SEA NEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -72.00 100o00 100.00 28.00 Z00.00 200.00 128.00 300.00 300.00 228.00 400.00 399.97 327.97 500.00 ¢99.89 427.89 600.00 599.40 527.40 ?00.00 698.33 626.33 800.00 796.79 724.79 900.00 894.76 B22.76 1000.00 9'~1.81 91q.81 1100.00 1086.96 1014.96 1200.00 tl80.1t 1108.13 1300.00 1269.97 1197.97 1400.00 1357.02 1285.02 1500.00 1442.50 1370.50 1600.00 1524.57 1452.57 1700.00 1604.07 1532.07 1800.00 1680.58 1608.58 1900.00 t754.27 1682.27 ZO00.O0 1825.Z6 1753.26 2100.00 189,.15 1822.15 2200.00 1965.27 1~93.27 2300.00 2030.00 1959.00 2400.00 20~7.57 2015.57 2500.00 2140.99 206B.99 2600.00 2195.53 2123.53 2700.00 2251.86 2179.36 2800°00 2305.47 2233.47 2900.00 ~359.86 2Z87.86 3000.00 2414.95 2342.95 3100.00 2470.03 2398.03 3200.00 2527.06 2455.06 3300.00 2586.85 2514.85 3400.00 2647.9~ 2575.94 3500.00 2708.59 2636.59 3600.00 2766.12 2694.12 3700.00 2818.45 2746.45 3800.00 2868.54 2796.54 3900.00 2918.53 2846.53 COURSE DEVIATION A[IMuTH DEG HIN DEG 0 0 0 8 0 18 0 21 1 17 7 3 9 21 10 50 12 24 15 19 23 28 29 32 36 38 41 ~3 48 39 5 36 57 59 15 3~ 26 15 46 33 45 7 46 1 52 29 56 47 58 6 55 20 56 45 57 48 56 39 56 ~5 55 53 54 55 52 38 52 20 53 15 56 38 59 52 59 49 60 20 DAT~: 20-" *':CF ':J 0 EVEN 100 VERTICAL SECTION FEET N 0 0 E 0.O0 S 48 5g W -0.07 S 2 2~. E 0.00 S 15 4 E 0.25 S 51 11 E 1.33 S 64 55 E 5.70 S 70 41 E 15.30 S 73 24 E 29.73 S 74 59 E 47.22 S 75 18 E 67.16 S 74 35 E 91.08 S 14 53 E 121.70 S 75 6 E 157.92 S 74 14 E 201.56 S 73 43 E 250.67 S 74 5 E 302.54 S 73 45 E 359.54 S 73 6 E 420.11 S 72 53 E 484.41 S 72 10 E 551.94 S 71 51 E b22.32 S 71 47 E 694.76 S 71 41 E 765.05 S ?0 44 E 841.18 S 69 49 E 922.88 S 68 50 E 1007.38 S 68 52 E 1091.15 S 68 I~- E 1173.70 S 67 19 E 1258.03 S 66 55 E 1341.76 S 66 37 E 1425.05 S 66 ZO E 1508.25 S 65 5~ E 1590.12 S 64 56 E 1669.92 S 64 43 E 1743.69 S 6t 9 E 1827.62 S 62 ~0 E 1908.64 S 52 3~, E 1993.01 S 62 42 E 207B.73 S 63 5!3 E 2164.54 ~:EET DOGL SEVE OEG/ 0 0 0 0 1 3 3 1 1 2 3 4 3 1 3 2 3 2 1 2 7 2 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: OF MEASURED DEPTH EG RECTANGULAR RITY NORTH/SOUTH 100 FEET .00 O.OO N .30 0.01 S .01 0.41 S .33 0.93 S .23 1.93 S .07 4.07 S .~1 7.61 S .84 12.00 S .51 16.73 S · 52 21.80 S .83 28.05 S .55 36.18 S .72 45.49 S · 17 57.13 S .39 70.65 S .05 85.10 S .78 100.84 S .29 118.21 S .61 137.02 S .87 157.29 S .61 179.07 S .29 201.72 S .26 223.70 S .68 2~8.22 S .83 275.77 S .39 305.70 S .14 335.98 S .48 366.17 S .73 398.22 S .74 430.91 S DEC 72.00 F-T F(]RMIC~' 86.68 E 91.11 S 72 4 E 116.27 E 121.77 S 72 43 E 151.40 E 15B.08 S 73 16 E 193.55 E 201.82 S 73 33 E 2~0.B5 E 251.00 S 73 39 E 290.76 E 302.96 S 73 41 E 345.64 E 360.05 S 73 44 E 403.74 -' 420.69 S 73 41 E 465.27 E 485.03 S 73 35 E 529.73 ~_ 552.59 S 73 28 E 596.67 E 622.96 S 73 18 E 665.50 E 695.40 S 73 8 E 732.27 E 765.6(3 S 73 1 E 804.35 E 8.1.78 S 72 51 E 881.26 E 923.40 S 72 37 E 960.31 E 1007.80 S 72 21 E 1038.43 E 1091.47 S 72 4 1115,36 E 1173.93 S 71 50 1193.49 E 1258.17 S 7l 33 E 1270.76 E 13~,1.83 S 71 16 E 0.71 4 63.8~, S 2.61 497.21 S 2.24 530.42 S 0.63 563.84 S 1.69 597.34 S 2.49 632.48 S 4.24 659.71 S 1.8B 708.86 S 0.94 74B.44 S 3.74 787.86 S 1347.47 E 1425.07 S 71 0 E 1423.94 E 1508.25 S 70 45 E 1499.05 E 1590.13 S 70 31 E 1571.90 5 1669.97 S 70 16 E 1643.63 E 17~8.81 S 70 2 E 1714.95 E 1827.86 S 69 45 E 1797.75 E 1909.0B S 69 28 E 1863.43 E 1993.71 S 69 10 E 1940.40 E 2079.7~ S 6~ 54 E 2017.51 E 2165.88 S 68 40 E COORDINATES HORIZ. DEPARTURE EAST/WEST DIST. AZIMUTH FEET FEET DEG MIN CONOCO INC. MZLNE POINT UNIT SCHRADER BLUFF NORTH SLOPE, ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 4000.00 2967.52 4100.00 3016.35 4200.00 3066.99 4300.00 3118.75 4400.00 3169.09 4500.00 3218.35 4600.00 3268.50 4700.00 3319.82 4800.00 3373.16 4900.00 3430.55 5000.00 3493.17 5100.00 3561.31 5200.00 3634.91 5300°00 3711.88 5400°00 3790.80 5500.00 3871.14 · 5600.00 3952.09 5700.00 4,033.¢8 5800.00 4,114,.85 5900.00 4,196.25 COMPUTATION D&TE: INTERPOLJ, TED VALUES FOR SUB-SEA VERTICAL DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MEN 2895.52 60 45 S 66 27 E 2944,.35 60 10 S .67 13 E 299¢.99 58 59 S 69 20 F_ 3046.75 58 59 S 73 4 E 3097.09 60 44 S 75 55 5 3146.35 59 59 S 75 37 E 3196.50 59 48 S 75 7 E 3247.82 58 12 S 75 37 E 3301.16 56 42 S 75 55 E 3358.55 53 17 S 75 55 E 3~,21.17 34,89.31 3562.gl 3639.'~8 3718o30 3799.14 3880.09 3961.¢8 4042.85 4124.25 49 16 S 76 44 42 S 76 40 44, S 76 38 53 S 76 37 2 S 75 36 8 S 74 35 45 S 74 35 25 S 72 35 39 S 72 35 30 S 72 18 E 18 E 33 E 51 E 43 E 3 E 43 E 365 25 E 2 O-"' ~C,FgO EVEN 100 VERTICAL SECTION FEET 2251.36 2338.47 2424.55 2510.09 2596.29 2682.95 2769.18 2854.74 2938.99 3020.52 309B.08 3170.37 3238.25 3301.78 3362.84 3480.74 3538.79 3596.86 3654.97 KELLY FEET OF MEASURED DEPTH DOGLEG RECTANGULAR SEVERITY NORTH/SOUTH OEG/IO0 FEET 1.67 8Z3.98 S 2.55 858.2'3 S 3.82 890.65 S 2.29 918.00 S 2.52 941.25 $ 1.2~ 962.33 S 0.21 984.2~ S 1.09 1006.06 S 3.83 1027.06 S 4.36 1046.93 S 6000.00 4277.70 6100.00 ~358.92 610~.00 4,362.16 420 5.70 35 35 S 4286.92 35 43 S 4290.16 35 43 S 72 16 72 17 72 17 3712.!~6 3771.44 3773.78 4.58 1065. 5.14 1082. 3.38 1098. 1.61 1113. 1.42 1128. 0.88 -.1143. 0.45 1159. O.1Z 1175. 0.53 1193. 0.18 1210. 1.01 1228. 0.00 1246. 0.00 1246. DATE OF SURVEY: 3USHINS ELEVATION: ENGINEER: P'--E 2 6 DEC ~0 72.00 F[ FORMICa' COORDINATES HDRIZ. DEPARTURE EAST/WEST DIST. AZIMUTH ;E6T FEET DEG MIN 2096.85 E 2252.93 S 68 33 E 2177.13 E 2340.20 S 6~ 29 E 2257.00 E 2426.38 S 68 28 E 2338.06 E 2511.82 S 2421.25 E Z597.77 S 68 45 2505.69 E 2684.13 S 68 59 E 2589.37 E 2770.13 S 69 11 2672.39 E 2855.49 S 69 22 2754.~2 E 2939.58 S 69 33 E 2833.74 E 3020.95 S 69 43 E 3098.39 S 69 53 E 3171.08 S 70 2 E 3238.39 S 70 10 E 3301.86 S 70 17 E 3362.B8 S 70 24 E 3422.22 S 70 29 E 3480.75 S 70 33 E 3538.80 S 70 36 E 3596.86 S 70 38 E 3654.97 S 70 39 E 50 S 2909.42 E 80 S 2980.48 E 87 S 3046.25 E 87 S 3108.31 E 31 S 3167.95 E 41 S-3225.55 E 18 S 3282.06 E 91 S 3337.71 E 23 S 3393.17 E 69 S 344,8.63 E 35 S 3503.89 E 3712. 19 S 3559.61 E 3771. 90 S 3561.83 E 3773. S 70 41 E S 70 42 E 78 S 70 42 E CONOCO INC. MILNE POINT UNIT H-Z SCHRADER BLUFF NORTH SLOPE, ALASKA C5MPUTATION DATE: 2O-r'cC~90 P^";E t DATE OF SURVEY: ~ DEC 90 KELLY BU'~HING ELEVATION: 72.00 Fi' ENGINEER: FORMICa' INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED 3EPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HSRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/100 FEET FEET FEET BEG MIN 0.00 0.00 -72.00 0 0 1000.00 991.81 919.81 15 48 2000.00 1825.26 1753.26 46 33 3000.00 Z414.95 2342.95 56 45 4000.00 2967.52 2895.52 60 45 5000.00 3493.17 3~21.17 49 16 6000.00 ~277.70 4205.70 35 35 6104.00 6362.16 4290.16 35 43 N 0 0 E 0.00 S 74 35 E 91.08 S 71 51 E 622..32 S 66 37 E 1425.05 S 66 2Z c: 2251.36 S 76 22 ~: 3098.08 S 72 16 E 371Z.96 S 72 17 E 3773.78 0.00 4.83 2.61 0.71 I. 67 4.58 1.01 0.00 0.00 N 0.00 E 0.00 N 0 0 E 28.05 S 86.68 E 91.11 S 72 4 E 179.07 S 596.67 E 622.96 S 73 18 E ¢63.8¢ S 1347.47 E 1425.07 S 71 0 E 823.93 S 2096.85 E 2252.93 S 63 33 E 1065.50 S 2939.4Z E 30:)8.39 S 69 53 F 1228.35 S 3503.89 E 3712.96 S 70 41 ) 12&6.90 S 3561.83 E 3773.78 S 70 42 ,., COMPUTATI3N DAT6: CONOCO INC. MILNE POINT UNIT H-2 SCHRADER BLUFm NORTH SLOPE, ALASKA INTERPOLATED VALUES FOR EVEN 100 TRUE SUS-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE VERTICAL D~VIATI,3N AZIMUTH SECTION DEG MIN DEG MIN FEET 0o00 0.00 -72.00 72.00 72.00 0.00 172.00 172.00 100.00 271,99 272.00 200,00 372.0! 372,00 300,00 472,03 472,00 400,00 572.41 572.00 500.00 673.35 672.00 600.00 774.77 772.00 700.00 876.73 872.00 :~00.00 0 3 6 8 10 11 0 0 N 0 0 E 0.00 0 6 S 83 51 W -0.04 0 17 S 3 31 W -0.05 0 18 S 11 51 E 0.17 58 S 41 52 E O.B4 10 S 62 58 E 3.90 10 S 69 21 E 12.14 52 S 72 50 E 25.55 26 S 74 42 E 42.56 52 S 75 27 E 62.26 979.50 972.00 900.00 1084.15 1072.00 1000.00 1191.15 1172.00 1100.00 1302.32 1272.00 1200.00 1417.35 1372.00 1300.00 1535.58 1472.00 1400.00 1659.32 1572.00 1500.00 1788.60 1672.00 1600.00 192Z,. 38 1772.00 1700.00 2068.25 1872.00 1800.00 14 19 22 28 .30 34 37 46 56 S 74 43 E 85.75 6 S 74 47 E 116.50 38 S 75 1l E 154.44 40 S 74 14 E 202.68 16 S 73 42 E Z59.40 15 S 74 ,5 E 322.38 30 S ?3 17 E 395.12 10 S 72 55 E Y, 76.92 40 S 72 3 E 568.68 23 S 71 46 E 672.00 2209.82 1972.00 1909.00 2371.93 Z072.00 2000.00 2557.77 2172.00 2100.00 2737.13 2272.00 2200.00 2922.03 2372.00 2300.00 3103.52 2472.00 2400.00 3275.56 2572.00 2500.00 3439.48 2672.0Q 2500.00 3610.87 2772.00 2700.00 3806. B7 2872.00 2800.00 46 42 55 53 56 48 57 26 56 30 55 ~9 52 32 52 31 57 3 59 50 S 71 37 E 772.19 S 70 7 E 899.54 S 68 50 E 1056.11 S 57 ~t E 1204.89 S 66 51 E 1360.09 S 56 17 E 1511.15 S 55 5 E 1650.59 S 63 50 E 1779.81 S 52 41 E 1117.68 S 62 40 E 2084.62 4009.17 2972.00 2~00.00 4209.70 3072.00 3000.00 4405.93 3172.00 3100.00 4606.94 3272.00 3200.00 4797.88 33T2.00 3300.00 4967.13 3472.00 3400.00 5114.B4 3572.00 3500.00 5248.57 3672.00 3600.D0 5376.45 3772.00 3700.Q0 5501.06 3872.00 3~00.00 50 49 58 52 60 51 59 48 56 47 5O 34 44 6 39 36 37 1Z 36 ~ S 66 29 E 2259.33 S 69 ~6 E 2432.86 S 76 5 E 2601.46 S 75 6 E 2775.17 S 75 5~ E 2937.23 S 76 21 E 3073.07 S 76 17 E 3181.12 S 76 24 E 3269.40 S ?6 1~ E 3343.70 S 74 47 E 3422.82 20- - ~-Q- 90 KELLY ~EET OF SUB-SEA DEPTH DOGLEG RECTANGULAR SEVERITY NORTH/SOUTH DEG/IO0 FEET 0.00 0.00 N 0.23 0.01 N 0.08 0.26 S 0.08 0.78 S 1.35 1.57 S 3.26 3.2g S 3.28 6.53 S 1.83 10.78 S 1.65 15.51 S 1.67 20.56 S 4.06 ,!6.64 S 3.41 34.82 S ¢.01 44.53 S 3.03 57.44 S 2.10 73.11 S 3.B2 t0.5~ S 2.27 110.97 S 2.65 134.81 S 3.33 162.~3 S 2.95 194.59 S 7.83 225.96 S 3.90 267.77 S 3.70 323.33 S 2.20 3?7.86 S 0.50 43B.12 S 2.63 498.3~ S 1.II 555-6) S 2.29 610.94 S 4.31 673.90 S 0.82 751.17 S 1.80 827.13 S 3.71 893.57 S 1.96 942.52 S 0.29 985.83 S 3.85 1026.62 S 3.33 1059.56 S 4.42 1085.25 S 1.59 1106.25 S 1.56 1124.B6 S 0.87 1143.57 S D~T£ OF SURVEY: BUSHING ELEVATION: ENGINEER: COORDIN,~TES HORIZ. E~ST/WEST DIST. FEET FEET 0.00 E 0.00 0.0¢ W 0.04 0.15 W 0.30 0.09 W 0.78 0.34 E 1.60 2.98 E 4.44 10.57 : 12.43 23.30 ~ 25.67 39.66 ~ 42.5q 58.77 E 52.26 81.53 ~ 85.77 i11.2S ~ 116.57 148.02 E 154.59 194.63 E 202.93 249.25 E 259.75 309.87 E 322.83 379.77 ~ 395.67 458.11 E 477.54 545.65 ~ 5~9.32 643.88 6 6,12.64 739.05 ~ 772. 859.3z+ : 900.09 1005.77 ~ 1056.~7 1144.31 E 1205.03 1287.63 ~ 1360.1~ 1426.61 5 1511.15 1554.29 ~ 1650.62 1671.84 E 1779.97 1795.87 E 19~5.6~ E 20cj5.65 2104.1:) E 2250.93 2264.78 E 2434.69 2426.23 E 2602.92 2595.17 E 2776.11 2752.60 E 2937.81 2885.00 E 3073.41 2990.z, 9 E 31~1.32 3076.67 E 3269.51 3154.17 E 3348.75 3226.15 E 3422.8.~ 5 ,.O~C 90 7Z.O0 F)r FORMICA' DEPARTURE AZIMUTd DEG N 0 0 E N 77 57 W S 28 58 W S 6 $7 W S 12 10 E S 42 S 58 17, S 65 10 S 68 38 E S 70 43 E S 71 S4 E S 72 37 E S 73 14 E S 73 33 E S 73 39 E S 73 43 E S 73 43 E S 73 36 E S 73 25 E S 73 11 E S 73 0 E S 72 ~Z E S 72 11 E S 71 44 E S 71 13 E S 70 q5 F S 70 ZO ) S 69 56 s S 68 53 E S 6Q 3Z E S 68 28 E S 68 46 E S 69 12 E S 69 33 E S 69 50 E S 70 3 E S 70 13 E S 70 ZZ E S 70 29 E CONOCO INC. MI:LNE POINT UNIT SCHRADER 8LUFF NORTH SLOPE, ALASKA CSMPUTATISN D~TE: 20-ncC,[90 O~kT5 DF SURVEY: KELLY 5USHING ELEVATION: INTERPOLATED VALUES FDR EVEN 100 FEET OF SUB-SE& DEPTH ENGINEER: 6 OEC ':~0 7Z.O0 FI EQRMICA' M TRUE SU~-SE& COURSE VERTICAL EASURED VERTICAL VE2TIC~L DEVIATION AZIMUTH SECTION OEPTH DEPTH DEPTH DEG MIN DEG MIN FEET 5624.50 3972.00 3900.00 35 38 S 73 42 E 349~.99 57~7.26 ~OT2.0O 4000.00 35 29 S 72 41 E 3566.1B 5870.20 ~172.00 4100.00 35 29 S 72 29 E 3637.67 5992.99 ~272.00 4200.00 35 30 S 72 16 E 3708.88 6104.00 ~362.16 4290.16 35 43 S 72 17 E 3?73.78 DOGLEG RECTANGULAR COORDINATES H3RIZ. DEP,~RTLJRE SEVERITY NORTH/SOUTH E~ST/WEST DIST. AZIMUTH DEG/IO0 FEET FEET FEET OEG 1.32 0.65 0.38 2.37 0.00 1163.16 S 32gS.7T =- 3495.00 S 70 34 E 11~.06 S 3363.88 E 3556.18 S 70 36 E 1205.47 S 3432.13 E 1637.67 S 70 39 E 1227.10 S 3500.01 E t708.88 S 70 ~1 E 1246.90 S 3561.83 E 3773.78 S 70 42 E CONOCO INC. MILNE POINT UNIT H-Z SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER GCT LAST READING COMPUTATION D&TE: ZO-' ~-90 INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION : MEASURED DEPTH TVD BELOW KB FROM KB 60~2.00 ~311.81 KELLY DATE_ OF SURVEY: BUSHING ELEVATION: ENGINEER: '=, t 6 DEC 72. O0 FT FORMICA SEC34 T13N RIOE SUB-SEA ¢239.81 RECTANGULAR COORDINATES NORTH/SOUTH E~STJWEST 1235.82 S 3527.22 E CONOCO INC. MILNE POINT UNIT H-2 SCHR,~DER BLUFF NORTH SLOPE~ ALASKA MARKER COMPUT,~TI IN DATe: 20-~ ~'C[- 90 KELLY ***~*****~,~ STRATIGRAPHIC SUMMARY ***~**~*~ SURFACE LOC~T'ION = SEC3~ TI~N RIOE MEASUREO ~E~TH TVD BELOW KB FROM KB SUB-SEA DATE OF SURVEY: 5U~H[NG ELEVATION: ENGINEER: P ' q E . i' 6 DEC ~'~ 72.00 F'_1' FORMICa' ' ' RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST FINAL MEASURED DEPTH 610~.00 WELL L3CAT[ON TRUE VERTICAL DEPTH ~36Z.15 AT TD: SUB-SEA HORIZONTAL DEPARTURE VERTICAL DISTANCE ~ZIMUTH DEPTH FEET DEG MIN ~2g0.16 377~.78 S 70 ~2 SCHLUMBERGER B'lr REIST '1' ONAL SURVEY COMPANY CONOCO INC. WELL MILNE POINT UNIT H-2 FIELD SCHRADER BLUFF COUNTRY USA RUN ONE DATE LOOOED REFERENCE FSIA. '(2484~FNL, 4053' FEL, SEC 34~_T13N, R10E) 4000 - : I -~000 SOUTH -4000 · . i' ~ . ' ~' ~t . : ."~'" ....... , .............. .-.i-=.' ,'~-~.~- i-:.--..~-.,. .......................... ,.,_;_,,_,_ .,_,....,, , ,._; ....... ;.;~ ~ i - ,. , ~ ' · , ;' , . :. · . !-'~ ?-!-*-'- +-~ --r---? : , · ~ .... ~.......T...~.........o ......... . ...... ....., .................... . o . ..................... · ...... +... ........ --.~--~.--, ' 4-.4-..-. -. ' , , .. -- -- ' ~ , ~ , I f : · ; ; ~ : ' · : ; · ' ~ : ° ' ....... I-, -r-: t-' , ~- .~- ..... l.~-.=-r+.---,--]-.= .... 7',---, ........... [ .................. ~ ................... t .............. i .............. t ............... ~ ................. -2000 - 1000 0 1000 2000 3000 4000 SO00 6000 EAST (2484" FNL, 4053' FEL, SEC 34, T13N, RIOE) 28:9. -2000 - 10OO 0 O ! 000 2000 3000 4000 '~-J-~-~4-L;'-'-r4'"J-J-Jr-~J'-~-~'-~ ...... -r .... '-~'°t~ ~ : :'-~'-~--~-~'-~J'-~-~'-~'-'~-~ ...... . ~,'-~-~'-;'-~ ............~ . ~-;- ..... .:~-~'~-~-~., ....~' .................~ ~'-;. ..... ~'" ................ ~ ; ......... 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J..':-": ..................... :..~-t .................. , ................. ~ ............... ~ .............. ~ .................. ............. ...... ........... ......... .............. ............................ .................. : ............... ........... , ....... , .......... ............ ................... "T-e+-~'?-F~-''-?-*T?-:'-+ .............. Rn~n~ .................. ?- ....... ~'-~'"~ ..... :'"7't .............. 7'?'~'"~ .......... ~ .............. ~ ....... ~ ......... 7': .................... :'T"~ ......... [ ................. ~ .................. 6000 109~ PROJECTION ON VERTICAL PLANE 108. - 288. SCALED IN vERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT CONOCO MILNE POINT/SCHRADER BLUFFS 1260 H-2 NORTH SLOPE BORROUGH ALASKA SPERRY-SUN DRILLING SERVICES MWD COMPLETION REPORT ANCHORAGE, ALASKA 907-563-3256 ROB RODERICK LEAD MWD ENGINEER TABLE OF CONTENTS SECTION I ......................................... RESULTS SECTION II .................................... WELL SUMMARY SECTION III ...................... COMPLETION SUMMARY OF RUNS SECTION IV ................................ BHA AND BIT DATA SECTION V ........................... DRILLING AND MUD DATA SECTION VI ................................... SURVEY REPORT SERVICE OBJECTIVES AND RESULTS RESULTS: MWD A: DRILL TO 350' MD, AND ORIENT BENT HOUSING MUD MOTOR ASSEMBLY. BECAUSE OF A NOTICABLY SLOWER ROP THAN ON THE H-2 WELL, A BIT TRIP WAS MADE TO CHECK THE BIT & BHA. EVERYTHING CHECKED OUT OK. MWD B: TRIPPED INTO HOLE WITH ORIGINAL BIT, BHA AND MWD TOOL. CONTINUED KICK-OFF TO A MD OF 3126'AND AN INCLINATION OF 58.3 DEG. MWD C: DRILLED OUT OF CSG SHOE MAINTAINING ANGLE TO A MD OF APPROXIMATELY 4500'. WITH A .54 DEG DTU, THE ANGLE WAS DROPPED TO 35 DEGREES AND MAINTAINED TO A TD OF 6150' (MD). SECTION I WELL SUMMARY JOB NUMBER RIG / PLATFORM AK-MW-00118 NABORS 27E KB ELEVATION 35' KB REFERENCE SURFACE LOCATION MAGNETIC PARAMETERS GROUND 2484' FNL, 4053' FEL SEC 34, T13N, R10E NORTH REFERENCE TRUE GRID TYPE UTM DECLINATION 30.10 DEGREES GRID CORRECTION 0.00 DEGREES TOTAL CORRECTION 30.10 DEGREES START AND ENDING DAYS 9-25-90 thru 10-3-90 START AND ENDING M. D. START COORDINATES (Offset) ( N / S ) : ( E / W ) : TARGET LOCATION (From Wellhead) MUD MOTOR SIZE / TYPE MWD PULSER SUB O.D. ENGINEERS ON LOCATION 105' to 6150' 3244' DISP, 1096'S, 3053'E S 70 DEG. 15 MIN E 8" EC MACH II, 1.5 DEG BH 6 1/4" EC MACH I, .54 DEG DTU 8" 6 3/4" ROB RODERICK LESTER KOHN SECTION I I COHPLETION SUNHARY OF RUNS START DATE/TIHE DATE/TIHE RUN RUN HODE END BIT HWD SERVICE OPERATIN6 START END FODTA6E AV6 SURVEYS TDDLFACES HOURS HD ND DRILLED 6PH DETECTED DETECTED 9-26/18=48 9-27/19=00 ! A 5 9-27/19:20 9-29/14:30 RRI B 5 9-30/22:30 10-2/22:30 2 C 5 18.8 105 1312 1207 420 8 2095 31.5 1312 3126 1814 420 22 1764 30.6 3126 6150 3024 400 39 2299 SECTION III DHA AND BIT DATA RUN A HWD RUN B HWD RUN C BHA: BHA: BHA: BIT BIT BIT NO. SIZE TYPE BIT/EC 1.5 DEB BH ROTOR/ XO/BIT SUB/ NMLC/ NMSTAB/NMDC/ SS MWD NMSTAB/ 3 NMDC/ STAB/ 2-DC/ STAB JARS/XO/39 HWDP I 12 I/4' BIT/ EC 1.5 DEB BH MOTOR/ XO/BIT RRI SUB/ NMLC/NMSTAB/ NMDC/SS MWD/NH STAB/3-NMDC/ STAB/2-DC/STAB/JARS X0/39 HWDP BIT/ EC .54 DEB DTU MOTOR/XO/ NB 2 STAB/STAB/NMLC/NMSTAB/NHDC/SSMND XO/ NMSTAB/ 3-NRDC/STAB/XO/ JARS 39 HWDP 12 I/4" 8 1/2" STC HA1JSL STC MA1JSL REED MHP 43 AJS JET SIZE 2x14, Ix9 2x14, lx9 2x15, IxO FODTA6E START END 105 1312 1312 3126 3126 6150 TOTAL FOOTA6E 1207 1814 3O24 SECTION IV DRILLING AND HUD DATA HND RUN A HltD RUN D HND RUN ~ AV6 AV6 AV6 AVG AV6 AVB GPH PPG SAND SOLIDS PV YP 420 420 400 9.5 9.5 B.8 AV8 CHLORIDES PROBE TEHP 1.5% B% lB 42 IBO0 16.4 .SZ 8Z 13 16 800 23.4 TR 4Z 10 9 550 30,5 SECTION V S. XRY SUN DRILLING SERVICES Page 9 CONOCO H-PAD, WELL #2 9-25-1990 AK-MW-00118 MEASURED ANGLE DIRECTION DEPTH DEG DEG VERTICAL LATITUDE DEPTH FEET DEPARTURE VERTICAL DOG FEET SECTION LEG 0.00 0.00 N 0.00 E 290.00 0.20 S 21.00 W 412.00 2.10 S 56.40 E 532.00 4.50 S 66.20 E 653.00 8.70 S 71.50 E 0.00 0.00 290.00 0.47 S 411.97 1.91 S 531.76 5.03 S 651.94 9.85 S 0.00 0.00 0.00 0.18 W -0.01 0.07 1.60 E 2.15 1.69 7.74 E 8.99 2.05 20.77 E 22.88 3.50 773.00 10.40 S 75.50 E 894.00 12.10 S 74.80 E 1015.00 16.50 S 74.70 E 1138.00 20.50 S 75.00 E 1271.00 25.90 S 74.00 E 770.27 15.44 S 888.94 21.50 S 1006.16 29.36 S 1122.78 39.55 S 1244.98 53.59 S 39.87 E 42.74 1.52 62.68 E 66.26 1.41 91.51 E 96.04 3.64 129.17 E 134.94 3.25 179.63 E 187.17 4.07 1375.00 29.70 S 74.30 E 1498.00 33.40 S 74.00 E 1624.00 37.80 S 73.80 E 1748.00 40.70 S 73.60 E 1871.00 43.40 S 73.40 E 1336.96 66.83 S 1441.76 84.41 S 1544.19 104.76 S 1640.20 126.78 S 1731.53 150.18 S 226.28 E 235.55 3.66 288.18 E 299.75 3.01 358.63 E 372.93 3.49 433.92 E 451.24 2.34 512.91 E 533.48 2.20 2031.00 47.30 S 72.40 E 2126.00 44.30 S 71.70 E 2253.00 49.90 S 71.90 E 2380.00 55.60 S 70.60 E 2599.00 55.00 S 69.60 E 1843.95 183.67 S 1910.18 204.65 S 1996.59 233.69 S 2073.44 266.21 S 2198.11 327.49 S 621.67 E 647.16 2.48 686.45 E 715.23 3.20 774.80 E 808.19 4.41 870.47 E 909.22 4.56 1039.76 E 1089.26 0.46 2758.00 57.50 S 67.60 E 2851.00 57.00 S 68.00 E 2983.00 56.60 S 67.60 E 3054.00 56.60 S 66.90 E 3201.00 55.00 S 64.60 E 2286.45 375.75 S 2336.76 405.30 S 2409.04 447.03 S 2448.12 469.96 S 2530.75 519.86 S 1162.82 E 1221.39 1.89 1235.24 E 1299.54 0.65 1337.50 E 1409.89 0.40 1392.17 E 146~.08 0.82 1503.01 E 1590.27 1.69 3390.00 52.20 S 63.90 E 3578.00 56.10 S 64.10 E 3675.00 59.10 S 63.40 E 3929.00 60.50 S 63.80 E 4116.00 60.10 S 66.80 E 2642.90 585.93 S 2752.98 652.71 S 2804.95 688.94 S 2932.71 786.54 S 3025.38 854.41 S 1640.02 E 1741.55 1.51 1776.96 E 1893.00 2.08 1850.40 E 1974.36 3.15 2047.03 E 2192.40 0.57 2194.58 E 2354.20 1.41 4275.00 58.90 S 71.00 E 4429.00 61.10 S 74.50 E 4587.00 59.60 S 74.00 E 4714.00 58.10 S 73.40 E 4810.00 56.80 S 74.30 E 3106.11 903.74 S 3183.12 943.24 S 3261.28 980.50 S 3326.97 1011.00 S 3378.62 1033.52 S 2322.33 E 2491.11 2.40 2449.68 E 2624.31 2.43 2581.83 E 2761.29 0.99 2686.15 E 2869.77 1.25 2763.87 E 2950.53 1.57 4907.00 53.30 S 74.70 E 5000.00 49.70 S 75.20 E 5126.00 44.50 S 75.40 E 5254.00 39.50 S 75.00 E 5379.00 37.10 S 74.70 E 3434.18 1054.77 S 3492.07 1073.67 S 3577.81 1097.09 S 3672.90 1118.95 S 3770.99 1139.19 S 2840.47 E 3029.81 3.62 2910.74 E 3102.33 3.89 2999.99 E 3194.24 4.13 3082.77 E 3279.54 3.91 3157.55 E 3356.76 1.93 CONOCO H-PAD, WELL #2 MEASURED ANGLE DIRECTION DEPTH DEG DEG 5571,00 35,80 S 73,10 E 5696,00 35,20 S 70,40 E 5947,00 35,40 S 71,00 E 6077,00 35,60. S 70,40 E SUN DRILLING SERVICES VERTICAL LATITUDE DEPTH FEET 3925.43 4027.20 4232.05 4337.89 1170,79 S 1193,51 S 1241,45 S 1266,40 S Page 10 9-25-1990 AK-MW-00118 DEPARTURE VERTICAL DOG FEET SECTION LEG 3267,14 E 3470,59 0,84 3336,07 E 3543,14 1,34 3472,96 E 3688,17 0,16 3544,21 E 3763,66 0,31 THE DOGLEG SEVERITY IS IN DEGREES PER 100 FEET THE VERTICAL SECTION WAS COMPUTED ALONG S 70,25 E (TRUE) BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 3763.66 FEET, IN THE DIRECTION OF S 70.34 E (TRUE) check off or list data as it is received,*list received date for 407. if not uircd list as NR I ~I07 l* ,,<-,/a'/~'~' { driiiin9 history.- l.'"'v/r' s.u.rve.~,1'/{ we{i! tests vf~! core descri~'~io ~r~v'~' ~:ored in...t~rva'ls Co..r.e analys!.s' ~/~ .... dry,,ditch intervals dio~ital data '.~ ~ . .., ........ ~~. ,,, NO. i ( ' ',:,~TER';,',,,J..s i Sc,~L_F '1 (to the nearest foot] ! [inchll §O'] I ii ii i ii ' i i iiiii ,lJ iii LUll SCHLUMBERGER WELL SERVICES A DIVISION OF ~CHLUMB£RGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2:175 DEC 2 ? 1990 CONOCO, Inc. 3201 "C,, Street, Suite 200 Anchorage, AK 99503 AHention: Van ~ineberger PLEASE REPLY TO SCHLUMBERGER WELL ~ERVICE$Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore2 BI. prints of the Gravel Pack (TDT-P), Run 1, 12/21/90 Company CONOCO, Inc. Well Milne Point Unit H-2 on: Field MJ_lne Point/Schrader Bluff Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX .77079 Attn: George Lamb - OF 2018 PER County North Slope State Alaska _l_BL__prints, 1RF Sepia CONOCO; Inc, 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7360RDW I BL prints, 1RF Sepia OXY U.S.A., Inc. ~6_P_~_~_t.a Drive Midland, TX 79710 ArCh: John Carrol *(915/685-5600) _l__]tL_prints, 1RF Sepia Chevron U.S.A. _11111 South W~lcre~t. . i ....... --. __Hm]~tnn: Tewnn 77oqq Attn: Priscilla MacLeroy J'713/561-365~- ~, 1RF Sepia ' /_Alaska 0il & Gas Conservation ~ \ ~3001 Porcupine Drive ~ ~Anchorage, AK 99501 i_ / · The film is re~f-Eturned---to Conoco. Log Library. We appreciate the privilege of serving you. prints prints prints RECEIVED O£C 3 I 1990 Alaska 0il & Gas Cons. Commission AnclSorage ReceJ ved by; ,I Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SwS-- ! 327-F TO: THRU: MEMORAI . UM St,,te of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~/ DATE: December 26, 1990 Commissioner / f3 FILE NO: JT.LG. 1226.5 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection Conoco MPU H-2 Kuparuk Rv Field FROM: Louis Grimaldi ~ Petroleum Inspector W~dnesd{y !.,~/1.9/,9q: i performed a RIG BOPE inspection on Pool #102 rzg per2ormzng completion work.for Conoco on MPU #H-2. I found the rig to be in good shape with the only discrepancies to be the gas detector was off. The tooipusher informed me that they were recalibrating them at the time and assured me that they would be operational that day. In summary: Pool #102 rig appears to be in good shape for completing MPU #H- 2. 02-00lA (Rev. ~89) 20/ll/M]~MO1.PM3 TO: THRU: MEMORANL, dM Sta,e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi DATE: December 26, 1990 Commissioner z FILE NO: JT .LG. 1226.4 TELEPHONE NO: SUBJECT: BOP Test Conoco MPU Well #H-2 Kuparuk Rv Field Permit No. 90-87 FROM: Louis K. Grimaldi ~Q~ Petroleum Inspector Tuesday i2/4/90: i witnessed a BOP test on Pool #102 rig drilling on Well' ~H,2--~ ~onoco Milne Pt. The test went well with the exceptions noted on the AOGCC BOP test report. The blind rams and annular preventer were fixed before #102 rig proceeded with the program. Attachment 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-21 ?S DEC 0 9 1990 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van L_in_eber g. er Gentlemen: Enclosed ore_2__gL_prints of the. Compony CONOCO, Inc. ~F.A~E RElY TO SCHLUMBERGER WELL SE~ICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Well Milne Point Unit H-2 ~erforating Record/Ge Run 1, 12/6/90, ~Data Frac/Press/Temp/GR/CCL, Run 1, 12/7/90 on: I Field Milne Point . Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County ~orth Slope qtote. Alaska _l_BL_prints, 1RF Sepia CON~C~. ThC, · _1000 South Pine Ponca City, OK. 74603 Attn: Glenn Welch 7360RDW I BL prints, 1RF Sepia OXY U.S.A., Inc. .~ _D_e_aLa Drive Midland, TX 79710 Attn: John Carrol ,(915/685-5600) _~rints, I RF Sepia Chevron U.S.A. ~1111 South W~l~remt_ _Hol~ton~ T~w~ 770qq Attn: Priscilla MacLeroy .'713/561-3652 rints,1 RF Sepia~'~ -Alaska 0~1 & Gas Conservation ission ~ 3001 Porcupine Drive~ Anchorage, AK .gg§o1/ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints Received by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES _.David M. Saalwaechter _ . DI~TR ICT MANAGER SWE,-- ! 327-F SCHLUMBERGER WELL SERVICES A DIVISION OF E,C.HLUMB£RGER TIECHNOLO~Y CORPORATION ~USTON. TE'XAS 77251-2175 CONOCO, Inc. 3201 ,~"h Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineber.ger ~$E RElY TO SCHLUMBERGER WELL ~RVICES?ouch 340069 Prudhoe Bay, AK 99734-0069 Attn= Bernie/Shelley Gentlemen: Enclosed are_2_Bi~_prints of the Packer Setting Rec, Run 1, Company CONOCO, Inc, Well Milne Point Unit H-2 Field Milne Point County North Slope Additional prints are being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: .George Lamb - OF 201~ PER t2/14/90 State , Alaska _l__BL_prints, 1 RF Sepia C/)N~CO~ Tnt_- lO00 South Pine Ponca City, OK 74603 Attn: Glenn Welch 736ORDW on: 1 BL prints, 1 RF Sepia OXY U.S.A., Inc. .6 Delta Drive · Midland, TX 79710 . At,n:.. .John Carro] *(915/685-56OO) _l_]tb_prints, 1RF Sepia .Chevron U.S.A. ~11111 South Wjlcramt_ _Hou~ton~ T~w~g 77~qq _Attn: Priscilla MacLeroy .~_713/561-3652 1 BL .rint~~':"~"~~ Al. as~'a¥'*~' &..Gas Conservatf~ C~mission ~ 300~ Porcupine Drive . ]' An~0rage, AK 99501 "~/ Att~: John Boyle ,~ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints RECEIVED O~C 1 0 !990 Alaska Oil & Gas Cnn.~ nnm.,~o~.. ...... ..,,~. iw,~lgl i Anch0ra~e Received by; Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M, Saalwaechter DISTRICT MANAGER SWS-- ! 327-F .O..PERATION: Dr1 g /x~ Wkvr Operator Wel 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COHI'tlSSION BOPE Inspection Report Location: Sec ,~/ T/~. R/~ H ~ Drlg contrctr ~~ Rtg~ Loca~ton (general)~ ~ ,~ Well sign Housekeeping (general ~~ Rig ~~ Reserve pit ~' HUD SYSTEHS: Trtp tank Pit gauge Flow monitor Gas detectors BOPE STACK: Annular preventer Pipe rams Blind rams ~ Choke ltne valves HCR valve~O>¥~.~). Kill line valves Check valve DATE Visual Audio Test; P, ressure ~.~, ,~ ~ /' ..TEST: Intttalf )~ Weekly.__ Other ve ~ ~ Representatt ,~' / ,~6'~, /~/'~/'~ ~/ // 7 Casing set @ ACcuMULATOR SYSTEH: Full charge pressure Press after closure Pump tncr clos press 200 pstg ~ Full charge press attained .~ . Control s: Naster ~?~/ ft psig pstg mtn /0 sec min ~)~'~ sec pstg Remote 0 y',~ B1 tnd switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly . Lower Kelly Ball type ~ Test pressure ~.. Test pressure Inside BOP ~'~//-~ Test pressure Choke mant fold./~'(z~h Test pressure Number valves //3 Number flanges Adjustable chokes,., Test pressure :'--oo Q Hydrau]tcally operated choke TEST RESULTS: Failures ~ Test time ~ hrs Repair or replacement of failed equipment to be made within days. Notify the Inspector~ and follow with wrttten/FAXed verification to Commission office. C.O0~t (rev 05/10/90) STATE OF ALASKA ;ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation s~utdown ~ Stimulate __ Plugging Pull tubing __ Alter casing __ Reliant well ~ 2. Name of Operator 5. Type of Well: CONOCO 'i-nc. Development Exploratory Suite 200 Straugrapnic __ Anchorage, AK 99503 SerWce __ &Address 3201C Street, 4. L z3cationolwellatsuflace 2484' FNL, 4053' FEL, Sec. 34, T13N, RIDE, U.M., NSB, Alask~ Perforate ~ Other At top of productive interval 3678' FNL, 717' FEL, At effective depth At total depth 3745' ~NL, 541' FEL, 12. Present well conclition summary Sec. 34, T13N, RIDE Sec. 34' T13N, RIDE ~ Da~met~ation(DForKB) KB ~5' AGL '~UnitorPrope~yname Milne Point Unit 8. Well number H-2 9. Permit number/approval number 90-87 '10. APl number 50-- 029-22062 1'1'. Field/Pool Schrader Bluff feet Total depth: measured 614 7 ' true vertical 4 3 8 7 ' Effective depth: measured true vertical Casing Length Structural , Conductor 115 ' Surface 3073 ' Intermediate Production 616 9 ' Liner Perforation depth: measured feet feet feet feet Size 13-3/8" 9-5/8" 7" Plugs (measured) Junk (measured) Cemented Surface Surface T.D.- 4500' Measureddepth 115' 3108' 6204' ~ue~dicaldep~ 80' 2457' 4428' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure n shutdown pending completion. Prior to well operation Representative Dally Average ProductJon or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure SubseQuent to operation 15. Attachments 16. Status pt welt ctasmlicat~on as: Copies of Legs and Surveys run Daily Report of Well Operations ~ Oil ~__ Gas 17, i hereOy certify that the foregoing is true and correct to ~e best of my knowledge. ~ Title Sr. Drilling Engineer Form~0-404Rev06/l~88 o. ~. mTerg - 44 - Service Tubing Pressure Date 10/10/90 SUBMIT IN DUPLICATE DRILLING HISTORY Kuparuk River - SBP - North_Slope Borough, Alaska W. I. 1.000000% Milne Point H No. 2 (P) CONFIDENTIAL AFE 10-61-1260 Location: 4053' FEL, 2484' FNL, Sec. 34, T13N, R10E, Umiat Meridian Location: Bottom hole, 541' FEL, 3745' FNL, Sec. 34, T13N, R10E Objective: 6,147' MD- Schrader Bluff 9-26-90: Finish moving rig. Connect service lines. N/U BOP, diverter line, and R/U riser, flowline & function test diverter. P/U BHA & cond. mud and circ. Orient MWD. Drlg F/ 105' to 362'. Cum Cost: $ 116,023 Mud wt. 9.5 Viscosity: 97 Cum Mud Cost: $ 3,417 Nabors 27E(0-1-0) Drilling Foreman: Polya 9-27-90: Drld. F/ 362' to 1312'. POOH inspect bit & motor. RIH Drld.g F 1312' to 1416'. DIRECTIONAL SURVEYS MEASURED DEPTH ANGLE DIRECTION 773' 10.40 S75.5E 894' 12.10 S74.8E 1015' 16.50 S74.7E 1138' 20.50 S75.0E 1271' 25.90 S74.0E 1375' 29.70 S74.3E Mud wt. 9.5 Viscosity: 52 Cum Mud Cost: $ 6,504 Cum Cost: $158,565 Nabors 27E(0-2-0) Drilling Foreman: Polya 9-28-90: Drld. F/ 1416' to 1880'. Short trip 6 stds. OK. Drld. F/ 1880" to 2671'. Short trip 10 stds. OK-15' fill. Drld. F/ 2671' to 2798'. DIRECTIONAL SURVEYS MEASURED DEPTH ANGLE 1624' 37.80 1871' 43.40 2126' 44.30 2380' 55.60 2599' 55.00 2758' 57.50 Mud wt. 9.9 Viscosity: 58 Cum Cost: $212,455 Nabors 27E(0-3-0) RECEIVED DIRECTION S73.8E 0CT 1 91990 ,4/ &GasCons. S69. 6E S67.6E Cum Mud Cost: $ 8,605 Drilling Foreman: Polya 9-29-90: Drld. F/ 2798' to 3126'. POOH to BHA. OK. RIH. Circ. and condition mud. POOH L/D BHA. R/U loggers and run BGT. Could not get below 2288'. POOH & R/D loggers. R/U to run csg. Run 58 jts 9 5/8" 36# K55 Buttress Mud wt. 9.8 Viscosity: 56 Cum Mud Cost: $ 13,811 Cum Cost: $267,971 Nabors 27E (0-4-0) Drilling Foreman: Polya STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report Rig# Well sig. of<&~x OPERATION: Drlg,/~ Wkvr Operator Location: Sec~ TJ~/LJ. R/~'L/M Drlg contrctr /t//~m/~ . Location (general) Nousekeeping (general) ~.~ Re~e~e pt~/~A MUD SYSTEMS: / I Audio Trip tank Pit gauge Flow monitor Gas detectors BOPE STACK: Test Pressure Annular preventer.. ~ ~-'~ ~ Pipe rams ~-"dP~ Blind rams ~ ... ,.~Z~..~. Choke line valves ._;~'~)~9 , Ktll line valves [~ 5 ~h~c~ ~ _ ~/~ / , DATE TEST: Initial, ~, Weekly~ Representative ,_~'/~) ~' Permit # ?~ - ~-~ ACCUMULATOR SYSTEM: Full charge pressure., Press after closure Other · / ft 1.,~ 0 pstg Pump incr clos press 200 psig -----mtn /~ sec Full charge press attained ./ min.~-~ sec N2. ,/~ ~'~6'.~" ~__~ ~-, ~-~5)~) psJg Controls:'Master .emote ~'/(A~ ~." ~-~" cov~ v/~ '-/~ KELLY AND FLOOR SAFELY VALVES: Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Number valves J Number flanges .z~ Adjustable chokes . Hydraulically operated choke Test pressure Test pressure Test pressure Test pressure Test pressure TEST RESULTS: ~-~i~,' hfs Failures ~..---- Test time Repair or replacement of failed equipment to be made within days. Notify \ the Inspector~ and follow with wrttten/FAXed verification to Commission office. Remarks: ///Z~ f~ V/ ! Distribution= orig - AOGCC c - Operator c - Supervisor C.OOq (rev 05/10/90) WITNESS July 27, 1990 Telecopy: (907)276-7542 David L. MountJoy Sr. Drilling Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Milne Point Unit No. H-2 Conoco Inc.- Permit No. 90-87 Sur. Loc. 2484'FNL, 4053'FEL, Sec. 34, T13N, R10E, UM. Btmhole Loc. 3745'F~, 541'FEL, Sec. 34, T13N, R!0E, Dear Mr. MountJoy: 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. The Commission will advise you of those BOPE tests that it wishes to witness. Very truly yours, DaVid W. Johnston Commis si~e~ of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~MISSION d!f Enclosure cc: Department of Fish ~ Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. la. Type of work Drill ~X Re-Entry - "-'.-., STATE OF ALASKA ALASKA L AND GAS CONSERVATION CC IlSSION PERMIT TO DRILL 20 AAC 25.005 Redrill ZI lb. Type of well. Exploratory Deepen StratigraphicTest ~_ Development Oil Service _.-_ Developement Gas ;-- Single Zone,~ Multiple Zone 2. Name of Operator CONOCO ]INC. 3. Address . Pouch 340045. Prudhoe Bay; AK 99734 4. Location of well at surface 2484' FNL, 4053' FEL, SEC. 34, T13N, RIOE At top of productive interval U.M., NSB, AK 3580' FNL, 1000' FEL, SEC. 34, T13N, RIOE At total depth 3745' FNL~ 541' FEL~ SEC.34~ T13N~ RIOE 12. Distance to nearest I 13. Distance to nearest well property line I 541 feet 60'F/H-1 @ 500' feet 16. To be completed for deviated wells Kickoff depth 500feet Maximum hole angle 590 18. Casing program] size I Specifications Hole Casing Coupling 5. Datum Elevation (DF or KB) KB 35 AGL feet 6. Property Designation ADL-25906 7. Unit or property Name MILNE POINT UNIT 8, Well number H-2 9. Approximate spud date SEPTEMBER 8, 1990 14. Number of acres in property 2560 10. Field and Pool KUPARUK RIVER FIELD 11. Type Bond (see 20 AAC 25.025) BLANKET Number 8086-15-54 Amount $200 '000 15. Proposed depth IMD and TVD) $1_47'MD, 4426'TVD~et 17. Anticipated pressure (see 20 ,~AC 25.035 (e)(2)) Maximum surface 1900 psig At total depth Fl'VD) 2000 psig Setting Depth Top Bottom Quantity of cement MD TVD (include stage data) 8.5 7 BTRS 35' +297 SKS 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 DOWNSQUEEZE +273 SKS PERMAFROST C +60 BBLS ARCTIC PACK Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented measured true vertical Measured depth RECEIVED JUL 1 ! 1990 PIT SKETCH X True Vertical depth 20. Attachments Filing fee ~ Property plat ~. BOP Sketch K; Diverter Sketch Z; Drilling program .~' Drilling fluid program ~ Time vs depth plot ~ Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements X~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,¢,~,~,,~.-,.~~~¢¢~.-~'"""Title SR. DRILLING FOREMAN Dat ¢ ~ ~Commission Use Only ¢0-~ 7 50--o ~?- 2 ~o ~ ~ 07/27/90 for other requirements Conditions of approval Samples required ~ Yes ~No Mud log required ~ Yes ~No Hydrogen sulfide measures ~ Yes ~_No Directional survey required ~ Yes ;Z N~ Required working pressure forBOPE'~2M; ~ 3M; ~ 5M; ~ 10M; ~ 15M Other: ~prove .......... Commissioner the commission Date,,~ Form 10-401 Rev. ~-1~~ - % - Sub~it' J SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT H-2 Conoco Inc. P. O. Box 340045 Prudhoe Bay, Alaska 99734 I. Casing and Cementing Program Al The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±744 sacks of Permafrost "E" cement followed by ±278 sacks of Class "G" Cement. A top job will be done if cement is not circulated to the surface. C. The 7" production casing will be cemented in two stages. The first stage will consist of ±232 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±297 sacks of Class "G" cement. The secondary cement job will consist of +273 sacks of Permafrost "C" cement followed by ±60 barrels of Arctic Pack pumped down the 7"x 9-5/8" annulus. II. Drilling Fluid Program ae Be Ce III. Drilling Program 0' - 3168' 9.0 ppg freshwater spud mud. ~ECEiVED 3168' - 5296' 9.2 ppg low solids non-disperseg~[ 5296' - TD 9.4 low solids non-dispersed. ~!~aOl.&~sCo~.~,~E[$$~,~ ,~chora~ Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13- 3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly safety valves will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is H-1 with a closure of 60 feet at a depth of 500'. The well will not be completed or tested at this time. ae Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. $. Drill a 12-1/4" surface hole to ±2500' TVD 3168' MD and set 9-5/8" casing. Ce Drill a 8-1/2" production hole to ±4426' TVD to 6147' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YD PV VIS FL 0 0 Gravel 1-1-4 9.0 32 20 90 15 500 500 Sand/Clay 1-1-4 9.0 25 20 65 15 3479 4970 "K" Sand 1-1-4 9.2 25 15 35 10 3729 5290 "M" Sand 1-1-4 9.4 25 15 35 10 3961 5580 "N" Sand 1-1-4 9.4 25 12 35 05 4126 5781 "0" Sand 1-1-4 9.4 25 12 35 05 4426 6147 TD 1-1-4 9.4 25 12 35 05 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. I I II! ~ -- . III NOTE,S: -1.- .... 8TA?E PLANE COORDINATE8 ARE ZONE 4 2. ALL GEODETIC PO,SITION8 ARE BASED ON N.A.D, 1927 OFFSETS TO SECTION LINE8 ARE COMPUTED EIASED ON PROTRACTED VALUE8 OF THE SECTION CORNER POSTION8 290' 30' 40' H PAD -TYPICAL SECT!ONNo ~CAL~ F. Bob _ II J MILNE POINT UNIT : ROAD '"'.--"-'"- - MIL.NE PT, VICINITY MAP MIL 6~ I IIIII I Il LOCATION IN SEC. 34, T13N, R1OE, UMIAT MERIDIAN WELL FROM EAST LINE FROM NORTH LINE H-1 4070' 2642' H-2 4053' 2484' H-3 4036' 2426' H-4 4019' 2369' STATE PLANE COORDINATES-ZONE 4 WELL Y X H--'i ' 0,009,8'89,28' 656,676,42' H-2 6,009,947,04' 556,692,64' N-3 0,O10, OO4.80' 556,008.85' H-4 6,O10, O62.56' 556,625.07' GEODETIC POSITION8 NAD 1927 ~ L WELL NORTH LATITUDI:: WE8T LONGITUDE H-1 70* 26'1,5.6012' 14~* 32'19,309" H-2 70* 26'16.1680' 149' 32'18.820' H-$ 70* 26'16.7350" 149' 32'18,33ff H-4 70' 26'17,3019' 149' 32'17,843' RECEIV :D L CCa.- o) DATE DEC. 15, 1989 DRAWN JSP CHECKED ~IELD 8OOK . I _ I IIII I l 1 19g0 ~..o.?...~ ~UL Oil & Gas ConS. Commissk~ ~'-"'~:"' A -..'y~-~,~~.:.~ ~ ~~ '"~ ~ 3CALE 1':200' JOB NO. 87033 _ -- Jill I I II ._ J I I T 13 N R g E T 13 N R 10 E T 13 N R 1 1 E MILNE POIN ~- ~-25S~ 2533XC AOL'47434 =S"O AC AOL'47433 =~SO AC 23 24 18 20 Al 22 23 24 19 2~ 21 22 iADL'25516 ~ ADL'47439 ADL'3 15~4 ~'25514 2550 AC ADL'25515 2~4 AC ,~3~14l] 1280 AC ADL'4?43Z 25~O AC ADL'47438 2544~C 1280 AC ACl ""~' ,~oh ...... ¢':c~0i~r ~ ~' ~ C...o. " ~ "' , ' CONoco. V 30 20 28 aT 26 · 2S 30 20 EXt / 36 30 A~-28817 ~ A~ MIl'' O 2235 AC 20 kADL'25~ 2SOO AC ADL-25518 2560 AC ADL'28231 ~1 Il ~ I I I I IIII I I I ..... UNIT numbore t 35,744 AC~ 48 IlfllT A ~I~CO SOHIO 0/04 UNIT AREA Me/Idlon,Aloehe I 2 t ' I Scale 13-5/8" 581888 BOP SYSTEM Fill L~ne Aa 13-,5/~ :~ Aa 13-5/~ 5~ Flow Line Annular Preventor J~sm Aa ~3-5/~ ~ × ti" ~ Tubing Spool w/ 2"-5000~ Side Outlets APl 11' 5H Casing Spool w/ 3"-5ooo Side Outlets Tl'readed Connect~n 9-5/8" SurFace Casing 13-3/8" Conductor' Casing C'hoke Line: 3" 5000~ Manual & 3" HCR VALVE Kill Line: Two 3" 5000~ Manual Valves Gate Valve Oal'e t, BOP STACK SIZE RATING MEETS APl RP53 & SPEC 6A FOR CLASS 5H 2, DOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAUL]C CONTROL SYSTEM TO INCLUDE (5) STAT]ON CONTROL MAN]FOLD LOCATED REMOTE WITH 168 OALLON ACCUMULATOR, RESERVOIR UNIT, & AUXILIARY ENERGY SOURCE FOR SYSTEM ACT]VAT]ON, ~r, MINIMUM ONE SET BLIND RAMS & TWO SETS APPR. OPR]ATE PIPE RAMS, 5, CHOKE & KILL HANIFOLDS SHOWN SEPARATELY TO HEET APl RP 53 CLASS 5H REQUIREHENTS, KILL /~ANIFOLD FROM RE),~OTE HIGH PRESSURE PUMP NOTE: !. H~RAIJLI¢ CC.'iTROL SYST£~I FOR BOP STACK R CNOKE i~Ah;FOLO TO I~LUD£ (5) STATION CONJROL UANIFOLD LOCATED R£FGT[LY ~ITH ~000 PSi ~CCU~/ULATOR 8 160 G~. ~'ESF.~','O1R 8 ,~UX. [~;[RG¥ SOL;,RCE. ($) S/A CONTROL ,ANIFOLD PLUS V-,'RIADLE C;h'OKE CONTROL TO 8E LOCATED ON RI(; FLOOR. Z I(ILL 8 CHOICE WANIFOLDS TO UEET APl RPS) CL. 5u STD$. ). KILL UANIFOLD SIZE- RHTING 2'- 5000 4_ CHOKE I, IANIFOLD SIZE - AATING 3'- 5000 j FRC~ Mb. U~P RF-h(OTE PRESSURE GAGE SENSOi:~ HYI~R~t ULIC CONTROLLED SPOOL RE.~OTE PRESSURE ADJUSTABLE C~OKE ADJUSTABLE CHOKE VARI,~BLE CHOKE REM. OTE CCNTROL l BLEED LINE TO ATMOS?HERI¢ TO PIT MUD/GAS SEPARATOR tCHOKE ~, KILL U, Ah~IFOLDS FOR q'~/8'~ 8~ 7" OD CASlt;O ~OP STACK BOP I,IAI IFOLD LAYOUT - CONOCO, INC. , GAGE SENSOR CHOKE MA~IFOLD TO SHALE SHAKER CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 318' .CONDUCTOR {)IV[ATIlt QUICK ¢ONN[CT AS$[IdlI. t' $&V£R '~Ut A$S[t,IBLY 1. The hydraulic control syst~ will be in accordance with API specifications and ~ requirements. 2. The HCR valve will open when the preventer closes. A single I0" peli~f line will pun off of the drilling spool HCR valve and will have a targeted do~nstpeam tee for downwind diversion. Valve~ on both side~ of the tee will be full open~n~ and l~nked together to enabl~ one to al~ays be open and the other to be closed. MuD CLEANER I, IUO TROUGH , ~EG~;~ER MIX/I:i.LL I i .' AGiTAT~ NAI3ORS D~tLL~G LI:4TED FLOW SHEET DEVELOPMENT W~ WELL NAME: MPU H-2 11-Jan-~0 CONDUCTOR SETTING DEPTH: SURFACE CASING SETTING DEPTH: INTERMEDIATE CASING SETTING DEPTH: PRODUCTION CASING DEPTH (OR TD): 80 .3168 6147 DEPTH OPERAT I ON: 0 I RIG MOVE: 0 2 RIG-UP; SET CONDUCTOR: (3,168) .3 DRL/SURVEY SURFACE HOLE: ('-: 168) 4 SURFACE HOLE LOGGING: (3,168) 5 CONDITIONING TRIP: (7,,168) 6 RU/RUN SURFACE CASING: (3,168) 7 RU/CEMENT SURFACE CASING: (.3,168) 8 CHNG BOPs; PU BNA; RIH: (-3,268) 9 DRL OUT; TEST: TOOH; RIH: (5,268) 10 DRILL INTERMEDIATE HOLE: (-3,268) 11 LOGGING OPERATIONS: (~ 268) 12 CONDITIONING TRIP: (5,268) 1-]. RU/RUN INTERMEDIATE CASING: CUM HOUR DAYS DAYS 6 0.-.-~5 0. ~= 12 0.50 0.75 56 2.34 3.09 0 O. 00 3.09 3 O. 13 3.22 10 0.42 3.64 6 O. 25 3.89 9 0.38 4.27 10 O. 41 4.67 0 O. O0 4.67 0 O. 00 4.67 0 0. O0 4.67 0 0. O0 4.67 0.0~-~ 4.67 0. O0 4.67 0.00 4.6 7 2.76 7.43 · 0 00 7.43 O. O0 7.43 (3,268) 14 RU/CEMENT INTERMEDIATE CASING: 0 (-3,268) 15 CHNG BOPs; PU BHA; RIH 0 (3,268) 16 DRL OUT; TEST; TOOH; RIH 0 (6,147) 17 DRILL PRODUCTION HOLE: 66 ~6,147) 18 CORZNG OPERATIONS: 0 (6,147) 19 LOGGING OPERATIONS (MWD ONLY): 0 (6,147) ~ CONDxTIONING TRIP: (6,147) 21 RU/RUN PRODUCTION CASING: 16 (6,147) 22 RU/CEMENT PRODUCTION CASING: 6 (6,147) 23 RD DRLG RiG 12 (6,147) 24 RU COMPLETION RiG: 12 (6,147) 25 RD DRLG RIG 12 (6,147) 26 RU COMPLETION RIG: 12 (6,147) 27 RD DRLG RIG 12 (6,147) 28 RU COMPLETION RIG: 12 (6,147) 29 CASED HOLE LOGGING: 1(3 (6,147) 30 PERFORATING: 33 0.42 '. 7.86 O. ~5 8.51 0.26 8.77 0.50 9.27 0.50 0. 0.50 I. 00 O. 50 1.50 O. =-C ~ O0 0.50 2.5(3 (-~ 4~ ~ 92 1..39 4.31 ] T I il I I I I I · ,._, 4 6 7 8 c~ CONOCO. Inc. Pad H. Wel I No, 2 Revlsea Pr'opoeal HI Ine Polni: Unl'i:. Nor"l:h elope. Alaek:'e 0 _ RKB ELEVATIONs 35' 1000_ 2000 _ 3000 4000 5000 KOP TVD=500 TMD=500 DEP=O 3 9 15 21 BUILD 3 DE9 PER I00 FT 27' 33 39 4,5 $I 57 EOB TVD=2134 TMD=2461 DEP=922 MAXIMUM AN GLE 58 DEG 50 MI N 9 5/8' CSG PT TVD=2500 TtiD=3168 DEP=1526 51 DROP 3 DEG 45 PER 100 FT 39 TARGET ANGLE :35 DEG BEGIN ANGLE DROP TVD=3190 THD=4502 DEP=2668 K-SNDS TVD=3479 THD=4970 DEP=3035 TARGET / H SNDS TVD=3729 THD=5296 DEP=3244 N SNDS TVD=3961 THD=5580 DEP=3406 0 SNDS TVD=4126 THD=5781 DEP=3522 TD / 7' LINER TVD=4426 THD=6147 DEP=3732 ! i I 1000 2000 3000 VERTIOAL SECTION I 4000 HORIZONTAL SCALE 1 IN. PROJECTION = 1000 FEET CONOCO. I.e. Pad H, We I I No = 2 Rev I ced P~opoea I HI ine Point Unit, North elope, Alaska SURFACE LOCATION, 2484' FNL. 4053' FEL SEC, 34. T13N. RIOE Z 1000 1000 2000 3000 1000 0 I S 70 DEC; 3244' (TO WEST-EAST 1000 2000 I 3000 I 15 MINE TARGET) 4000 I TARGET / H SNDS TVD=37'2g THD=$296 DEP=3244 SOUTH 109~ EAST 305,.3 TARGET LOCATION, 3580' FNL. 1000' FEL SEC. 34. TI3N. RIOE TD LOCATION, 3745' FNL. $41' FEL SEC. 34. TI3N. RIOE 225O 2300 2350 >_400 ~.450 ~.500 .~550 :600 .65O 4150 4100 I I 4050 I 4000 I P00820 , , ~ / / ; '/2100 ' / / / / 900 )' 1 ?00 ° 500 3950 4150 "' ~qoo i 4100 I 4050 *'l-LO0 \ %11 oo 4000 I 3950 3900 I 3850 I I 3900 3850 _ 225 230, 235~ 240~ 245( 250( 255( 260( 265( CEECK LIST FOR NEW WELL PERMITS iT_=~M APPROVE DATE _ 3. 4. 5. 6. 7. 8. (3) A dmin M~/O['_. ~7,,'~2.~qz'-) 9. (10 ~d i3) 12. 13. (14 :h~ 22) (s) (23 thru 28) Company (~rp,~,,~c.z> . Lease & Well No. /gZ~C 2.5-9~'3/~ ~ ,~/~ (~.~.) ;/7/-,2._ - YES NO ~S Is the perm/t fee attached .......................................... ~ -- Is well to' be located in a defined pool ............................. ~ Is well located proper distance from property line .................. / Is well located proper distance from other weils .................... /, Is sufficient undedicated acreage available in this pool ............ ~ Is well to be deviated and is we!!bore plat included ................ is operator the oniy affected party ......... i ....................... ~ Can permit be approved before fifteen-day wait ...................... ~ ~ Does operator have a bond in force .................................. Is a conservation order needed ...................................... AP Is administrative approval needed ................................... is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is cdnductor string provided ........................................ ,, Will surface casing protect all zones reasonably expected to sez~e as an underground source of drinking water ..................... .,~ .... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... ,~ , Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old we!Ibore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrmm~ and descriptions of dive:re: and BOPE attached. Does BOPE have sufficient pressure rating - Test to 2O~dD psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... thru rev: 01/30/89 6.011. . For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential ore:pressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. n ZTZ;a, ceo. u zZ [ oN/ow POOL CLASS STATUS AREA NO. SNORE , , Additional R~rks:' 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. ,o COMPANY NAME ~ CONOCO WELL ~AME I MIbNE PO!~ UNIT H-2 FIELD h!AME ~ SCHRADER BLUFF BOROUGH ~ NORTH SLOPE STATE I .aLASKA AP! ~UMBER ~ 50-02~-2~062 ~EFERENCE NO ~ 93101 MICROFILMED · **** R~EL HEADER SFPVICE N~"= : EDIT ORIGIN : FbIC REEl, NA.E ~ 74]06 CDNT!NIJa?~ON ~ : CO~EMT : CONOCO INC.. **** TAPE HEADER **** SFRV!CE NA~ t EDIT O~IG!N ! FbIC T~PF ~A~E ! 74106 CON~!NUATIO~ # : CO~ENT : CONOCO INC.. SCHRADER ~LUFF. ~IbNM ~OINT UNIT M-~. 50-029-22062 PAGE: **** FILM HEADER **** FfLF NA~g : EDIT .00l $~RVICE ! PLIC V~RMION : O01A06 ~L~ TyP~ : LO ******************************************************************************* ******************************************************************************* ~* ** ** SCHLUMBERGER WELL SERVICES ** ******************************************************************************* ******************************************************************************* COMPANY NAME: CONoco INC.' W~Lt,$ ~I[,N~ POINT UNIT H-2 FIELD: SCNR~DE~ BLUFF STATE: ALASKA API N~.]MBEP~ 50-0~0-2~062 [,OCATION: ~4~4' F~[, & 4053' FEL SECTImN~ 34 T~WNSHIP: PYiR~A~!ENT D~TUM; ~Sb ELEVATION: 0 S Ta~e Veri~.~cation bist~n~ 'hl.m~eroer A.I. asMo ComputlnO Center · 9-~AR-~993 0g~22 bOG ~A~URED FROm RK~ 72 r~aTM LOGGED: Tn DRILLE~: 03-0CT-1990 6{50 ~i52 ABOVE PERMANENT DATUM DF: 70.5 GL: 37 CaST,G: 9 5/~" s D~ILLER DEPTH OF 3106 AMD LOGGER DEPTH OF 3~08 BTT SIZE: 8.5" VISCOSITY: 35 FLUI~ 505S~ 5 TYPE FL!~ID IN HOLE: bSMD DENSITY: 9.2 Pti: 9 4.48 m 63 4.76 ~ 53 6.02 ~ 52 ~UD RESISTIVITY: ~?bT~aTE ~ESIST%VITY: ~UO CAKE ~ESISTIVI~Y: T~M~ CI~CI.!LAT~ON. E~JDED: 20:]0 03-OCT T~E LO~GER ON BOTTO.~ 01.:48 03-OCT ~AXI~U~ T~{P ~ECORDED: 89 PRUDHOE BAY S~RRER/FRXTZKE DIL, LOM/PO[,YA DISTRICT: TCC-B-320 C5~C-H-332 4969 DIS-2?6 A~-AA-724 NGD-B-7]9 gSC-E-793 D~C-271 TC~-278 FTE!,,D 1.5" ST.A~':.!DOFFS AMD 2.5' HOLE FINDER USED ON THE'r.OLO STRING. ~ ,;AS INVALID - THEREFORE NOT PRESENTED. ~FNSITY HOLE CORRECTION : NO~E, NGT FILTERING : KAI.,~ N~UTRON ~ATRIW = SAND, HOLE CORRECTION = CALIPER CO~PUTING CENTER PEMARKS: 8EC~US~ ALL TOOLS WERE RUM IN COMBINATION. NO DEPTH-ADJUSTING WAS P~RFOR~ED.~'~ THE CHAN~Eb ON THIS LIBRARY TAPE LABELED Sp,DTE IS TH~ SA~E CURVE LABELED "SP~" ON RESISTIVITY FIELD PRINT. D~TE JOB STARTED: 2.4-0CT-90 jO8 REFMRE'NCE NO: 74106 LDP/ANA: KOHR!NG PAGM: ****************************************************************************** $ ?an.e V~ri~J. catton hl.~t~f, ncl h]umh~roer Alaska Compt)tino Center · g-MAR-1993 09:22 F T I',F, - CONOC[] INC. $CH~ADEP RbUFF ~.lI.~,~[ POI.~IT UNIT H-2 50-029-22062 PASS bOG DATA FROM PIELD FILE .004 D~TA SAHPLEn EVERY -.5000 FEET DATA INCLUDED - TOOt EXTEHSION TOOL TYPE USED NAME D!T-E ,DTE bDT .bDT CNT-A/D/H ,CNL HGT .NGT PHASOR DUAL INDUCTION SFL LITHO DENSITY COMPENSATED NEUTRON . NATURAL GR~MA SPECTROSCOPY 6138f TO 3108' 6130f TO 3108' 6illf TO 3108' 6088' TO 3108' , ****************************************************************************** ** nASA FO~gAT SPEC]FICATTON RECORD ** ** SET mYPE - 64EB ** TYPE ~EP~ CODE VALUE ~ 66 0 2 ~ 0 3 73 300 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT ~1, 66 27 ~2 68 13 66 0 1,4 65 ~5 66 68 ~6 66 0 66 0 verification tistino ,hl, Umberqer Alaska Computing Center 9-~AR-1993 09122 PAGE: NAMF KE~V IlNTT SE~VTCE AP! AP! AP! AP! FILE N{JM~ NUMB STZE REPR PROCESS ID ORDER # LOG TYP~ C[,AS$ ~OD NUmB SA~P ELE~ COPE (HEX} D~PT FT 5491R5 00 000 00 0 1 1 ] 4 68 SVbt! DTE OHM~ 5441~5 O0 000 00 0 1 1 1 4 68 ~b~ DT~ OH~ 549185 00 000 O0 0 1 I ~ 4 68 I[,D DTF ON~ 549!~5 O0 000 O0 0 1 1 1 4 68 S~ nT~ ~V 5491~5 00 000 00 0 ! ~ 1 4 68 IPP~ DT~ DH~. 54~185 O0 000 O0 0 I 1 1 4 68 I~P~~ DTE OH~H 549185 00 000 O0 0 1 ~ 3 4 68 ~FRE DTE HZ 549185 00 000 00 0 1 ! t 4 6~ ]'DOW ~TE 549185 00 000 00 0 1 1 1 4 68 ~Ow DTE 549185 00 000 00 0 ~ 1 1 4 68 CI~P DTE MMHO 549185 O0 000 00 0 1 1 1 4 68 CIMD DT~ M~HO 549185 00 000 00 0 1 ~ ! 4 68 ~R~ DT~ MMHO 549185 O0 000 00 0 1 1 1 4 68 I?X~ DTE ~HO 549185 00 000 O0 0 I 1 1 4 68 tTR" DT~ M~HO 549185 00 000 00 0 1 1 ! 4 68 $GR D~ GAPI 549185 O0 000 00 0 ! I 1 4 68 CG~ DTE GAPI 549185 00 000 00 0 1 ! 1 4 68 T~NS DT~ LB 549185 00 000 O0 0 ! 1 1 4 68 MTEV DTE OEGF 549185 00 000 00 0 1 1 1 4 68 ~E$ DT~ O.~ 549185 00 000 00 0 1 1 1 4 68 ~?F~! DTE LB 549185 00 000 00 0 I 1 1 4 68 PPHr LDT PU 549185 00 ,000 00 0 1 1 1 4 68 R~OB I, DT G/C3 5491~5 00 000 00 0 1 1 1 4 68 D~HO LOT G/C3 549185 00 000 00 0 1 I 1 4 68 P~F [~DT 549185 O0 000 00 0 I 1 I 4 68 O[,S LDT 5491a5 00 ~00 00 0 1 ! ~ 4 68 0SS ~OT 5491~5 O0 000 00 0 1 1 I 4 68 bS LD? CPS 5491~5 O0 000 O0 0 1 1 t 4 68 Lt! bDT CPS 5491~5 00 000 00 o 1 ! 1. 4 68 bt,, [,I)~ C~S 540185 O0 000 O0 0 ! ! t 4 6~ [,~T~ bDT CPS 549185 00 000 O0 0 1 ! 1 4 68 SSl [,,Dm CPS 549185 00 000 00 0 1 1 ~ 4 68 SS~ bDT CPS 549185 00 000 00 0 1 1 I 4 ~8 I,$HV bDT V 549185 00 000 00 0 1 ! ! 4 68 SSNV [.,~T V 5491~5 00 000 00 0 1 1 ! ~ 68 SlP~ bDT G/C] 549185 00 000 00 0 1 1 I 4 68 b$~ t,~T G/¢3 549185 00 000 00 0 1 1 I 4 68 [.,URw !.,9T G/C3 549185 0~ 000 O0 0 I 1 I 4 6~ C~T,I r,~ IN 549185 nO 000 00 0 ! ~ 1 4 68 ~ .......... , . " oOR I..,DT GIP! 549185 00 000 00 0 1 1 1 4 68 CGR [,9T GAPI 549185 O0 000 O0 0 1 1 ~ 4 68 T~¥$ L~T LB 549185 00 000 00 0 1. t. 1 d 68 ~TE~ LDT DEGF 549185 o0 000 00 0 1 1 ! 4 68 .~ES LOT OHM~ 549185 00 000 00 0 1 1 1 4 68 H?E~ !,DT LB 549185 00 000 00 0 1 1 ! 4 68 NP~T CN[, P!.! 549185 00 000 00 0 I 1 t 4 68 TNPH CNL PU 549185 00 000 00 0 I I i 4 68 TNR~ CNL 549185 00 000 00 0 1 1 ! 4 68 NPO~ CNL PI! 540105 00 000 00 0 I 1 ! 4 68 ~CN~ CN5 CPS 549185 00 000 00 0 1 1 1 ~ 68 0000000000 0000000000 090O0OO000 00000000O0 0000000000 000000000o 000000000o O000oO000o 0000000000 0o00000000 0000000000 0000000000 0000000o00 0000000000 0000000000 0000000000 0000000000 O000OO0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00000o0000 0000000000 0000000000 0000000000 0000000000 0000000000 00o0000000 0000000000 0000000000 0000000000 0o00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 Tape veri~.tcation I.,lst~ng ~hlUmhergerAalask gomputtnO Center 9-~AR-1993 09:22 PAGEI mmmm~mmm#mmmmmm#mmmmmmmmmmm~mmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmmmmmmmmmmm ~{F SFRV [!NET S~RVICE IPI lPI API IPI FIL~ NUM~ NUMB SIZE ~EPR PROCESS TD flRDER # LOG TYPE CGASS MOD NtI~8 SAMP ELEM CODE CHEX) ~F? CNI, CPS 549185 00 000 00 C~TC CNL CPS 5491~5 00 000 O0 CmTC CNL CPS 549~85 00 OOO 00 SGR CNL GAPI 54q185 O0 000 O0 CGP CN5 GAPt 5491R5 00 000 O0 C~L! CNL IN 549185 O0 000 O0 T~NS CNL I,~ 5491~5 O0 000 O0 ~RES CNL O{~M~ 5491~5 O0 000 O0 ~TE~ CN[, D~GF 549185 O0 000 O0 ~{ CNL LB 549185 O0 000 O0 $~ NGT GAP! 549185 O0 000 O0 CG~ ~GT GAPI 54. o185 O0 000 O0 THO~ NG~ PP~ 549185 O0 000 O0 PnTa NG? P~ 549185 O0 000 O0 !):AN ~G~ PPM 549185 O0 000 O0 wiNG NGT CPS 549185 O0 000 O0 W~N~ NGT CPS 549185 O0 000 O0 W)N~ NGT CPS 54~185 O0 000 O0 W4NO NGT CPS 5491A5 O0 000 O0 WSN~ NGT CPS 549185 O0 000 O0 TE~!S NGT LB 549185 00 000 00 ~TE~ ~gT DEGF 549185 00 000 O0 ~mE~ ~GT OH~ 549185 00 000 00 C8 NGT F/8~ 549185 ~4T~N 0 1 1 ! 4 68 0000000000 0 I 1 i 4 68 0000000000 0 1 I ! 4 68 0000000000 0 1 1 1 ~ 68 0000000000 0 1 ~ ! 4 68 0000000000 0 1 1 ! 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 I 4 68 0000000000 0 1 1 I 4 68 0000000000 0 ! ! 1 4 68 0000000000 0 ! I 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4. 68 0000000000 0 1 1 i 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 ! 1 4 68 0000000000 0 1 ! I 4 68 0000000000 0 ! 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 549185 00., 000 O0 0 1 1 I 4 68 0000000000 DFPT. 6208.500 ~Ft, IJ;. DTE 4.336 XLM*DTE 3.307 ILD.DTE SP.DTE 96.063 IDPH.DT~ 1.~4 IMPH.DTE ~ IFRE DTE I~OF.DTE 3.000 I,OF.DT~ 2. 0 CIDP.DTE 61:326 . . 500 C~.~O.DTE ,I~n ~TE 494,750 IIXD..DTE 88 375 IIR~,DTE 282.250 SGR.DTE '"CGg~DTE 0.000 TENS,OTE 1695:000 MTEM.DTE 87.313 MRES.DTE HTE~.~TE -8.3 250 DPHI.hDT ~2 549 RHOB bDT 2 278 DRH. O.bDT ~E~.t.,DT 229~8 qb&.bVT 01015 O$SiLDT OlO00 LU.LDT 343.000 LS.. bDT 191,625 GITH,LDT 10~.750 SSI..LDT $$9.LOw 318,750 LS~V:bDT 170 000 SSHV,5OT 1~54.000 SI~.LDT L~a~.LDt 2.275 !.,']~H,L9T 2i~1 CALI,LDT 9,453 SG~.LDT CGO.LDT 0.000 TENg. LDT 1695 0 ~TE~,LDT 87.31t M~ES.LDT ,TE~.I,D~ -~3,250 NP~I.CNL 39.~0 TNPH.C~L 39.550 T~RA CNL NPO~.~][~ 39.550 ~CNT.CNL ~087o 5 RCFT.CNL 573.252 CNTC]CNL CWTC.CNL 6~3.766 SGR.CNL 0 000 CG~.CNL 0.000 CALI.CNL Tv'~.CNL 1695.000 ~RE$.CNL 2~992 ~TER.CNL 87.313 MTEN.C~L 'SG~.NGT 0,000 CG~]NGT 0.000 THOR.NGT 0 000 POTA.NGT [.!O~.NGT 0.000 win NGT 256.322 W}NG'NGT 13~184 W3NG.NGT ~.4N~.~GT ~1,494 WSNG.NGT 6.897 TENS.NGT 1~95 000 ~PES.NGT "2.99~ CS.NGT 936.000 HTEN,NGT 83~250 ' 1.567 20,0O0 300.500 0.000 2,902 0.001 363,000 215,375 2.~73 0.000 ~,9~2 3.389 ~084,751 9.453 -~3,250 0.000 45.977 87.313 S Tape Yerlficat. ion l. istfn~ b!um.~erqer AlasKa Computino Center DFPT, 6200.000 SFtU,DTE SP.DTE 96,063 !DPH,DTE ~DO~.DTF 3.000 .T. MOF, D~E ITPr~.PTE .494,750 ~IXO.~TE CG~. DTE O. 000 TENS. DTE HTE~' .DT~ -79,500 PE~. bDT 3,367 OLS,BDT bU. b~T 34), 000 L[,,LDT SSg.LDT 3~ 8.750 b~P~.bD~ 2,275 BU~H,b~T CGm. bDT 0. 000 TE~S. bDT HTEN. [,DT -79.500 ~.*PO~. CNL 39.550 ~CNT CFb CFTC. CN~, 6~3. 766 SGR T~NS.CNL ~530,000 $GP. NGT O. 000 CGR. NGT UPAS. {tGT 0.000 W1~IG.NGT W4~4G. ~Gw 11.404 WbNG.N~T ~P~. ~GT 2,992 Cfi. MGT DEPT 6100.000 SFLU DTE InOF OTE 0,000 I~F,DTE IIRD:DTE 3~3.250 IIXO.DTE CG~.DTE 57,3~3 TEN~ DTE ~TE~.DTE 896.000 DP~.~.:bDT LU: t~DT" 387.500 Lb: bDT S8~.LDT 315.750 LSBV,bDT b,BR,.LDT 2.207 bUPH.bOT CG~.LDT 57.323 TENS,bDT . CFTO.CNL 627.01 ! 8O~.CNb T~NS,CNL 48~5.000 MR~,CNb SG~. NGT 86,278 CGR. N~T IJ~A~. NGT 3.941 WiNG N'GT W4N0.NGT 20.764 WbNG:NGT .PE~. NGT 2.99~ CS. NGT DMP? 6000000 SFLU. o oho .Or IIRD.DTE 168:375 IIXD:DTE CG~,DTE 6! ,3~8 TENS, DTE P~F. LD~ 2,768 ObS. LOT I..,U. t, DT 34 ~ . 000 Lb. bDT gSg. LDT 306. 750 LSHV bDT 1.,,~ R~. t, DT 2,275 bURN:bDT CGP. LD~ 61,388 TENS, LOT HTEa'. bDT 9~3,500 MPHI.CNL ~PC)~, C~L 43115 ~CNT.CNL g-MAR-1993 09:22 4 . 4 2.000 88.375 2530.000 22.549 1 ,625 1706.000 2.281 2530,000 39.740 2087.385 o.o0o 2.9092 0.0 0 256,3~2 6.8 7 1740.000 2 0 0,000 45,656 8 00 ~19 5 1706000 2 9.09 2166 . 3 268.272 14,950 1870.000 5,090 5.203 0.000 15.$08 4960 000 0,007 196.250 1706,000 2.285 4960000 20776 4 9 313 ILM.DTE IMPH.DTE CIDP.DTE IIRM.DTE MTEm.DTE RHOB.bDT OSS.bDT blTH.bDT 8SHV.bOT CALI.bDT UTEM.bDT THPH,CNb RCFT.CNb CGR.CNb MTEM,CNh THOR,NGT W2NG,NGT TE~S.NGT HTEN,MGT ILM',.DTE ~MPH.DT~ CIDP,DTE IIR~.DTE MTE~.,D?E RHOB,bDT OSS,bDT bITH,bDT SMV"bDT ALI,bDT ~TE~,bDT TNPH.,CNL RCFT,CNb CG~.C~b MTEM.CNb THOR,NGT W~NG NGT ~TEN.NGT ILM'.DTE IMPH,DTE CIDP.DTE IIRM..DTE MTE~,DTE RHOB,LDT OSS,bDT bITH,bDT SSHV.,bDT CALl,bDT ~TEM,LDT TMPH.CNL RCFT,CNb CGR,CN'b 3.307 3.326 611.500 282.250 87. 313 0.000 102.750 ~353.000 0.453 87.313 39.550 573.252 0.000 87,31] 0.000 132.184 2530.000 -79.500 2.098 1.874 473.500 440,000 0.023 134.125 000 135~'813 . 8~.313 4 .077 89 5 87.313 7.537 1.47,010 4885.000 896.000 192.000 183.625 87.750 2.268 0. 118.~1388 ,.055 87 750 41:477 540.099 6i.388 IbO.DTE IFRE.DTE CIMP.DTE SG~.DTE MRE$.DTE DmHO.LDT LS.LDT SS1.LDT S1, RH.LDT SGR.LDT ~RES.LDT TNRA.CNL CNTC.CNL CALI.CNL HTEN.CNb POTA.NGT W3NG.NGT ~TEM.~GT IbD.DTE IFRE.DTE CIMP.DTE SGR,DTE ~RES.DTE DRHO.LDT LS.LDT SSI.LDT S1. RH,LDT 8GR.bDT ~RES,bDT TNRA.CNL CNTC.CNL CAbI.CNL HTEN.CNb POTA..NGT W3NG.NGT NTE~.NGT It, D DTE CI~P.DTE SGR.DTE MRES.DTE LS.LDT SSi.bDT S1RH.LDT SG~.LDT MRES.LDT TNRA..CNL CNTC.CML CALI.CNL PAGE: 1.567 20.000 300,500 0.000 2,992 0,00! 363.000 215.375 2.273 o.0o0 2,992 3.3~9 20~4.751 9.453 -79.500 0 000 45:977 87,313 2,035 20.000 533,000 86,278 2,992 -0,003 413000 2 7:375 2,217 86.278 2 992 3:424 2126,1.60 9,813 896,000 1.844 43 t89 87~31,3 5 129 20:000 191.500 79.313 3,006 -0.007 366,750 210.750 2.305 79,313 3,006 3.566 2145.857 9,055 Verification Alaska ComDutinq Center DEPT. 5900.000 SFLU.DTE $~.DTE °0,688 IDPW.DTE IDOW.DTE 0.000 IMOF.DTE IIRD.DT~ 105,688 IIXD,DTE CG~.DTE 49.081 TENS,DTE HTEW.DTM 106~.000 DPMI.bDT mE~.[,DT 2.6~0 OLS.bDT LU.I,DT 3n7.750 Lb. LDT SS?.bDT 320.000 bSHV.BDT LSRW.LDT ~.20~ LURH.bDT CGm. LDT 49.0~1 TENS. bDT HTE~J.I,Dw 1062.000 NPHI.CNL ~!Pf~.CNL 37,974 RCNT,CNb C~TC.CNL 659,417 SGR,CNb TENS.CML 5245,000 ~RE$.CMb SG~.WGT ~1.360 CGR.NGT {I~Au.~GT 1,671 W~MG.NGT W4NG.NGT 6.410 W5NG.NGT M~MS.NGT 3.018 CS.NGT DEPT. 5800.000 SFLU.DTE SP.DTE B4.37~ IDPH.DTE IDO~.DTE 0,000 I~OF.DTE IIRD.DT~ 53.906 IIXD.DTE CG~, DTE 46. 202 TENS. DTE ~!TEM.DTE 955.000 DPHI.bDT DEF bDT ~,730 Lt!' bDT 337. 750 Lb.bDT Ssg:LDT 313,000 LSHV.LDT bSR}'!.LDT 2.~79 bUSH.bDT CGP.bDT 46.202 TENS.bDT HTEW bDT 955.000 NPHI'CNb N~O~:CNL 40.4~1 ~CNT,CML CFTC.CNL 7~2,573 SGR,CNL TENS.CML 4985,000 ~RES,CNb ~G~ ~GT 66,879 CGR NCT URA~[~GT 2,814. W~,NG:NGT W4NC,NGT ~0.956 W5MG,NGT ~E~,NCT 3.053 CS.NGT DFPT. 5700.090 SFL[!.DTE SD,DTE 10~,063 IDPH.DTE ~0~.DTE 0.000 I~OF,DTE IIRn.DT~ 99.1~5 IIXD,DTE CGP.DT~ 46,401 TENS.DTE HTEN,DTE 1097,000 DPHI bDT P~?. [,DT 3.148 OLS~LDT [,U. bDT 299. 750 LL. LDT ~S~. !.,DT ~07.750 LSHV. bDT 9-~AR-1993 09:22 3,~6 ~TE~4.CNb 61. 8 THOR.NGT 257.996 W2NG.NGT 12,793 TENS.NGT 1870.000 ~TEH.NGT 1.2,273 XL..DTE 8 680 IHPH.DTE 01000 CIDP.DTE 14 070 II~M.DTE 5245 000 HTE~.DTE 27.039 RHOB.LDT -0,003 O$S,bDT 224,250 LITH,bDT 1706.000 $$HV.bDT 61.360 CGR,CNb 3,018 ~4TE~.C~L 49.~1 THOR.NGT 199. 6 W2NG,NGT 5.342 TEN$.~GTMGT 1874.000 HT£N. 2~ 906 ILM.DTE 1:703 XMPH..DTE 0.000 CIDP DTE -0.889 ~I~M:DTE 49~5 000 ~TEM.DTE ~:343 RHOB,bDT 0.007 O$$,bDT 1,94,125 b~TH DT 4985.000 ~TE~:LDT 39,766 TNPM,CNb 2340.421 RCFT.CNL 66,~79 CGR,CNL 3 ~TE~.CNL 4~'~2 THOR.NGT 236~656 W2NG,MGT 2 988 TENS,NGT 1870[000 7.125 IL~,DTE 9,180 I~P~.DTE 0 0~0 CIDP.DTE 4i3 1 IIR~.DTE 5~10 000 ~TEM.DTE 18.256 RHOB.LDT 0 016 O$S.LDT 170~750 L, ITH,LDT 1706,000 SSHV,LDT 87 750 . 11 . 960.000 4923.500 8.570 9.289 115.063 !10.250 87.813 2.204 0.020 ~46.875 1355.000 8.883 87.813 38.698 599.856 49.08~ 87.813 5.940 84,402 5245.000 106~.000 16.969 17.188 53.438 55,906 87.500 2281 o:o 4 1 1-375 , [ iooo 8 703 87 500 38.796 673,651 46.202 87.500 6,75! 110.55~ 4985.000 955.000 9.~7~ 8.992 !08.875 101.938 87.125 .349 ..009 105.500 1355.000 HTEM.CNL POTA.NGT W3NG.NGT ~TEM.NGT ILD.DTE IFRE.DTE CIMP.DTE SGR.DTE MRE$.DTE DRNO.LOT bS.LDT $$~.LDT SIRH.[,DT SGP.L, DT MRES.LDT T~RA.CNI, CNTC,CNb C&bI.CNb HTEN.CNL POTA,NGT ~3NG,NGT MTE~.NGT IbD.DTE IFRE.DTE CI~P.DTE SGR,DTE MRE$.DTE DRHO,bDT BS.[,DT 851.~DT $1RH,LDT $G~.LDT NRES.LDT TNRA.CML C~TC.C~[, CAbI.CNL NTEN.CNL POTA.NGT W3NG.WGT ~T~,NGT IbD.DTE iFRE.DTE CI~P.DTE SGR.DTE ~RES.DTE DRHO.I.,DT L,S.LD? SS1.LDT S!~H.LDT PAGE: 923.500 2.018 45.842 87.750 8.461 2O.O0O 107.563 61.360 3.018 0.000 418.000 2~.9.000 2.203 61.360 3.018 3.324 2151.735 8.8~3 1062.000 1.705 35.256 87,813 17.500 20.000 58.125 66,879 3.053 0,001 363,000 215.500 2.273 66.879 3.053 3 329 2421:659 8,703 955.000 1.32! 21.9~2 87.500 9.063 20.000 61.94~ 3.084 -0.006 320.750 206.750 2.379 S Ta~e Verification I.,istlnq ~hlumber~er AlasKa Compt.]tlnm Center L$~.LDT 9.354 LURH.LDT CGP.LD? 46.40! TENS.LOT HTE~J. [,DT 1097.000 NPNI.C~L K~POD.CNL 36.699 DCNT.CNL CFTC.C~L J. 049. 996 SGR.CNL TFN$.CN[, 51t0.000 "RES.CNb SGD.NGT 6~ .94] CGR. NGT U~3.NGT 2.1~6 W1NG.NGT W~M~.NGT ~0.66! WSN~.NGT ~R~S. NGT ~. 084 CS. NGT DFDT. 5600.000 SFLU.DTE SP.DTE 98.563 IDPH..DTE IDQW.DTE 0.000 IMQF.DTE IIRD.~T~ ]~5.6~5 IIXD.DTE CG~,DTE 65.8)9 TEN$.DTE HTE~.DTE 969.500 DP~I.LDT ~Ew. LOT 2.87 3 OL$. bDT bU. LOT 305. 500 LL.LDT $Sg.LD? 303 250 LSHV.bDT LSR.~.LD? 2:]44 L[JRH.LDT CGP.SDT 65.839 TENS. LOT NTE~.LDT 969.500 NPHI.CNL ~!~OR.CNL 34.762 RCNT.CNL CWTC.CNL 694.290 SGR.CNb TF~$.CNL 4635.000 ~RE$,.CNL SG~.NGT ~7,672 CGR.NGT ~A~.NGT 2,97~ ~ING.NGT WaHC.~]GT 8.51.1 ,SNG.N¢;T ~ES.NGT ~.!00 C$.NGT 5500.000 SFL~.DTE 'SP~DTE 102,875 IDP ..DTE zr)o~.~TE 0.000 IMOF.DTE I!RD.DT~ 133,750 IIXD.DTE CG~.DT~ 56o0~4 TENS.DTE HT~N.DTE 1.054,000 DPHI.LDT UT 2 QLS,.LOT [,DT 302~2~0 Lb. LDT SS2iLDT 303.750 I, SNV,bDT bDT 2.346 LU~H..I, DT CG~.LDT 56.094 TENS. bDT NTEN.LDT 1054.000 NP~I.CNL NPO~.CNb 38.683 RCNT.CNL C~TC.CNL 6~.107 SGR.CNb 7'~.C~L, 4~05.o00 ~R~S.CNL SGR.NGT 76.799 CGR.NGT IJPA~,.~T 2 ~28 WiNG,NGT ~.4¢~G.NG~ 5o3~9 NLNG,NGT DEFT 5400.000 SFLU.DTE SP[DTE 68.375 IDPH.DTE IDOF.D~E 0,000 I~OF.DTE IIRh. D ~ ~5.578 II~D.DTE 9-M~R-1993 09:22 2.]65 CA~I.LDT 5110.000 ~TE~,LDT 34.312 TNPH.CNL 2450.580 RCFT.C~L 943 CGR.CNb 46.401 THOR.,GT 199.~60 10,661 1~61.000 HTEN.NGT 7.039 I[,~.DTE 6.887 I~PH.DTE 0.000 CIDP.DTE 6.328 IIR~.DTE 4635.000 MTEM.DTE 1~.466 RHOB.GDT 0 004 OSS.SDT 171:875 LITH.bDT 1706.000 SSHV.bDT ~.354 CAbI.LDT 0 ~TEM,LOT 87., 2 CGR.C~b 0 13. 0 0 87. 30. 954. 46. 95. 5110.. 1097. o 145. 143. 86. 2. 1355. 9. 86 361 668. 65. 86. 146. 4635. 969. 5.859 IL~.DTE ~ 6.523 IMP~,DTE .: 0,000 CIDP.OTE 153. 5 324 IIR~.OTE 151. 4805i000 ~TEM,DTE 85. 18 255 RHOB.LDT 2. 0 019 QSS.LDT O. 173i125 LITH.~DT 99. 1705 000 $$HV.bDT 1355 9 36~ CALI.LDT 9~ 4805,000 ~TE~.LDT 85. 1868,000 [tTgN,~GT 1054, 7~5. 0.643 ILM.DTE o.ooo 46¸ 53.' 22,. 20. 219 125 220 998 401 125 599 949 000 000 574 754 125 ~75 56] 01] 000 563 565 O87 80,O 000 500 ~03 238 125 875 939 349 015 938 000 609 938 284. 581. 0~4 9~8 188 979 000 000 719 563 047 ,359 SGR.LDT MRES.LDT TNRA.CNL CNTC.CNL CaL!.CNt HTEN.CNL POTA.NGT W3NG.NGT ~TE~.NGT ILD.DTE IFR~.DTE C!MP.DTE MRES.DTE DRHO.LDT LS.LOT 5$1.LDT $1RN.LDT SGR.i, DT MRES.LDT TNRA.CNL CNTC.CNb CALI.CNL HTEN.CNL POTA.NGT W3NG.NGT ~TE~.NGT I[,,D.DTE IFRE.DTE CI~P.DTE SGR.DTE gRES.DTE DRHO.LDT LS.!,DT SSi.LOT S1RH,bDT SCR.LDT MR~S.[,OT TNRA.CNb CNTC CNb C~bl:CNL HTEN.CNL POTA.~GT W3NG.NGT MTE~.~GT IL, DDTE IFRE."OTE CI~P. DTE SGP .DTE PAGE: 61.943 3.084 3.073 2871.524 9.219 i097.000 1.371 39.446 87.1~5 6.828 20.000 148.000 87.672 3.100 0.001 324.750 211.250 2.342 87.672 3.100 3.163 2188.21.0 9.398 969.500 2.14:6 46,809 86.563 6 492 o:ooo 160.250 76,799 3.125 0.003 3~4.250 212,250 2 336 76:709 3.125 3,486 ~098.376 9.609 1054.000 1,602 36.170 85,938 39 950 o:ooo 18,656 29.668 + IS ~a~e veri_~icatiom :~lUm.~erqer A!as~a Computtnq Cemter CG,.DT~ ~7.310 TENS,DTE H?E~.DTE ~070,000 DP~I.bDT PEV.LDT ~.06~ OhS,bDT LU.t,D~ 454.500 bb.bDT SS?,bUT 324,750 bSNV.LDT LSRU.I, DT 2.1~1 bURH.LDT CGP.LDT 27.310 TENS.bDT HTE~.I..DT 1070.000 NPB!,CNb MPOP.CM{. 37.885 ~CNT.CNb CWTC,CNb .692 9~9 SGR,CNb TENS _Nb 4665:006 ~RES CNb SG~.NGT 29.668 C~R.NGT URA~.NGT 0,3~! WlNG.NGT W4~!~.NGT ~.132 W5NG.NGT ~mE$.NGT 3.135 C$.NGT OFPT. 5]00.000 SF[,U.DTE SD.DTF 90,438 IDPH.DTE IDOF.DTE G,00() I~OF,DTE I!Pg.~T~ 70.500 IIXD..DTE CG~.DTE 51,841 TEN$.DTE HTE~.DTE 1127,000 DPHI,bDT PEF.LDT 2,133 OL$,bDT LU.LDT 406,000 LL.bDT SS~.LDT 317,500 [,SHV.bDT R bDT 2.178 bURN.bDT b ~GP:LDT 51,841 TENS,bDT ~!TEM.LDT ~127.000 ~PMI,CNb ~PO~.CNL 40,638 RCNT.CNL CWTC.CMb 682.549 S~R.CNL T~NS.CN5 46~0,000 MRES,CNb SGR,MGT 63,7~9 CGR.N~T URAW.NGT 1,61~ W1NG,NGT 4NC.N~T 4.~74 W5NG,NGT ~PE$.~GT 3.180 CS.NGT DEPT. 5200.000 SFI, U.DTE TM 95 500 IDPH DTE IDOW,DT~ 0:000 I'~OF,DTE IIRD,DTE 1.~1.563 IIXD,DTE CG~.DTE 61'099 TENS,DTE MTEM.DTK !~0~.000 DPHI.LDT PEW.bDT ~,918 OhS, bDT L!I.bDT 351,500 LL.LDT SSg,LDT 310.~50 LSHV,LDT I.,~R~ LDT 2 ~58 LURH,LDT HTE~.LDT 1!02,000 NPW!.,CNI, NPO~.CMI~ 39,336 RCNT.CNL CwTC.CNb 627.9~6 SGR.CNL TEM~,CNL 4355.000 ~RES.CNL SG~.MGT 77.337 CGR.NGT [~RAN.NGT ~.210 WING NGT .~NC.MGT 7.952 WbNG~N~T ~ES.MGT 3.207 CS.NGT 9-~AR-1993 09:22 4665,000 33,511 0,001 269,000 !706,000 2 117 4665 000 4 233~ 085 48O 29 668 3.135 2~.310 9 ,684 3,198 i910,000 13.203 14,641 0,000 000 29,263 ~]0!00~ 125 1701 000. 2. 2 4620.~0 43,.236 2212,243 63,729 3,180 51~841 215,812 342 .9o :ooo 6..430 7,191 0,000 3'893 4355,000 23 900 oloo 20 075 1704!000 2 268 4355.000 40,911 16,292 2277.337 3,~07 6 099 2541449 8,946 !903.000 ~TEM,D?E RHOB.LDT O$$.LDT blTH,bDT $SHV.bDT CALl.bDT ~TEM,LDT TNPH,CNL RCFT,C~b CGR,CNL NTEM.CNb TH~R.N~T W2NG..NGT TENS,NGT HTEN.,GT IL~,DTE IHPH.DTE CXDP,DTE IIR~.DTE MTEM,DTE RHOB.bDT O$S,hDT bITM.hDT SSHV,LDT CAbI,bDT MTEM,bDT TNPH,CML ~CFT,CNb CGR,CNL MTE~,CNL THOR,NGT W2NG,NGT TENS.N~T HTEN,NGT CIDP.DTE IlR~,DTE MTEM.,DTE ~HOB.LDT OSS,LDT LITH.LDT $SHV,LDT CALI,bDT MTE~..bDT TNPH.CNL RCFT.CML CGR.C~L ~TE~,CML THOR,NGT W2NG.~GT TENS.NGT NT~N,NGT 85.56~ 2.097 0.011 190,375 1355.000 10,477 85,563 38,518 626..345 27,310 85,563 3.363 44.776 4665.000 1070.000 14.719 15.211 68,250 64.438 84.688 2.167 0.011 165,~75 1355,000 84. 39.545 626,345 51.841. 84.688 6,156 102,564 4620,000 !!27.000 6.859 6,887 138.875 137.500 84.250 2.256 0,018 122 31.3 t 5 :ooo 9 711 40.677 581.957 6~.099 84,250 9,730 126.243 4355.000 1102.000 MRES.DTE DRHO.LDT LS.LDT SSI.LDT SIRH.LDT SGR.LDT ~RE$.bDT TNRA,CNL CUTC.CNI, C~LI.CWL MTEN.CML POTA.NGT W3NG.NGT IUD,DTE !FRE.DTE CI~P.DTE SGR.DTE DRHO.bDT bS.bDT SSI'bDT S1RH,bDT SGR bDT MRES:LDT TNR~.CNL CMTC.CML CAL~.CML MTEN,CNL POTA.NGT W3NG.MGT MTE~.~GT IbD.DTE IrRE,DTE CIMP.DTE DRHO.LDT LS.LDT SSI,LDT S~RH.bDT SGP.bDT MRES.LDT TM~A.CNL CMTC.CNL CALI.CWL HTEN,CNL POTA.MGT W3NG.NGT ~TE~.WGT PAGE! 3.135 -0.01.5 496,250 215,500 2,168 29.668 3.135 3,546 2301,536 10.477 1070.000 0,934 20.256 ~5.563 13.492 20.000 65,688 63.7~9 3.100 439.000 213.500 2 227 63:729 3.180 3,530 2262.547 8,852 !127.000 1,829 ~5,256 84.6~8 7,152 20.000 145,125 77,337 3,207 -0,003 377.750 214,000 2.271 77.337 3.207 3 474 9,711 1.102.000 1.673 34.791 ~4,250 :S 'r~ve ver.~lcatlon bistina .~hlum~ermer Alaska Complltin~ Center DFPT. 5100.000 SPLU.DTE SP.DTE ~B.688 IDPH.DTE IDqW.DTF' 0.000 IMOF.DTE ] IRn. DTE 61.563 ~IXD.DTE CGP. DT~ 51.513 TENS. DTE HTE~,~. DT~] 1065.O00 DPqI. LDT PEw. t, DT 2. 498 ObS. LOT LU. LDT 3~9. 509 LL. DDT SS~.[,DT 31q.750 [~SMV.LDT bSR~.LDT ~.199 LURH.LDT CGR. bDT K1.5 ~ 3 TENS.SDT HTE~ . LDT ~ 065.000 NPHI CNL NPO~.CNL ' 43.075 RC~T~C~L CFTC.CNL 6~3. ~70 SGR.CNL T~NS.CNb ~5o.000 ~R~S CNn SGP.NGT 65.403 CGR:NGT URAN.~G~ ~.891 WiNG.NGT WaN~.NGT 2.i~8 WSNG.NGT ~RS.NGT 3.230 C8.NGT DEPT 5000 000 SFI, U.DTE 8P ~DTF 97 ~500 IDPH. ~TE ~POF.DTE 0,000 IgOF.DTE I !RD.DTF 143.375 IIXD.DTE CG~ ~T~ 57.229 TENS, DTE HTE" ~ OT~: 1056. 000 DP.I.LDT PF:F.bDT 3.008 Ot, S.nDT t,U. LOT 389.750 LL.bDT SS9 bDT 323.000 L, SHV LDT CG~. LDT 57.2~9 TENS. bDT HTE~,I. LDT ]056.000 NPHI.CNb NPC]o CHL 44.4~4 ~CNT.. CNL Cw~C [ CNL 507. 250 SGR. CNL TENS.CNL 4020.000 MR~S.CNL SgP. NOT ~2. 828 CGR.NGT U~AN.NGT 3..4.~4 WING.NGT W4N~.NGT ~0.934 W5NG.NGT NP~8, NGT 3.273 CS. N~T DFPT. 4900.000 SFLU.DT~ SP.DTE 91.875 IDPN.DTE IIRO.DtE 103:313 IIXD:DTE CG~.DT~ 48.774 TENS D:. E HTEN.DTF 10~8.000 DPHI:LDT ~EF. LDT 2,617 OLS. LDT LI,!. I, DT 425. 500 Lb. LDT 8,5~.5DT 324.750 LSHV.LDT L S ~ ~.4. l, r) T 2.148 L U ~ ~I. b D T CC;P LDT 4~ 774 TEN~ LDT H'rE%,. t..,bT I0~8.000 NPHI:CNL NDOD.CN[, 42 ~48 ~CNT. CN[.~ C~T~. CNL 673: ~ 6g SGR .CNL 9-MAR-1993 09122 8.641 ILM.DTE 14.055 0.000 CIDP.DTE 0.040 IIRM.DTE 4150.000 MTEM.DTE 27.408 RHOB.LDT -0.005 OSS.LDT 224.750 LITH.LDT 1706.000 SSHV.LDT 2,205 CALI.SDT 4150.000 ~TEM.LDT 41.061 TNPH.CNL 2008.461 RCFT.CNb 65.403 CGR.CN5 .2 30 MTEM.CNL 5 .51J THORoNGT 231.~15 W~NG,NGT 7..7 TEN$,NGT' 1906.000 HTEN.~GT 5 IMPH.DTE 0.000 CXDPoDTE 5,508 IIR~°DTE 4020.000 MTEM.DT~ 27'299 0. 002 OSS.4DT 227!125 bXTH'BDT 1705 000 8SHV.LDT 2 ~o5 CAU~.5OT 4020i000 MTEM.LDT 47 648 TNPH.CNL 190~ 419 RCFT.CNL 8~2828 c~.c~5 273 MTEM.CN[, ~4 911 TENS.NGT lgo :ooo 7.887 8.820 IMP~,DTE 0. 0~0 CIDP. DTE 3880 000 ~TEM.DTE 30~639 RHOB.[,DT '0 007 OSS,.LDT 247~375 LITH'LDT 1704.000 SSHV,LDT ~.~54 CALI.SDT 3880 000 ~T~.SDT 40i633 TNPH.CNL 2322 672 RCFT 61 934 COr:CN~ !2.06] 11.344 71.125 78.563 83.563 2.198 0.018 137.875 1355.000 11.000 563 583.204 51,513 563 8 .:o 8 107.447 4150.000 1065.000 5.52~ 5.59 165.750 170.500 82.750 2.200 0.024 133.875 1354.,000 9.617 82.750 45:159 488.42O 57..229 82.750 9.462 132.207 4020.000 1056.000 113.313 1141000 82.3t3 2.144 0.019 154.875 1354 000 9:133 82. 3 636 342 a8:774 ILD.DTE IFRE.DTE CIMP.DTE SGR.DTE mRES.DTE DPHO.LDT L$.LDT SS~..LDT $~RH.LDT SGR.LDT MRES.LDT TNRA.CNL CNTC.CNL CALI.C~5 NTEN.CNL, POTA.NGT ~3NG.NGT ~TE~.NGT ILD.DTE XFRE.DTE CIMP.DTE SGR,DTE MRES.DTE DDHO.[,DT L$.LDT SS{.LDT $1~H.t, DT SGR.LDT TNRA.CN!., CNTC.CNL CALT.CNL HTEN.CNL POTA.NGT W3NG.NGT ~TEM.NGT ILD.DTE IFRE.DTE C!~D.DTE SGR.DTE ~RES.DTE DRHO.SDT LS.LDT SSI.LDT S1RH bDT SG~[LDT ~RES,LDT TNRA.CNL C~TC CNL CAbIiCNL PAGEt !3.883 20.000 88.125 65.403 3.230 -0.002 419.500 218.1~5 2.207 65.403 3.230 3.571 ~121.664 11.000 1065.000 1,592 30°851 83,563 5 980 o:ooo !78.625 82.828 3.273 0.004 422.000 222.250 2.178 ~2.928 3,273 3,834 1874.5~0 9.617 1056.000 1,368 34,791, ~2.750 8.656 20.000 117 375 61:934 3,328 -0.004 460.250 219.500 2 166 3.328 3.411 2337.~94 9.133 10 IR Taoe Vertftcat~.on List~no :blumberoer AlasKa Computing Center T~.t;$. CNb 38R. 0.000 MRFS.CNL $G~.NGT 61.934 CGR. UP~N.~GT 1.7ql W1NG.NGT Wa~;C, NGT 2,137 W5WG,NGT ~P~S. NGT 3,3~8 CS.NGT DwPT. ~800,000 8FLU,DTE $P.DTE 94,750 IDDH.DTE I~O~.[)TE 0.000 IMOF.DTE II~m.DTF 114.875 IIXD,DTE CGR.DTE 42,0~0 TENS,DTE HTE~.DTM 9R6,000 DP~I,LDT PEW. LI)T 2. 584 ~[,S, D~T LI.T. LDT 415,500 LL.LDT S3~.LDT 3~0,250 LSHV,LDT I,~.LDT 2,160 LUPH,L~T C(;P.LDT 42,010 TENS, LDT HTEM,LDT 9~6.000 NDHI.CNL NPO~.CN~, ~35,878 RCNT.CNL CFTC.CML 786,677 S~R,CNL T~NS.CMb 37~0,000 ~RES,CNL SGP, NGT 60,034 C~R. N~T U~AN.HGT ~,453 W1NG.NGT W4hG,NGT 7,968 W5NG.NGT ~ES. 5'GT 3. 355 CS.~GT D~pT. 4700.000: SFLU.DTE SP. [')TE 93.625 IDPH,DTE ~.DOF.~T~ 0.000 IMOF,DTE ~7~D.{)T~ 93,750 I!~D.DTE CGP,DTE 41.850 TENS. DTE HTEK', DT~ 934.000 DPHI.LDT PEW. LDT ~, 627 OLS, bDT LU.LDT 408.750 5[, LDT SS~,bDT 3] 8,500 I.,$~u. bI)T 2,174 LURH.LDT CG~,LDT 4~.850 TEN&.LDT HTE~.LDT 9~4.000 NP~I.CNb ~O~,CUL 36.0~7 ~CNT,CNL CFTC.C~5 72~.58! S~R,C~L T~Ng,CNL ]435.000 ~ES,Ct~L SG~. NGT 55. 881 CGR UPA~3.NGT 1.910 WING,~GT W4NG,NGT 4.264 W5NG m~E~. ~JGT 3' 375 D~P'r. 4600 000 SFt, U. DTE SP DTE 1].~438 IDPH,DTE IBOw~f)TE 0.000 I~OF,DTE ITRD.DTE ~20.18~ IIXD,DTE H~F~'. DTE !0~6 500 DPUI.bDT PE~. I. D 2: 537 0I,,&.. bDT LU.LDT 385.750 bt BDT gsa. [,,,D~ 3~.4,250 LSHV:BDT 9-MAR-~993 09:22 3.328 48.774 185,897 6.410 1908.000 8.~03 7,840 0,000 373~ '887 ,000 30,416 -0 003 242~375 1705.000 373~ 16~ o06 39 907 2434 542 60 034 3.355 42,010 185.259 3.984 190!.000 14.328 9.969 0.000 7.~10 3435. O0 28,925 .5 1705 0 0 2,178 343~,000 3 .841 2304,929 55 3i3 5 41.850 !87,633 ~ 529 190 '000 5,758 7,359 0.000 5.016 3700.000 223'i 0°1 125 1705.000 MTE~.CNL THOR.NGT W2NG.NGT TEN$.NGT HTEN,NGT ILM.DTE !HPW.DTE CIDP.DTE IIR~.,DTE MTEM.OTE RHOB.BDT OSS.,bDT 5ITH,5DT $$HV,LOT CALI.bDT MTEM.LDT TN~H,CNL RCFT.CNL CGR.CNL MTEM.,CNL THOR.NGT W2NG.NGT TEN$.NGT RTEN.NGT IL~.DTE IMPH.DTE CIDP,DTE MTEM.DTE RHOB.bDT 'OSS,SDT LITH.bDT SSHV.LOT m?Em.bOT TNPH,CNL RCFT,CNb CGR,CML mTEM,CNb THOR,NGT W~NG.MGT TENS.MGT HTEN,NGT ILM,DTE IMPH.DTE CIDP,DTE IIRM,DTE ~TE~.DTE RHOB.LDT OSS,bDT GITH,LDT SSHV.LDT 82,313 5,923 112,179 3880.000 1028.000 7.73~ 7.n20 127.500 122,125 81,813 2,148 0,008 151,500 1354.000 B.977 81.~13 35.889 689.797 42.010 81.813 5.382 100.598 3730.000 986,000 10'438 10 875 ~.oo1:t88 90.688 80,563 ~ I73 0.i031 147 375 1354,000 11,258 80,563 35 786 41,850 80 5 3 3435.000 934.000 6.68~ 135 50 14! 000 80 250 142.750 1354.000 , POTA.NGT w3NG.NGT ~TE~.NGT ILD.DTE IFRE.DTE CI~P.DTE SG~.DTE HRES.DTE DWMO.LOT L$.L~T S$1..LDT SIRH.LOT SGP.LDT MRE$.t, DT TMR~.CNL CWTC.CNL CALI.CNL HTEN.CNL POTA..~GT W3NG,NGT MTE~.~GT ILD.DTE IFRE.DTE CI~P.DTE 8GR.DTE MRES.DTE DRHO.LDT bS.LDT SS~,LDT SGR.LDT ~RES.LDT TNRA.CML CNTC.CML CALI.C~L HTEN.CNL POTA.MGT W3NG.NGT MTEM.NGT ILD.DTE IFRE.DTE CI~P.DTE SGR DTE DRHO.LDT LS.LDT SSI,LDT S~RH,[,DT PAGE: 11 1.6~9 26.709 82.313 7.707 20.000 127,813 60,034 3.355 -0.013 450.250 213.875 2.213 60.034 3,355 3.359 2430.85~ 8.977 986.000 1.3~6 35.857 ~1.813 9,648 20,000 91.938 55.881 3.375 4~0,001. 9.750 220,000 2.178 55.~81 ~.375 3.347 231.8,296 11,258 934,000 1,196 24.520 80.563 7.2R5 20.000 ~47.875 85.394 3.361 0.006 416,000 222,500 2.1~2 ~hlUmberoer Alaska ComputinO Center LgRu. LDT 2,205 t, II~H.LDT CG~.LD* 64.65~ TENS.LOT HTE~.LDT 1016.5~0 MP~I.CNL 5, mO~.CMb 40,3~7 ~CNT.C~L CFTC.CNL 5&7.5a8 SGR.CNb TFNS.CML 3700.000 ~RES,CNb SG~.~CT 85.]~4 C~R,NGT U~A~.~GT 2.8~3 W1NG.NGT W4ti~.NGT ~.5~9 W5NG,NGT u~K~.~G? 3,361 CS.WGT D~PT. 4500.000 SFLU.DTE SP.DTM 101,875 IDPH,DTE ID~ ~TE 0 O00 IMOF.DTE IIRn:DTE !01:I~8 IIXO'DTE CG~.DTE 46.953 TEN$.DTE HTE~.DTE 10~2.000 DPHI.bDT PEm LOT 2 484 OL$.LgT $S?.LOT ~23.000 bSHV.bDT LSRN.!,DT 2.146 LURH,LDT ~G~.I..,D~ 46,953 TENS.bDT HTE~.LDT 1052.000 NPMI.,CNL NPO~,CNL 40,9~0 ~CNT,CNL C~TC.C~L 6~9,000 SGR.CNb TENS.CNL 3405.000 MRE$,CNI~ SG~.N~T 60,!43 CGR.NGT [/~A~.~GT 1,795 WlNG.NGT WdM~.NGT 3 198 N .. ,. WL.G NGT u~E$. ~GT 3. 404 CS: MGT D~p~ 4400 000 SFLU.DTE SP:DTE 10723!3 IDPH.DTE TnOF.DTE 0,000 IMOF.DTE I!RD.DTE 113.938 IIXD.DTE CGm.DTE 50.874. TENS.DTE }iTE~.DTE 1066.000 DPNI.bDT LU[L[)T 4]7:750 [,b:LDT SS2.LDT 322,750 LSHV.LDT L, SR~.LDT 2 133 LURM.bDT CGP.[.,DT 501874 TENS.bDT HTE~.L!.)T t066,000 NPHI,CNb NPOP.CNL 44 207 RCNT.CNb CFTC.CNL 588:609 8GR.,CNL TFN$ CNL 3500 000 ~RE$.CNb '~:~T 64:8.4 W~HG.NGT 8,547 , 5NG.NGT ~T. 4300.000 S~U..~TE S~.DTM 100,250 IDPH.DTE 9-~AR-1993 092~2 2.~11 3700.000 43.97~ 1~64.555 85,394 3,361 64,656 297,441 10,661 193X.n00 8,094 8.797 o.ooo 4.~56 3405,000 31.615 -0,012 248,000 1705.000 2,148 3405,000 4{.471 2326.486 60,143 3 404 46i953 211,087 2.132 !942,000 7,184 7,867 0,000 6 402 35~ 000 867 -0 008 255 125 1705,000 02.~39 35 0.000 43,994 2150 148 642884 414 221.154 1945 000 11 094: 0 000 6:746 CAbI.bDT MTEM.LDT TMPH.CML RCFT.CNb CGR.CNb MTE~.CNL TMOR.~GT W2NG.~GT TEN$.gGT HT~N.NGT Ib~.DTE IMPH.DTE CIDP.DTE IIRM,DTE ~TE~.DTE RH.OB.LDT OSS bDT kITH:bDT SSMV.LDT CAbI,bDT ~TEM,LDT TNPM.CNb ~CFT.CNL CGR,CNb MTEH,CNb THOR.MGT W2NG,NGT T~N$,NGT HTEN.NGT ILM.OTE IMPH.DTE CIDP DTE IIR~:DTE ~TE~,DTE RHOB,LDT OSS,LDT LITH,bDT SSHV.bDT CALl,bDT MTEM,bDT TNP~,CNb RCFT,CNb CGR,CNb ~TE~:,CNL THOR,NGT W2NG,NGT TENS,~GT HTEN.NGT ILM,DTE IMPH.DTE CIDP,DTE IIRM,DTE 9.820 SGR.bDT 80.950 ~RES.LDT 40.696 TWRA.CNL 564.747 C~TC.CNL 64.656 CALI.CML 80.250 HTEN.CNL 8.679 POTA.NGT 132.J96 WLNG.NGT 3700.000 !016.500 8,148 ILD.DTE 8.9~4 IFRE.DTE 113.563 CI~P.DTE 115.938 SGR.DTE 9,375 MRES.DTE 2,128 DRHO.LDT 0,007 LS.LDT 166.500 8SI.LDT 1353.000 SIRH.bDT 9,336 SGR.bDT 79,375 ~ES.bDT 42,469 TNRA.CNL 574,581 CNTC,CNL 46,953 CALI,CML 79..375 HTEN,CN!, 5,706 POTA.~GT 76,759 W]NG.NGT 3405.000 ~TEM.NGT 1052.000 ,. 7 ~87 IbD.DTE 7:88 IFRE.DTE 1.27,063 CINP.DTE 127.750 SGR,DTE 78.813 M~ES.DTE 2.~24 DRHO.LDT 0.019 LS.bDT 163,750 SSi.LOT 135~.000 StRH.I,.,OT .133 SGR.LDT 531 483 CNTC.CNL 50:874 C~5I.C~L 78.813 HTEN.CML 6.132 POTA.NGT 98,291 WLNG.NGT 3500.000 MTE..~.NGT 1066.000 9,531 ]LD.DTE 9.953 IFRE.DTE !03.~13 CIMP.DTE 99.~50 SG~.~TE ~5,394 3.361 3.650 !946.521 9.820 1016.500 2.037 43.710 ~0.250 8,672 20.000 121.313 60.143 3.404 '0.0~0 462,750 210,6~5 2.227 60.143 3.404 3,474 2248.282 9.336 lo52.000 1.675 30,917 79,375 7 7~2 2020o0 133,375 64,884 3,414 -0,009 474.0n0 2~7.500 2,170 64.884 3.4~4 3,595 2137.350 9.133 1.066.000 1,773 44,872 78,813 9.367 20,000 1.00,438 60,496 IS ?a~e v~rificat~o~ Listino. '.hlumberqer ~lasK8 Comput. in~ Center cG,~. t~'r~ 41.313 TENS. DTF. oF.~. bDT 2. 645 ObS.L,~T L~. bDT 558. 000 bt. LOT SSg. l,l)~ 334.500 LSNV.LDT l,.~R~,, bDT !. 9~ 1 LUSH. bDT ~G~. t,I.>T 4~.3~ 3 TENS.bDT HTF~.'. I,DT 1050. 000 NPNI .CNL t..~PO~. C~L 40.923 RC~T.Ct~b CWTC.CNb 598. 550 SGR.CNL T~NS.CN[., 3300.000 MRES,CNL SGR. NGT 60. 496 CGR. NGT Um~W.NGT 2.611 W1NG.NGT W4NC.NGT 6,897 WtNG.NGT "PE~."~G· 3,408 CS, NGT DFPT. 4200.000 SFLU.DTE SP.DTE 122.750 IDPH.DTE I~Qr. DTE 0.000 IMOF.DTE ITRD.~TE 127.438 IIXD.DTE CGP.~TE 60.695 TEMS.DTE HTE~.D?E 969.500 ~P~I.LDT P~F.bDT 2.916 QLS.LDT 1,[~ bDT 407.500 LL.LDT Rg bDT 2.164 LURH..tDT L~G~,. :.[,DF 60. 695 TEN~.LDT HTEN.bDT 969.500 NPHI.CNb NPO~.CNL 46'803 RCNTeCNL CrTC.CNL 501.037 SGR.CNL TFN$,CNL 3265.000 MRE$.CNL SG~.NGT 84.352 CGR.NGT U~AN.NGT 3.220 W~NG.NGT W4UC.NGT 12.8~t WtNG N~T ~P~.NGT 3.463 CS:NGT t~P?. 4100.000 SFbU.DTE SP.DTE ~3.625 IDPH.DTE IDOm. DTE 0.000 T~OF.DTE ITRO.~TE 83.698 IIXD.OTE CG~.DT~ 43.7~8 TENS.DTE ~T~.DTE 1042.000 DPMI.LDT PEF.I,i)T 2.281 ObS. L~T !~!.~.~,I)T 459,500 I,,b. LDT SS~.[,~T 3~3.500 bSHV'LDT LSat, !,r)m 2 1.02 LURHiLDT ltTE~!. I, DT 1(')42,000 NPHI.CNL NPOP.CNL ~3,636 PCNT.CNb TEMS.C~!L 3135.000 IRES.CNb 8G~,NGT 51.53! CGR.NGT ~mA~.~GT !.054 W1NG,MGT W4~IG.NGT 5,330 W5NG NGT ~ES.NGT 3.494 'CS~NGT 9-~AR-1993 09:~2 3300.000 ~TEM.D?E 41.270 RHOB.bDT 0.0~2 O$S.LDT 330.750 bITH.LDT 17o5.ooo ss.v.~oT ~.oo2 3300.000 ~TEM.bDT 45.87J TNPH.CNL 2340.42~ RCFT,CNL 60.496 CGR,CN5 3.408 ~TEM.CNL 41.313 THOR,NGT 193.~03 W2NG.NGT 2 ~99 TENS,NGT 1949~000 HTEN,gGT 6.297 6.996 .000 .930 3265.000 30.337 0.010 241.~00 1705. O0 2.180 3~65 000 48 ~40 1893 91 60 695 298 077 7 479 1943 000 !961 i 9§6 0 0 7 33 067 0.00.4 273.~50 1705. O0 41 186 205'7 081 51 531 3:494 43.788 0 IbM.DTE IMPH.DTE ClOP.DTE IIRM.DTE MTEM.DTE RHOB.bDT O$S..LDT bITH,LDT $$HV,LDT CAI.,I,LDT ~TEM.tDT TNPH.CNb RCFT,CNL CGR,CNL MTEM..CNb THOR.NGT W2NG.NGT TENS.N~T HT~N.NGT IMPH.DTE CIDP.DTE IIRm. OTE MTEM.DTE RHOB,bDT QSS.bDT ,ITHbDT SHV:.LDT CALI.bDT ~TEM.LDT TNPH.C~L RCFT.CNL CGR.CNL ~TE~.CNL THOR.NGT I~2NG.NGT TENS..NGT HTEN,~GT 78 0 211 1354 44 54.l 41 78 3 105 3300 1050 6 6 142 142 77 2 0 144 1353 8 77 46 453 60 77 B 1!.6 3265 969 10 1,0 91 90 76 2 0 180 1353 11 76 49 534 43 76 5 7~ 3135 1042 .250 .96q .011 .625 .000 .273 .250 .390 .259 .313 .250 .561 .747 .000 .000 .598 .742 .875 :87s 313 ,149 .010 .750 .O00 .664 .313 .939 ,996 ,695 .313 .802 :453 .000 .500 .492 .656 .625 :.188 875 O24 875 000 .414 .875 .679 .842 .788 .875 336 [495 :000 000 MPE$.DTE DmHO.LDT tS.bDT SS1.LDT S1RH.LDT SGR.LDT MRES.bDT TNRA.CNL CNTC.CNt., C~bl..C~b HTEN.CNI! POTA.~GT W3NG.NGT MTE~.NGT ILD.DTE IFRE.DTE CIMP.DTM SGR.DTE mRES.DTE DRHO.LDT LS.bDT SSI.bDT S1RH.LDT SGR.LDT MRE$,LDT TNRA.CML CNTC.CNL CALI.C~L HTEN.CNL POTA.NGT W3NG.NGT ~TEM.~GT lbD.DTE IFRE.DTE CIMP.DTE SGR.DTE MRES.OTE DRHO,bDT L$..LDT SSI.LDT 8!RH.LDT SGR.bDT ~PE$.L, DT TNRA.CNL CNTC.CNI, C~LI.CN5 HTEN.CNI, POTA.NGT W3NG.NGT ~TE~.NGT PAGC: 13 3.408 -0.022 609.500 2t7.~5 2.075 60.496 3.408 3.709 ~175.046 9.~73 1050.000 1.787 39.080 78.250 6.887 20,000 148.250 84.35~ 3,463 -0.017 445.250 211.500 2.230 8.4.352 3.463 3.82! !886.223 8.664 969.500 1.752 47.009 77,313 1.0,648 20.000 93.750 51.531 3.494 503.250 218.375 2.143 51,531 3.494 3 588 ~095~372 11.414 1042.000 1,5!2 31.983 76.875 r8 "tane Verification bj.$tJ, na ~hlumbero~r Alaska Comput.~na Center DFPT 4000,000 SP~DTF. 89.438 [nOW "TE n.O00 I T ~,'">. 9TE 95,250 C.(;n...mT~ 41.646 }{q'Et~. DTE 951. 500 PEF.UDT 2.445 hD. bDT 454,750 ,,SS;;.t, DT 317.0nO cOP.bDT 4.1. 646 HTEN.LDT 951,500 ~O.~ CML 41.653 C~TC.' ¢~[, 556,805 T ,)'$ C~b 2950,0.00 MGR. NGT 55,969 U~A~. NGT I ,950 W 4N~. ~'GT 2,132 ~PES.NGT 3,516 DEPT. 3900.0.00 SD.DTE 99,563 I~OF.DTE 0,000 I~R~,DTE 94,188 CGm.DTE 69,891 HT~t~,DTE 966,500 PEF.[,,DT 2.887 LU.!,,DT 446.250 SS2,bPT 327,250 LS~U,LQT 2.1~7 CGP.LDT 69 891 MTE~.LDT 966[500 MPO~.CML 49,203 C~TC.CML 432,9~4 T~NS.CNL 2980.000 ~G~,NGT 94,7~0 U~Ag. NGT 3.388 W~.N~T 11.727 M~ES.NGT 3.535 T 3800 000 ITr~.DT~ 74.250 H?EN.DTE 990,500 PE~.L, DT 2.277 bU. t. DT 534,500 SST.bDT 334,250 bMRN.LDT 2.020 CC~.L, OT 4~.460 HTEN.bDT 990.500 NPO~.C~L 43.609 CFTC.CNb 625.734 SFLU.DTE IDDH.DTE IIXD.DTE TEN$.DTE DPPI.bDT OhS.bDT bb,LDT bS~V,LDT LURH.bDT TENS,bDT NP~I.CNb RCNT,CNb MGR.,CML ~RES.CNb C~R,NGT W~NG,NOT W5NG.NOT CS.~GT SFbU.DTE IDPH,DTE IMOF,DTE IIXD:.DTE TEN$.-DTE DPHI.bDT oLS.bDT LL,LDT bSHV.bDT bURN.bDT ENS.bDT PHI,CML RCNT,CNL SGR,CNL ~RES.CNb C~R.NGT WlNG.. qT w5MG.~GT CS,NGT DTE DPH .. I~OF.DTE II×D.DTE TEMS.DTE DPHi.LDT OLS.LDT !,b.bDT bSHV,LDT [,U~H,LDT TENS.LDT ~PHI.CNL ~C~T .CNb 9-~AR-1993 09:22 9.070 IL~.DTE 9.477 IMPH.DTE 0.000 ClDP.DTE 4.957 IIR~.DTE 2~50.000 MTEM,DT~ 33.303 rHOB.bDT 0.000 QMS.bDT 268.750 LITH,bDT 1705.000 SSHV.GDT 2.115 CaI, I.bDT 2950.000 MTEM,LDT 41,610 TNPH,CNL 2030,587 RCFT,CNL 55,969 CGR.CNb 3.516 MTEM,CNb 41,646 THOR,NOT 183,369 W2NG,NGT 6.397 TENS,NOT 1948.000 HTEN,NGT 8.~89 IbM.DTE 9.664 IHPH.DTE 0,000 CIDP.DTE 29~ 0 MTEM.DTE 6 PHOB,bDT -o.oo 22~ CALX,bDT 3.~ 5 MTE~ CML 1~.609 IL~,DTE I .383 IMPN,DTE 0.000 CIDP,DTE 291~:~00 ~TE~ DTE 3 15 ~HOB:bDT 0.00~ QMS.bDT 316,500 bITH.GDT 1704,0(10 $SHV.LDT 2.025 CALI,bDT 10,000 ~TEM,LDT 2940.575 TNP~.C~L 2t85 623 RCFT.CML 44:760 CGR.C~L 105.4 102.1 76.0 2.1 0.0 178.2 1353.0 10.7 76.0 42.5 497.7 41.6 76.0 5.4 89.5 2950,0 951.5 1.03.3 101.'1 75.1 2..~ 0.0 15i.6 0 75 1 50:7 388 5 75.1 10.2 ~52.4 2980.0 966.5 11 8 80.6 79.6 75.2 2.0 0.0 224.0 i353.0 75.2 42.7 583.2 4~ .~ 50 II, D.DTE 38 IFRE.OTE 3g CIMP.DTE 88 S~R.DTE O0 ~PES.DTF O1 D~HO.LDT 40 LS.!,DT 50 SS1.LDT 00 S1RH,LDT 19 SGR.LDT O0 MRES.LDT 07 TNRA.CNL 80 CNTC.CNL 46 CAbI.CNL 00 37 POTa. NGT 52 W3NG.NGT 00 ~TEM,NGT 00 IbD.DTE I IFRE.DTE 75 CI~P.DTE 25 SG~.DTE 88 MRES.DTE 18 D~HO.LDT 31 LS.LDT 25 SSJ,.L, DT 00 S1RH.bDT 22 MGP.LDT 88 MRE$..LDT 03 TN~A,CNL 41 CNTC,CNU 9! CALI.C~L 88 HTEN,CNL 4! POTA.NGT 52 W3NG.NGT 00 MTEM.NGT 00 91 ILD.DTE 88 SGR.DTE 50 M~ES.DTE DRHO,bDT 08 I,$.LDT 00 SSI.LOT 00 Sl~H.LDT 20 MGR.LDT 50 MRES.b~T 07 TNRA.CM[, 04 C~TC.C~[, 6O CAbI.CNL PAGE: 9.281 20.000 105.875 55.969 3.516 -0.009 496.250 219.000 2.145 55.969 3,516 3.595 1992,037 ~0.7~9 951.500 1.349 19.190 76.000 9.445 20,000 104 875 94:780 3.535 0.000 484,000 223.750 2 ~7 912780 3.535 3.958 174 1. 484 9.422 966,500 1,99~ 41.578 75.~8 12.039 20.O00 81.500 44,760 3.5~7 -0,019 583,5OO 217.250 2.098 44.760 3.527 3,464 2223,783 9,820 14 [~ Te~e Verif{catio~ Listina :hlUmberqer Alaska Computinq · Center TENS.CNL 2910.000 SGu.NGT 44.760 IlPA~'.NGT 0.449 W4~C.NGT 2.137 ~PE~.NG? 3.527 OCPT. ]700.000 SP.D?E 84.875 ~UoV.OT~ o ooo Ilgg.n~E 8i2813 CG~.DT~ 53,670 MTEW,DTF 9a~,500 FE~.LDT 2.807 Lt~.LO? 416.500 S$~.[,Dr ]24.0o0 CGU.LDT 53.670 I.,9T 941o50~ TEU. .. 43.00. UOu.C~t CFTC.CNL 519.800 TEN~.CNL 2980.000 SG~.NGT 74.255 WdH~.NGT 2.137 ~RES.~GT ].578 s~.o'r~ 73.s63 ioo~.~ o.ooo OT~ ~ ooo om~ o~o ooo LOT 52.4'500 LO· 2.033 CGP:LDT ]4,694 .m~..t, um 960 0o0 CFTC.CN[. 549.91~ m~.~.c~ S~.~T 43.~ Wd-NC.NGT 1.066 ~P~S,NGT 3,56I D~PT. 3500,000 SP.DTE 66.?50 i~o~ o~ o ooo CG~.DTE 32.755 ~E~.t, DT 2.777 LU. LOT 554. 500 ~$~. [,0~ 346'000 ~RDS.CNL CGR.NGT WlMG.NGT w5NG.NGT CS. NGT SFLU.DTE !I)PH.DTE I~OF.D?E IIXD..OTE TENS.VTE DPNI.bDT OLS.LDT Lb,bDT 5SHV.L~T LUSH.bDT TENS.bDT NPHI.CNb ~CNT.CNL SGR.CNL MRES.CNL CGR.NGT WlNG,NGT w5NG.NGT CS.NGT SFLU.DTE rDPH.,DTE XMOF.DTE 'IIXD.DTE TENS'DTE DPHI.LDT OLS.bDT 'LL,LDT LSHV.LOT LUPH.LDT TENS. bDT NPHI.CNL RCNT,CNL SGR.CNL ~RES.CNL CGR.NGT w1NG.NGT WLNG.NGT C$.NGT $F[,U.,DTE IDPH.DTE I~QF.DTE IIXD.OTE TEN$'DTE DPNI.LDT OLS. LDT I,L.LDT LSHV.LDT 9-MAR-1993 09:22 {.527 MTE~.,CNL 41.460 THOR, NGT 150.641 W2NG. N~T 3.205 TENS,NGT t944.000 {4TEN. NGT 8.594 11.1064 IMPH.DTE o. oo C~U~.UTZ ~.404 ]o.9~o ~HO~.5~T O.0Z4 248.~25 LITH.LOT ~7o4. oo 2.166 CAI, I. bDT 1867.114 RCFT.CgL 74. ~ss CGR.CN~ 3.578 ~TEM,CN5 5),670 T}{OR,NGT 255.342 W2NG,NGT 11.752 TENS,NGT 1970.000 "TEN.NGT 9.477 ILM,DTE 11.133 IMPH,DTE 0.000 CIDP'DTE 4.375 IIRM,DTE 2970'000 ~TB~ DTE 38..092 RHOB~bDT 0,000 ~S$ bDT 308,000 bITH,bDT ~. 705,000 ~SHV, LDT 2.035 CA51.5DT 2970.000 ~TE~.LDT 45,620 TNPH.CNL 2118,946 RCFT.CNL 4].883 CGR.CN5 3 561 MTEM.CNL 34~694 142 857 W2NG. N~T 6.397 TENS,NGT t981.000 MTEN, NGT 11,789 IL~,D...ET "' 12.797 IMPH,DTE 0.000 CIDP.D, ET I. 068 IIRM.DTE ~995.000 ~TE~,.DTE 39.464 RHO~'LDT o. oo i oss. 326 000 LITH,LDT 75.250 4.684 64.103 2910.000 990.500 10.766 10.727 89.563 87.938 74.6~5 2.140 0.012 1.34.875 1353.000 10.406 74.6~5 42.946 479.812 53.670 74.625 7.896 105.769 2980.000 941.500 10.734 11.031 89.750 88.~88 74. 75 2'.i21 O. lB 2 5O , 4]:ooo I025~ 44,218 488.519 34.694 74.375 4.R87 7~.495 ~970.000 960.000 11 898 1~2o78 78.063 74. 3 1.999 0.025 217.6~5 1352.000 HTEN.CNL POTA.~GT W3NG.NGT MTE~.NGT ILD.DTE IFRE.DT~: CI.P.DTE SG~.DT~ ~RES.OTE LS.LOT SS1.LDT S1RH.LDT SG~.LDT ~RES.LDT TNR~.CNL CNTC.CNL CALI.CN[. HTEN.C~L POTA.NGT W3NG.NGT MTEg. NGT !5D.DTE IFRE.DTE CINP.DTE SGR.PTE DRHO.LDT LS.LDT S$1.LDT S!RH.LDT SGR.DDT ~RE$.LDT Tw~A.C~L C~TC.CN[, C~LI.CNL HTEN.CNL POT~.NGT W3NG,NGT ~TE~.NGT I[,D.DTE IFRE.DTE CIMP.DTE SG~.DTE ~ES,.DTE DRHO.LDT LS.LDT S$1.t, DT ${RH.LDT PAGE: 15 990.500 1.522 33.120 75.250 10.891 20.000 93.188 74.255 3.578 -0.008 456.750 217.125 2.182 74.255 3.578 3.815 1867.150 10.406 941.500 1.521 37,393 74.6~5 10.859 20.000 43.88.3 3.56! -0 012 5702500 221,125 2.0~0 43,883 3.561 3,775 2014.867 ~0,258 960.000 1.037 17.058 74.375 1,2.461 20.000 82.750 41.653 3.539 0.000 603,000 2~9.750 2.000 ChlUmberqer Alaska Comput~nn Center LSR~4. LBT 1,999 LURH. bDT ~GV.t. DT 32,755 TENS,bDT P.. TE%'.. LD~ 97~,000 NP~I.CNL NPOR,CML 47,997 ~CNT.CNL CWTC,CNG 490,542 SGR,C~L TENS.CML ~995,000 MRES,CNL 8G~. NGT 41. 653 CGR, NGT U~A~.UGT 1,21~ wlNG,NGT w4Nc,~GT 3,440 W5NG,NGT uPES. NGT 3,5~9 CS,NGT DEPT. 3400.000 SFLU,DTE SP.DT~ 76,813 !DPN,~TE l~Ow DT~ 0,000 I,OF,DTE I'IR~DT~ 93.563 IIXD,~TE CGm, DTE F3,190 TENS, DTE [-{~E~'. DT~ 1006.500 DP~I.%DT PEW. bDT ~, 855 QLS, bDT LU,L~T 4! ~,750 Lb, bDT SS~,LDT 318,000 LSHV.bDT bSRR.LDT 2,156 bURR.bDT CG~.LDT 5].190 TENS. bDT WTE~~. [,~T 1006,500 NPHI, CML NPOP,CML 41,691 qCNT, C,L CFTC,CNL 529, ]05 SGR,CNL 30 5.000 SG~, NGT 72,55 ] CGR: NGT UPA~, NGT ~,636 WlNG,NGT w4NG,NGT 5,330 WbMG,NGT ~E$. NG~ 3,545 C$, NGT DFDT. 3300,000 SFLU,DTE SP,DTE 64,000 IDPH,DTE IDOr,DTE 0,000 IMQF,DTE IIRD,DTE 70,3!3 IIXD,DTE CC~. ~TE 42,339 TENS DTE H~EK'~ DT~ 930.500 DPHI:LDT PEw. bDT ~,.484 ~LS,bDT L~I. LDT 445. 500 Lb, LDT SS~. t,D~ 330. 750 LSHV bDT CG~,bDT 4~,339 TENS, bDT HTE~,LDW 9~0,500 MP~I,CNL ~PO~,CNL 43.095 ~CNT,CNb CFTC. CNL 55~, 367 SGR, CNL T~NS,CNL 2990,000 .SGR, ~GT aO, 810 C~R: NGT lj~ A~,~. ~GT 2.514 WI.~G.NGT ~'J~. NGT ! ! ,494 W5MG. NGT ~P~g. ~G~ 3. 553 CS. NGT D~'~T. 3200.000 SFLU.DTE Sn. [:)T~ 64,6~5 IDPH,DTE [nOr,DTE 0.000 IMOF,DTE I!UD.DT~: ~5,500 IIXD,DTE 9-MAR-!993 09~22 2.006 CALl,bDT 9~ 000 ~T~H.LDT 294 ~091 TNPH,CNL 1627,983 RCFT,CNL 41,653 CGR,CNL 3,539 ~TE~,CNL 32.75~ THOR,NGT 139,908 W2NG,NGT 5,734 TENS,NGT 1984,000 HTEN.NGT 8.039 IbM,DTE 9,750 IMPH,DTE 0,000 CIDP,DTE ],967 XIR~,DTE 3085,~00 MTEM,DTE 30. 77 RHOB.LDT 0.009 OSS.LDT 245..250 LITH,LDT 1704.000 SSHV.LDT ~.170 CADI,bDT 3085,000 ~TE~,LDT 42,718 TNPH,CNL 1854,265 RCFT,CNb 72,553 CGR,CML ,545 MTEM,CNL 5 ,190 THOR,NGT 233,475 W2NG.,NGT 9,595 TEN$.,NGT 1985~000 ~TEN,~G'r 10,469 ILM.DTE 12.88] IMPH,DTE 0,000 C~DP,DTE -1 045 IIRM,DTE 2990i000 'MTEM,DTE 31 747 RHOB,bDT 002 QS$ bDT [705 ooo SS 'V.bOT ' 2~127 CALI,LDT 2990,000 MTEM,LDT 42,i78 TNPH.C~L 192S'62~ RCrT.C~[, 60,810 CGR,CNL 3,553 MTE~4,CNL 42.339 THOR,NGT 1.97,701 W2NG,NGT 8,046 TENS,NGT '.984.000 HTEM,~GT 9 ~0 I[,~ DTE o'ooo 9.977 74.813 43.596 428.192 32.755 74.~13 4.526 71.~Ot 2995.000 978.000 9.14! 9.266 102.500 ~03.438 74.250 2.149 0.022 148.;250 1352.000 9,609 1.. 14 463,593 53,!90 0 . 121.535 3085,000 1006.500 11.78! 11.813 77 563 80~375 74.563 2.126 0,033 168.625 135~,000 11.391 74,563 4!,63~ 497,030 42.339 4 95 402 2990.000 g30,500 9.64R 9.867 94 688 9 1o6 SG~.I,DT MRES.LDT TNkA.C~L CNTC.CNL CAbI,C~b HTEM.CML POT~,NGT W3NG,NGT ~TEM,~GT ILD,DTE IFRE.DTE C!MD.DTE SG~.DTE ~RES.DTE DRHO.bDT LS.LDT SS1.LDT S1RH.I,DT SGR.[.,DT ERgS.LOT TNRA.CNL CNTC,CML CAI.,I.CNL MTEN,CNL POTA,NGT W3NG,~GT ILD,DTE IFRE,QTE CIMP,QTE SG~,DTE MRES.DTE DRHO.I, DT L$.bDT S81,bDT $1RH.LDT SG~,LDT ~RE$,LDT TNRA,CM[. CMTC,CML CAL!,CNL HTEN,C~L POTA.MGT W3NG.NGT IFRE,DTE CIMP.DTE SGR.DTE PAGE: 41.653 3.539 3.833 1773,339 9,977 978.000 1.000 17.202 74,~13 9,508 ~0.000 107.813 72,553 3.545 -0.009 452,250 ~16,375 2.~93 72,553 3.545 3,564 1,847.133 9,609 ~006,500 ~.640 2@,785 74,250 ~2,719 20,000 ~4,625 A0.810 3,553 0,005 485,000 227.000 2.100 60,810 3.553 3,642 {982.562 11,391 930.500 1,174 27.5~6 74,563 10.320 20.000 101,250 71,428 16 Tape veri~icatJ, on Listino :hlumberqer AlasKa ComPutinq Center CG~.DTR 53.382 TEN$.DTE HTEN,P?E 942,000 DPHIoLDT PEw. LI)T 2,477 OL$,LDT LU.LDT 350,750 LL,LDT KS?,LDT 310,750 5SNV,LDT bSR~.LDT 2.25~ LURH.bDT CG~.bDT 53,382 TENS, bDT HTEg,LDT 942,000 NPHI,CNL NDO~,CNL 38.729 RCNT,CNb CFTC.CN[, 573.150 SGR.CN5 'F~NS,CPL 2760.000 m~E$,CgL SG~,NGT 71,428 CG~,NGT U~,NGT 2,456 W!NG,NGT W~NG,NGT 7,463 W5NG,NGT U~S,~GT 3,631 C$,NGT n. Eg?. ]1o0.00o SFLU.OTE SP. D'P~: 97,375 IDPH,DTE I')OF..DT~ 0 000 .T~OF. DTE trn 74:9,8 IIXD.DTE CG~:OTK 27.408 TENS,DTE HTE~. DTE 860. 500 DPHI. bDT PEm.b~T 21.766 OLS.LDT [,U. bDT 2! 4. 750 bb. bDT 882.LDT 135.000 LSHV.hDT t.,MRu.LDT 2,547 LURH bDT CGP,LDT 27.408 TE~$:G~T [!TE ~S, bDT 860,500 MPHI, CNb JDO~.CML "59.g29 RCNT:CNL C~T~.CNL 300. 247 SGR.CNb TmNS.C~4L, 2505.000 ~RMS.C~iL SG~. MGm 39,138 CGR,...GT ~l~A~. NGT 1,597 WiNG,NGT WdNC,NGT 5,330 WbNG,NGT ~PES, NGT 3,646 CS./'.I~T u pT. 3o82.ooo S Uu. T SP.DT~ 107.438 IDPH,DTE CG~,DT~ 31,802 TENS., DTE Ltl,bDT 271.,750 LL,LDT LSR~.I, DT 2,39! bUSH.bDT CG~.LDT 31.802 ?ENS.LDT HTEm LDT 863 500 NPHI.CNL MPPm:CML 57:965 ~CNT,CNL CFTC.CML 270,343 SGR,CML TFM$.CNL 25!0,000 gRES,CNL S(;~.UGT 41,016 CGR,NGT ~tPAw.~GT 1,~54 W1MG.NGT WdHC.NGT ~.598 W5MG.NGT ~$.~GT 3,627 CS,NGT 9-"AR-~993 09:22 60,000 MTEM,DTE 2723,957 RHOB,LDT 0,01! QSS,LDT 203.750 blTH,bDT 1702.000 $$HV,bDT 2.~68 CAbI,bDT 2760,000 MTEM,bDT 40.377 TNPH.CML 2004o]05 RCFT,CNL 7~.421 CGR.CNL 3.631 MTE~,CNL 53.382 THOR.NGT 244,1.36 W2NG,NGT 8,529 TEN$,~GT 1985,000 HTE~,NGT 4.359 IL~.DTE 13.797 IgPH,DTE 0.000 CIDP,DTE '411,~50 IIWM,DTE 2505, O0 MTEM,DTE 46.~66 RHOB,bDT 0,057 O$$,bDT 113.~3 I, ITH bDT 1707, 0 $SHV:bDT 2,592 CRLI,I~DT 2505.000 ~TEH.,LDT 62,~50 TNPW,CNL 11~9,047 RCFT.CNB 9.1.38 CGR,CNb 3 646 MTEM,CNb !3 527 W2NG.NGT 4 264 TE~S,NGT 1989~000 HTEN,NGT 9696,000 IL~,DTE 9,773 IMPH,DTE 0,000 CIDP,DTE -410,~50 IIR~,DTE 2510,000 ~TEM,D~E 62.380 ~HOB.bDT 0.111 OSS,LDT 15~ 625 LIT}I,LDT 170 :000 SSHV.LDT 2.430 CALI,LDT 2510.000 ~TE~,LDT 54.681 TNPH,CNb 11.34.364 ~CFT,CML 41 016 CGR,CNL 3:6~7 ~.802 TUOR..NGT 1 ,67~ W2NG,NGT 3,44~ TENS,NGT 197!,000 HTEN,NGT 73.875 2.255 0.017 128.125 1352.000 10.602 73.875 39.835 53].483 53..382 73.~75 8.252 122.601 2760,000 942,000 1950.000 1950,000 72.438 -446.750 72,938 1,~77 -0.104 24.875 1357.000 8,977 72.938 55.663 265,065 8 72. 3,888 50.107 2505 000 860:500 1950.000 1950.000 102.250 -542.500 72.938 1.621 -0.157 32 969 1357:000 8,945 72,938 56.~74 267. 51 31 802 4.,4~4 64.368 2510.000 ~63,500 MRES.DTE DRHO.LDT t,S.LDT SSI.LDT S!RH.LDT SGR.LDT M~ES.bDT TMRA.CML CNTC.C~L CALI.C~L HTEN.CNL POTA.NGT W3NG.MGT ~TEM.MGT ILD.DTE IFRE,DTE CImP.DTE SG~.DTE mRE$,DTE DRHO,LDT L$,LDT SS1,LDT S1RH.LDT 8GR.bOT MRE$.bDT TNR~,CNI., CMTC,CNL CaLI.C~b HTEN,CNL POTA,NGT W3NG.NGT MTE~,~GT I[,D.DTE IFRE.DTE CIMP.DTE SG~.DTE MRE$.DTE D~HO,L. DT LS.LDT SS1.LOT S1RH..LDT SGR.LDT MRE$.LDT TNRA.CNL CNTC.CMb CALI.CSL [ITEM.CML POTA.MGT W3NG,MGT MTE~,NGT PAGE: 3.631 -0.004 370.250 213.875 2.271 71.428 3.631 3.517 1953.374 !0.602 94~.000 !.416 28.7~5 73.R75 11.523 20.000 -449.500 39.138 3.646 -0.671 220,375 79,625 3.992 39,138 3,646 4,6J2 1274,203 8,977 860,500 0,812 9.539 20,000 -529.500 41.016 3.627 -0,760 287,500 73,125 4,047 41.016 3.627 4.163 1157,504 8,945 863,500 0,949 21,839 72,938 17 :blUmber~er ~!osko Computtnc Center · c~-~,~R.,.1 ~93 09: 22 ** EB]D OF DATA ** **** F T L~.: TRAILER **** FT[,F NA.E : EDIT .o01 SFRVlCE : FLIC VER,$10N : OO1A06 D~ : 90110125 ~X REC 5'[ZE : 8192 FIL~ TYPE : LO b~S~ ~I[,E : **** T~PE T~A I!.,EN **** 5~RV!C~ KA~.~ : EDIT D~TF .: gO/10/~5 O~lCI~ : FbTC T~PF NA~ : 74106 CON~INI. IAT!ON ~ : ..... ~ ~ ~ CO~i~ENT : OriNOCO IMC., oC~:.ADER BL, UFF, ~I[,NE POINT UNIT SFRVICE ~!.~ME : ~;DIT D~T~ : 901!,0125 OPI~I'N : FLIC CONTINUATION ~' : CO~UENT : CONOCO INC., SCHRADER BLUFF, MIbNE POINT UNIT H-2, 50-029-~2062