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190-006
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~ Bren Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOT,Scanned.wpd STATE OF ALASKA ALASKA O AND GAS CONSERVATION. COMMI ON R~CIV~D == ~~ 0 ~ 201a .. . WELL COMPLETION OR RECOMPLETION REPORT AND 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended 2oAAC zs.~os zoAAC zs.»o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1 b. ®Developm~~lt~loratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 1/13/2010 12. Permit to Drill Number: 190-006 ° 309-392 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 02/21/1990 13. API Number: 50.029-24998-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 03/03/1990 14. Well Name and Number: MPL-02 3207 FSL, 5056 FEL, SEC. 08, T13N, R10E, UM Top of Productive Horizon: 3951' FSL, 1565' FEL, SEC. 07, T13N, R10E, UM g. KB (ft above MSL): 56' GL (ft above MSL): 15. Field /Pool(s): Milne Point Unit / Kuparuk River Total Depth: 4023' FSL, 1765' FEL, SEC. 07, T13N, R10E, UM 9. Plug Back Depth (MD+TVD): 7560' 7034' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 544825 y_ 6031397 Zone- ASP4 10. Total Depth (MD+TVD): 7936' 7346' 16. Property Designation: ADL 025509 TPI: x- 543030 y- 6032130 Zone- ASP4 Total Depth: x- 542829 Y- 6032201 Zone- ASP4 11 • SSSV Depth (MD+TVD): N/A 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and Tinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): NGT / CNL / LBT / DIL 22. Re-Drill/Lateral Top Window MDlfVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM .TOP BOTTOM SIZE CEMENTING RECORD PULLED 13-3/8" 48# H-40 rface 82' rf To Surfa " 7' rf 4 -1/" P 11 7" 2 L- rf 79 1' Surfa 7317' 8-1/ " 2 B Is CI ss' ' 24. Open to production or injection? ^ Yes ®No 25. TUBING RECORD If Yes, list each interval open (MD+TVD of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD / TVD ~ MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .~ ~y rf (~ ~ ~~ 3" 9 . DEPTH INTERVAL (MD OF MATERIAL USED AMOUNT AND KIND . d i. ~d Yiw~~ ~F~ h e~`~ , 7560 / / Set Whipstock 7560' P&A w/ 22.5 Bbls Cement '~ 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqu ired? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS FEB 0 5 2010 ~~ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ~~ ~ a~~,~ Submit Original Only 29. GEOLOGIC MARKERS (List all formati ons and ma encountered): 30. NATION TESTS • NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 3517 3516' None Schrader Bluff 4057' 4043' Top HRZ 7044' 6602' , Base HRZ 7089' 6640' Kuparuk 7392' 6894' Kuparuk C 7554' 7029' Kupaurk A 7652' 7110' Miluveach 7789' 7224 Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. ~~~ lb Signed: Terrie Hubble Title: Drilling Technologist Date: MPL-02 190-006 309-392 Preparnd ByNameMumber• Tenie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Sean McLaughlin, 564-4387 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, San Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only MPL-02, Well History (Pre Rig Sidetrack) Date Summary 11/26/09 T/I/0= 400/260/360, Temp= S/I. Freeze Protect. Pumped 15 bbls diesel down Tbg. Pumped 2 bbls 60/40, 3 bbls diesel, 2bbls 60/40 down Production Line. Bled off psi. Pumped 2 bbls 60/40, 3 bbls diesel, 2 bbls 60/40 down Test Line. Bled off psi. FWHP= 400/260/360. SV,WV,SSV =Closed. MV =Open. IAV, OAv = OTG. 11/29/09 WELL S/I ON ARRIVAL. RAN 1.72" CENT, S. ABSORBER, DUAL SPARTEK GAUGES. 15 MIN GRADIENT STOP ~ 6,906' SLM (6,937' MD). TAG PUMP C~ 7,375' SLM (7,406' MD) -31' CORRECTION TO SLM. 3 HR BHP STOP C~ 7,372' SLM (7,403' MD). PULLED DGLV FROM ST#1 Q 7253' MD. PULLED DPSOV FROM ST#2 ~ 168' MD. SET 1" BK DGLV IN ST#2 C«? 168' MD. ASSIST WELL SUPPORT TO SET BPV. JOB COMPLETE. WELL LEFT S/I. BPV INSTALLED. Nabors 4ES moved on this well to pull the ESP and run workstring (11/21/09 - 11/27/09). 12/19/2009 WELL S/I ON ARRIVAL. ASSIST SUPPORT TECHS W/CRANE & PULLED BPV. R/U SLICKLINE EQUIPMENT FOR POST RIG. 12/20/2009 PULL BALL & ROD FROM 7338' MD. PULL DCK SHEAR VALVE/SET 1" BK DUMMY C~ 3014' MD. PULL RHC PLUG BODY FROM 7338' MD. DRIFT TUBING W/ 20' x 3.70" DUMMY WHIPSTOCK S/D Q 7710' SLM. WELL S/I ON DEPART. 12/21/2009 T/I/O = 0/0/0. Temp = SI. MITIA PASSED to 2500psi. Fluid packed IA w/ 18.7bbls diesel. Pressured up w/ additional 0.8bbls (19.5 total.) IA lost Opsi in 30min. Bled to zero. FW HP's = 0/0/0. IA, OA =open to gauge. Rest of tree shut (Post RWO, no flowline.) 12/22/2009 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = O/O/O, MV = C, SW = C, WV = C, IA/OA = OTG SET BAKER 4-1/2" X 7" WHIPSTOCK AT 7560', ORIENTATION WAS 2° LOHS. (REFERENCED SLB DUAL INDUCTION LOG DATED 3-MARCH-1990) POSITIVE SURFACE INDICATION OF SETTING. TWO RADIOACTIVE PIP TAGS PLACED 10' BELOW TOP OF WHIPSTOCK AT 7570' ELMD. FINAL T/110 = 0/0/0, WV = C, MV = C, WV = C, IA/OA = OTG, WELL SHUT-IN ON DEPARTURE. JOB COMPLETE. 1/7/2010 MIRU coil tubing unit. Perform weekly BOP test. MU and RIH cementing BHA displacing well with 1% KCL then swapping to Diesel. O-ring leak on lubricator forced us to POOH to repair. RIH w/ BDN BHA. Pump 22.5 bbls 15.8 ppg cement. Bullheaded 7 2 bbls cement past whipstock to achieve 500 psi bump. then layed in 15.3 bbls cement 1 to 1 up to 6745'. Pressure up to 1200 psi for 30 minutes. Pressure held constant, no bleed off. Dropped ball and cleaned out to top of whipstock tray with 1.5# biozan. 1/8/2010 Clean out cement to whipstock tray. POOH at 80% washing all jewelry and BOP stack. Freeze protect well with 60/40 McOH from 2500'. RDMO. Job Complete. Page 1 of 1 • • BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WI.~R~4~~ ~~~ ~'sP~f~un art: 12/9/2009 End: Contractor Name: ~g Release: 2/1/2010 Rig Name: ~J4~(5 4~E5 Rig Number: N2 Date ~ From - To Hours Task- Code ~ NPT Phase Description ofi Operations I 12/9/2009 11:30 - 12:30 1.00 RIGD P PRE SCOPE DOWN DERRICK AND LAY OVER -PREP RIG FOR MOVE 12:30 - 14:30 2.00 MOB N WAIT PRE WAIT ON TRUCKS TO MOVE RIG. DOYON 15 BLOCKING SPINE ROAD. 14:30 - 18:00 3.50 MOB P PRE PJSM WITH PEAK AND RIG CREW 18:00 - 21:30 I 3.50 I MOB I P 21:30 - 00:00 2.50 RIGU P 12/10/2009 00:00 - 01:00 1.00 RIGU P 01:00 - 02:00 1.00 RIGU P 02:00 - 03:00 1.00 WHSUR P 03:00 - 04:30 I 1.501 KILL I P 04:30 - 05:30 I 1.001 KILL I P 05:30 - 08:30 3.00 ~ KILL ~ P 08:30 - 11:30 I 3.001 WHSUR I N 11:30 - 12:30 I 1.00 WHSUR P 12:30 - 14:00 I 1.501 WHSUR I P 14:00 - 17:00 ~ 3.00 ~ BOPSUq P -MOVE CAMP, PIPE SHED, PITS AND SUB OFF OF WELL L-36 -GAVE AOGCC 24-HRS. NOTIFICATION OF BOPE TESTING PRE - -SPOT PITS & PIPE SHED -MOVE CAMP AND SPOT IN FRONT OF RIG PRE RAISE DERRICK AND SCOPE UP -RIG UP FLOOR AND PITS PRE CONTINUE TO RIG UP FLOOR AND PITS -RIG ACCEPTED ~ 0100 HRS ON 12-10-09 PRE RU, SPOT TIGER TANK AND HOOK UP LINES. -RU CIRCULATING LINES TO TREE WING VALVE AND IA. DECOMP PICK UP DSM LUBRICATOR AND FILL WITH DIESEL -TEST TO 500 PSI -PULL BPV AND LAY DOWN DECOMP TAKE ON 580 BBLS OF 8.6 PPG SEAWATER 110 DEGREE INTO PITS -HOLD PJSM WITH CREW AND CH2MHILL DRIVERS FOR WELL KILL DECOMP TEST LINES TO 3500 PSI -OPEN WELL TAKE PRESSURES -IA=330 - OA=80 - T=310 DECOMP -PUMPED 150-BBLS. 110E SEAWATER DOWN TUBING AT 5.0-BPM AT 300-900 PSI. WITH NO RETURNS TO SURFACE. -CAUGHT FLUID AT 3800' FROM SURFACE. -SHUT DOWN PUMPING. TUBING AND IA ON VACUUM. -SHUT IN TUBING AND BULLHEAD 350-BBLS OF 110E SEAWATER DOWN IA. -SHUT DOWN PUMPING AND MONITORED WELL FOR 30-MINUTES. TBG. AND IA ON VACUUM. WAIT DECOMP WAIT ON CAMERON WELLHEAD TECH TO ARRIVE ON PAD. CAMERON WELLHEAD TECH. UNABLE TO ARRIVE ON TIME DUE TO BEING HELD UP BY NORDIC 2 RIG MOVE ON SPINE ROAD. DECOMP CAMERON WELLHEAD TECH SETTWC WITH "T" BAR ENSURING PROPER TRAVEL INTO TUBING HANGER PROFILE. PRESSURE TEST TWC FROM BELOW BY PUMPING AT 3.0-BPM AND CHARTING TEST FOR 10-MINUTES. NO PRESSURE OBTAINED FROM BELOW. PRESSURE TESTED TWC FROM ABOVE TO 3500-PSI FOR 10-MINUTES CHARTED. DECOMP CAMERON WELLHEAD TECH PRESSURE TESTED TUBING HANGER VOID TO 5000-PSI. N/D TREE AND ADAPTER FLANGE. CAMERON WELLHEAD TECH. PRESSURE TESTED CASING PACKOFF TO 3000-PSI. DECOMP NU BOPE. AOGCC -CHUCK SCHEVE WAIVED TEST WITNESS. rnntea: zrr~zuiu's:zu:~srm • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 12/9/2009 End: Contractor Name: Rig Release: 2/1/2010 Rig Name: Ids Rig Number: N2 Date From- To Hours ~ Task Code NPT Phase Description of Operations 12/10/2009 17:00 - 23:30 6.50 BOPSU P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: BOP CONFIGURATION: -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. -SPACER SPOOL. -2 7/8" X 5" VARIABLE BORE RAMS. -TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S W ITH 2-7/8" TEST JOINT. -TESTED ANNULAR WITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. 200 PSI BUILD UP FROM 1700 PSI = 45 SECONDS. 23:30 - 00:00 0.50 ~ 12/11/2009 ~ 00:00 - 01:00 ~ 1.00 -FULL BUILD UP TO 3000 PSI = 166 SECONDS. -4 BOTTLES x 1670 PSI. -CHUCK SCHEVE WAIVED AOGCC RIGHT TO WITNESS BOPE TEST AT 15:00-HRS ON 12-10-09. P DECOMP R/U DUTCH SYSTEM AND P/U WELL SUPPORT LUBRICATOR TO PULL TWC P 01:00 - 04:30 3.501 PULL ~ N 04:30 - 06:00 1.50 ~ PULL ~ P 06:00 - 06:30 0.501 PULL ~ P 06:30 - 13:00 6.501 PULL P DECOMP CONTINUE R/U LUBRICATOR -TEST TO 500 PSI AND PULL TWC -UD LUBRICATOR AND DUTCH SYSTEM WAIT DECOMP CLEAR ICE FROM DERRICK -BLOCKS WOULD NOT LOWER TO FLOOR DUE TO FROST ON LINES -BLOCK OFF PAD ENTRANCE AND CLEAR FLOOR -DERRICK HAND SENT UP TO CLEAR ICE AND FROST FROM LINES AND DERRICK DECOMP T. INSTALL CLOSED TIW VALVE -SCREW INTO HANGER WITH 8-1/2 TURNS -CAMERON REP. BOLDS -PULL HANGER TO FLOOR -PU WT.=70K TO BREAK FREE -PULLED AT 57K -DID NOT ATTEMPT CBU. CANNOT FILL HOLE. DECOMP CREW CHANGE. -SERVICE RIG AND CLEAR ICE FROM DERRICK -CHECK PVT'S AND ENVIRO WALKAROUND DECOMP POH WITH COMPLETION. -POH STANDING 2-7/8" TUBING IN DERRICK. -CONTINUOUS HOLE FILL WITH 20-BPH PLUS PIPE AND ESP CABLE DISPLACEMENT WHILE POH. -78 STANDS PIPE IN DERRICK. -TUBING IN GOOD CONDITION AND NO FOREIGN MATERIAL DEPOSITION ON TUBING INSIDE OR OUTSIDE. -RECOVERED 234 JTS. 2-7/8" 8RD. TUBING, 2 X 2-78" X 1" GLMS, "XN" NIPPLE, 1 X 10' 2-7/8" 8RD. PUP, i X 8' 2-7/8" rnncea: uuzu iu s:ev:~a rm • $P EXPLORATION Page 3of 6' Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 12/9/2009 End: Contractor Name: Rig Release: 2/1/2010 Rig Name: # Rig Number: N2 Date From - To Hours Tasl< Code NPT Phase Description of Operations 12/11/2009 06:30 - 13:00 6.50 PULL P DECOMP 8RD. PUPS AND 1 X 2' 2-7/8" 8RD. PUP AND WKM TUBING HANGER. 13:00 - 16:00 3.00 PULL P DECOMP CENTRILIFT BROKE OUT AND LAYED ESP BHA DOWN. 16:00 - 17:00 I 1.001 PULL I P 17:00 - 18:00 1.00 PULL N 18:00 - 18:30 0.50 PULL P 18:30 - 19:00 0.50 CLEAN ~ P 19:00 - 23:30 4.501 CLEAN P 23:30 - 00:00 I 0.50 I CLEAN I P 12/12/2009 00:00 - 01:00 1.00 CLEAN N 01:00 - 04:00 3.00 CLEAN P 04:00 - 05:00 1.00 CLEAN I P 05:00 - 06:00 1.00 CLEAN P 06:00 - 06:30 0.501 CLEAN ~ P 06:30 - 13:00 I 6.501 DHB I P 13:00 - 14:00 1.00 DHB P 14:00 - 15:00 1.00 DHB P 15:00 - 16:30 I 1.501 DHB I P 16:30 - 18:00 I 1.50 CLEAN ~ P 18:00 - 19:00 I 1.001 CLEAN I P 19:00 - 21:00 ~ 2.00 ~ CLEAN ~ P -RECOVERED PUMP DISCHARGE HEAD, PUMP, PUMP, GAS SEPARATOR, SEAL SECTION, SEAL SECTION, MOTOR, PUMPMATE SENSOR AND CENTRALIZER. NO FOREIGN MATERIAL DEPOSITION ON ESP BHA. DECOMP CLEAR AND CLEAN RIG FLOOR AND PREP. TO RIH WITH SCRAPER BHA. WAIT DECOMP CLEAR ICE FROM DERRICK DECOMP CREW CHANGE. -SERVICE RIG AND CLEAR ICE FROM DERRICK -CHECK PVT'S AND ENVIRO WALKAROUND DECOMP PUMU 6-1/8" BIT, 7" CASING SCRAPER, 2 X 4-3/4" BOOT BASKETS AND XO TO 2-7/8" 8RD. TUBING. TTL LENGTH = 14.86' DECOMP RIH WITH CASING SCRAPER BHA ON 77 STANDS OF 2-7/8" 8RD. TUBING FROM DERRICK. P/U 11SINGLES FROM PIPE SHED. SCRAPE FROM 7,332' TO 7,425' & 7,522' TO 7,613', 3) TIMES EACH. PUW=43K SOW=38K. FEED WELL WITH CONTINUOUS HOLE FILL AT 20-BPH. DECOMP R/U POWER TONGS AND FLOOR FOR POH AND STANDING BACK 2-7/8" 8 RND TBG. WAIT DECOMP CLEAR ICE FROM DERRICK DECOMP POH STANDING BACK 80 STANDS OF 2-7/8" 8RND TBG IN DERRICK DECOMP UD BHA #1 SCRAPER ASSY. -CLEAR AND CLEAN RIG FLOOR DECOMP BRING 7" HALCO RBP TO FLOOR -MAKE UP RBP BHA DECOMP CREW CHANGE. -SERVICE RIG AND CLEAR ICE FROM DERRICK -CHECK PVT'S AND ENVIRO WALKAROUND DECOMP RIH WITH 7" RBP ON 2-7/8" 8RND TBG TO 751.0', CHECKING EVERY 2-7/8" CONNECTION ON THE WAY IN TO 2300 FT/LBS. SFT THE RBP AND PRESSURE TEST TO S CHARTED. GOOD TEST. DECOMP RIG UP AND REVERSE CIRCULATE TO CLEAN UP INSIDE OF TUBING. DECOMP PRESSURE TEST THE 7" CASING AND THE RBP TO 2000 PSI FOR 30 MINUTES CHARTED. GOOD TEST. DECOMP lAY DOWN A SINGLE AND 3 STANDS OF 2-7/8" 8RND TBG. MAKE UP STORM PACKER RIH AND SET AT 25.5'. PRESSURE TEST THE 7" STORM PACKER TO 2000 PSI FOR 20 MINUTES CHARTED. GOOD TEST. DECOMP PULL OUT THE VBR's AND HAVE REDRESSED WHILE N/D BOP STACK. ONCE THE STACK IS N/D, INSTALL THE NEW FMC TBG SPOOL ONTO THE EXISTING CAMERON WKM TBG SPOOL. DECOMP CREW CHANGE. -SERVICE RIG AND CLEAR ICE FROM DERRICK -CHECK PVT'S AND ENVIRO WALKAROUND DECOMP CONTINUE N/U DSA AND STACK -PAD STUDS ON FMC Y(IfltBtl: 'L/1/LUIU :S:'LU:L;1 YM l J l J BP EXPLORATION.- Page 4 of 6 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 12/9/2009 End: Contractor Name: Rig Release: 2/1/2010 Rig Name: fG2 Rig Number: N2 i Date From - To !Hours Task .Code NPT Phase Description of Operations 12/12/2009. 19:00 - 21:00 2.00 CLEAN P DECOMP TBG HEAD TOO LONG TO GET ANY TYPE OF WRENCH ON -CONSULT FMC, CAMERON, AND TOWN ENGINEER. 21:00 - 00:00 3.00 CLEAN N WAIT DECOMP SET BACK BOP'S AND REMOVE FMC TBG SPOOL, SHORTEN PAD STUDS 1/2" -INSTALL REBUILT VBR'S 12/13/2009 00:00 - 02:00 2.00 BOPSU P DECOMP N/U FMC TBG SPOOL AND TO. NUTS -INSTALL BOP STACK AND TO. NUTS 02:00 - 05:00 3.00 BOPSU P DECOMP R/U AND TEST 2-7/8"X5" VBR'S WITH 2-7/8" & 4-1/2" TEST JT -TEST BREAKS, CHOKE AND KILL LINES -ALL TESTS TO 250 PSI LOW AND 3500 PSI HIGH -5 CHARTED MINUTES EACH -R/D TEST EQUIPMENT 05:00 - 07:30 2.50 DHB P DECOMP P/U 24' 3-1/2" IF PUP JT WITH STORM VALVE RETRIEVING TOOL -CHECK FOR PRESSURE -RELEASE STORM VALVE -PULL AND UD 07:30 - 12:30 5.00 DHB P DECOMP M/U 3 STANDS AND 1 JT. OF 2-7/8" TUBING AND RIH TO LATCH UPON THE 7" RBP. RELEASE THE RBP (SHOWED SIGNS OF BEING ON A VAC) PUMP 150 BBLS DOWN THE HOLE AND BEGIN PULLING OUT OF THE HOLE LAYING DOWN THE 2-7/8" TUBING. -CONSTANT HOLE FILL OF 20 BBUHR. 12:30 - 13:30 1.00 DHB N WAIT DECOMP HIGH LEVEL H2S ALARM ON THE RIG. SECURE THE WELL AND EVACUATE THE RIG AND SECURE THE PAD. CONTACT THE RWO SUPERINTENDENT AND NABOBS SUPERINTENDENT. BEFORE THE DRILLER LEFT THE FLOOR THE SIERRA MONITOR READ NO H2S. THEREFORE AFTER CONSULTING WITH THE SUPERINTENDENTS THE DRILLER AND LEAD FLOORHAND PUT ON SCBA'S AND "SNIFFED" THE RIG AND IT SHOWED NO SIGNS OF H2S. OPERATIONS RESUMED AS PLANNED. 13:30 - 18:30 5.00 DHB P DECOMP CONTINUED TO PULL OUT OF THE HOLE LAYING DOWN THE 2-7/8" 8RND TUBING. -UD 239 JTS OF 2-7/8" 8 RND TBG. -UD 7" HALCO RBP AND RUNNING TOOL -CONSTANT HOLE FILL OF 40 BBUHR. 18:30 - 19:30 1.00 BUNCO P RUNCMP CREW CHANGE. -SERVICE RIG -CHECK PVT'S AND ENVIRO WALKAROUND 19:30 - 20:00 0.50 BUNCO RUNCMP R/U TONGS FOR RUNNING TBG -LOAD JEWELERY INTO PIPE SHED & INSPECT 20:00 - 00:00 4.00 BUNCO RUNCMP MAKE UP TAIL PIPE ASSY & BAKER S-3 PACKER -RUN 4-1/2" 12.6 LB/FT L-80, IBT-M COMPLETION PER . RUNNING ORDER -AVERAGE MAKE UP TO. = 3800 FT LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. -40 JOINTS IN HOLE ~ 00:00 HRS -CONSTANT HOLE FILL OF 40 BBUHR. rnntea: uueutus:~u:e~ rm BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Event Name: WORKOVER Contractor Name: A Rig Name: ~ Date Frorn - To Hours '~ Task ..:Code 12/14/2009 ~ 00:00 - 01:00 ~ 1.00 01:00 - 04:30 I 3.50 ~ FiU 04:30 - 05:30 1.00 RU 05:30 - 06:00 0.50 RU Spud Date: 2/21/1990 Start: 12/9/2009 End: Rig Release: 2/1/2010 Rig Number: N2 T Phase Description of Operations RUNCMP SHUT DOWN FOR LUNCH AND HOLD WEEKLY SAFETY MEETING RUNCMP CONT. TO RUN 4-1/2", 12.6 LB/FT, L-80, IBT-M COMPLETION PER RUNNING ORDER -AVERAGE MAKE UP TO. = 3800 FT LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. -122 JOINTS IN HOLE ~ 04:30 HRS -CONSTANT HOLE FILL OF 40 BBUHR. RUNCMP R/U SHEAVE AND CONTROL LINE SPOOLER RUNCMP CONT. TO RUN 4-1/2", 12.6 LB/FT, L-80, IBT-M COMPLETION PER RUNNING ORDER -AVERAGE MAKE UP TO. = 3800 FT LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. -CONSTANT HOLE FILL OF 40 BBUHR. 06:00 - 06:30 0.50 BUNCO RUNCMP SERVICE RIG AND PRE-TOUR CHECKLIST. 06:30 - 07:00 0.50 BUNCO RUNCMP RIG UP THE CONTROL LINE SPOOLER AND SHEAVE. STRING THE CONTROL LINE. 07:00 - 12:30 5.50 BUNCO P RUNCMP CONT. TO RUN 4-1/2", 12.6 LB/FT, L-80, IBT-M COMPLETION PER RUNNING ORDER -AVERAGE MAKE UP TO. = 3800 FT LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. -CONSTANT HOLE FILL OF 40 BBUHR. 12:30 - 14:30 2.00 BUNCO RUNCMP TERMINATE THE CONTROL LINE AT THE FLOOR. MAKE UP THE TUBING HANGER, RUN IN THE HOLE AND LAND, WHILE HOLDING CONSTANT PRESSURE ON THE CONTROL LINE TO KEEP THE SSSV OPEN. [CROP THE BALL AND ROD . COMPLETION CONSISTS OF THE FOLLOWING: -4-1/2" WLEG -BAKER LOK'D 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING JT. -4-1/2" X NIPPLE W/ RHC SLEEVE -BAKER 7" X 4-1/2" S-3 PRODUCTION PACKER -BAKER 80-47 PBR ASSEMBLY -4-1/2" X NIPPLE (3.813" ID) -JTS (1-105) 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING -4-1/2" X 1" KBG GLM W/ DCK SHEAR -JTS (106-122) 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING JT. -4-1/2" TRM-4PE-CF SSSV -JTS (123-178) 4-1/2", 12.6 LB/FT, 1-80 IBT-M TUBING JT. -SPACE OUT PUP 7.82' -JT (179) 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING JT. -FMC 10" X 4-1/2" TUBING HANGER -CONTROL LINE FROM 2300' TO SURFACE -62 SS CONTROL LINE BANDS 14:30 - 17:00 2.50 BUNCO RUNCMP Pl-A~F DOWN THE TUBING AND PRESSURE UP TO 3500 .. PSI TO SET AND TEST THE PACKER. HOLD 3500 PSI FOR 30 CHARTED MINUTES. BLEED OFF THE TUBING TO 0 PSI AND BOLDS AND PULL THE HANGER TO THE FLOOR rnnrea uuzuw rzo:~a rm • $P EXPLORATION Page 6 of 6 <Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 12/9/2009 End: Contractor Name: Rig Release: 2/1/2010 Rig Name: Rig Number: N2 ..Date From - To Hours. Task Code NPT Phase Description of Operations 12/14/2009 14:30 - 17:00 2.50 BUNCO RUNCMP TO VERIFY THE PBR SHEARED. GOOD SHEAR. RUN IN 17:00 - 18:00 I 1.00 18:00 - 18:30 0.50 18:30 - 20:00 1.50 20:00 - 21:00 1.00 BOPSU~ P 21:00 - 22:00 1.00 WHSUR P 22:00 - 00:00 2.00 WHSUR P 12/15/2009 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:00 1.00 WHSUR P 02:00 - 05:30 3.50 WHSUR P 05:30 - 07:30 2.00 WHSUR P 07:30 - 08:30 1.00 WHSUR P 08:30 - 11:00 2.50 WHSUR P 11:00 - 12:00 1.00 WHSUR P AND LAND THE HANGER AGAIN. RILDS, PRESSURE UP TUBING TO 1500 PSITHE IA TO 2000 PSI FOR 30 CHARTED MINUTES. BLEED OFF THE PRESSURE AND PRESSURE UP THE ANNULUS TO SHEAR THE DCK VALVE. SHEARED AT 1875 PSI. RUNCMP PUMP THROUGH DCK VALVE BOTH WAYS -PUMP DOWN TBG ~ 3 BPM WITH 1500 PSI -PUMP DOWN IA @ 3 BPM WITH 1500 PSI RUNCMP SERVICE RIG AND PRE-TOUR CHECKLIST RUNCMP FMC INSTALL TWC AND TEST FROM ABOVE TO 3500 PSI -TEST FROM BELOW TO 1000 PSI FOR 10 CHARTED MIN EACH RUNCMP E D WN BOP'S RUNCMP NIPPLE UP TBG HEAD ADAPTER AND TREE RUNCMP TERMINATE CONTROL LINE THROUGH ADAPTER TEST CCL AND ADAPTER VOID TO 5000 PSI FOR 30 MIN EACH RUNCMP TEST TREE TO 5000 PSI -NO VISUAL LEAKS RUNCMP RIG UP LUBRICATOR AND TEST TO 500 PSI -PULL TWC AND L/D SAME RUNCMP PJSM WITH LRS AND PRESSURE TEST LINES TO 3500 PSI -PUMP DIESEL DOWN IA WITH LRS -PUMPED 2 BPM WITH 1000 PSI WITH 47 BBLS AWAY PRESSURED UP TO 2000 PSI -SHUT DOWN CHECK SURFACE EQUIP. NOTHING FOUND SURFACE -CONTINUE PUMPING ~ 0.7 BPM WITH 1100 PSI -PUMPED 85 BBLS OF 70 DEGREE RUNCMP U-TUBE DIESEL -SECURE CELLAR RUNCMP PICK UP AND RIG UP THE LUBRICATOR. PRESSURE TEST TO 500 PSI. SET THE BPV. RUNCMP SECURE THE TREE AND CELLAR -BLOW DOWN AND R/D LINES RUNCMP AFTER ACTION REVIEW WITH CREW. -RIG RELEASE AT 12:00 HRS 12/15/2009. Printetl: 2/2/2010 3:2023 I'M BP EXPLORATION Page 1 af~3 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: REENTER+COMPLETE Start: 1/8/2010 End: Contractor Name: NORDIC CALISTA Rig Release: 1/8/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task. Code NPT Phase bescription of Operations 1/12/2010 00:00 - 00:10 0.17 MOB P PRE SAFETY MTG 00:10 - 04:10 4.00 MOB P PRE MOVE RIG FROM MPC-24 TO MPL PAD ~v 04:10 - 07:00 2.83 MOB N WAIT PRE WO ROADS AND PADS TO RELEVEL IN FRONT OF WELL CREW CHANGE /'' ,\ SAFETY MTG ~/ 07:00 - 09:00 2.00 MOB P PRE MOVE RIG OVER WELL AND SET DOWN 09:00 - 11:00 2.00 MOB P PRE ACCEPT RIG FOR OPERATION AT 0900 HRS 1/12/2010 SET CUTTINGS BOX, BERM CELLAR W/ SNOW, GENERAL RU R X P MOVE SNOW PILES AT EDGE OF PAD TO GIVE MORE ROOM 11:00 - 14:00 3.00 BOPSU P PRE ND THE AP. NU BOPE- DIFFICULT DUE TO WELLHEAD NOT BEING VERTICAL MOVE OFFICE TRAILER FROM MPC PAD AND SPOT SET BULLRAIL AND SWAP TO RIG POWER 14:00 - 20:00 6.00 BOPSU P PRE NU MPD LOOP, CONTINUE TO RU BOPE. SHELL TEST BOPE. 20:00 - 00:00 4.00 BOPSU P PRE P AO CC BEGS 250PSI / 3500PS1. JOHN CRISP ST. 1/13/2010 00:00 - 04:10 4.17 BOPSU P PRE CONTINUE TO PRESSURE TEST BOPE PER AOGCC BEGS, 250PSI/3500PSI. 04:10 - 04:25 0.25 BOPSU P PRE BLOW DOWN STACK, KILL LINE &MPD LOOP. 04:25 - 04:40 0.25 RIGU P PRE PJSM REGARDING RU TO PULL BPV. 04:40 - 06:45 2.08 RIGU P PRE RU LUBRICATOR. FILL STACK WITH DIESEL. PRESSURE TEST 250PSI/1100PSI. PULL 4" BPV AND FOUND 275 PSI. CREW CHANGE/SAFETY MTG REMOVE LUBRICATOR AND TOOLS FROM FLOOR. RDMO MPU DSM 06:45 - 08:50 2.08 BOPSU P PRE SAFETY MTG RU INJECTOR. FILL CT W/ KCL AND TAKE DIESEL AND NaCI TO CUTTINGS BOX PT PACKOFF AND VALVE IN REEL 250/3500 08:50 - 10:30 1.67 RIGU P PRE PUMP SLACK BACK INTO REEL 3.12/2280. BLOW CT BACK W/ AIR. RU HYD CUTTER AND CUT 324' BEFORE FINDING WIRE. RD CUTTER 10:30 - 13:45 3.25 STWHIP P WEXIT INSTALL CTC. PT 40K CT IS 13006', CTV=49.1, 440K RF INSTALL BHI LOC. PT 4000 HOOK UP HYD PANEL TO TRSSSV AND VERIFY FLAPPER IS OPEN OPEN WELLBORE TO CLOSED CHOKE. IAP 7, OAP 6. BLEED DOWN 10 PSI WHP TO TIGER TANK AND BLOW DOWN LINE 13:45 - 14:30 0.75 STWHIP P WEXIT MONITOR WELL FOR FLOW. SET INJECTOR OVER BUNGHOLE. PUMP 1.5 CT VOLUMES FORWARD 2.75/1640 WHILE HAVE PRESPUD MTG. THEN HAVE MEETING TO MU BHA 14:30 - 16:00 1.50 STWHIP P WEXIT M A #1. SET BHA IN WELLBORE AND CONFIRM SPACE OUT 16:00 - 17:25 1.42 STWHIP P WEXIT RIFJ„w/ BHA #1 CIRC THRU MILL 1.0/540 17:25 - 17:40 0.25 STWHIP P WEXIT LOG TIE-IN DOWN FROM 7200' TO 7540'. MINUS 26' CORRECTION. 17:40 - 17:45 0.08 STWHIP P WEXIT DRY TAG WS AT 7567'. ~~~•--+~ ~~ Pfiflt8tl: 7/L5/ZUIU 1"L:Uti:3U PM. Tree: 29/16" 5M ~ MPL-02A L1 LZ Wellhead: 13 5/8" x 11' 5M ~ ~ 'DGB' tbg spool w/ 11" x 2 7/8" CIW Tubing Hanger, 2 7/8" EUE 8 rd threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 48#/ft , H-40 Weld ' +-80 Set. KOP @ 3,200' Max. hole angle =33.58' deg. f/ 7700' to TD' Hole angle thru' perfs = 33 eg. Orig. K v. = 56.0' (N 27E) Pad GL~v. = 21' CTD sidetrack 02/01 /2010 Nordic 2 55~ 9 5/8", 36#/ft , J-55 Btrc. 5,076' 7" 26 #/ft, L-80, Btrc. production casing (drift ID = 6.182", cap. = 0.0383 bpf ) 4-1I2" Works~tring Stimulation Summary 11/11/90 -185.3 M lbs. 16 / 20 Carbolite TOWS at 7560' Perforation Summary Ref log: DIL / GR 03/03/90 Size SPF Interval (TVD) 4-112° x 7 packer at 7360' - X NIP (3.813" ID} at 7380' -Top of 3-3116" liner at 7404' --End of tubing at 7460' 7985' - 3-3116" uncemented Drill Liner~~,~ 2-318" slotted liner //..'J DATE REV. BY COMMENTS 11 / 16 / 90 JBF Drilled and Completed by Nabors 27E 05 / 28 / 96 MDO Recompleted by Nabors 4 ES 05 /30 /01 BMH RWO by Nabors 4 ES 02/28/06 MDO ESP RWO Nabors 3-S 7" float collar 7 808' and 7" 26 #/ft float shoe 7 901' and MILNE POINT UNIT WELL L-2A, L1, L2 API NO: 50-029-21998-01 BP EXPLORATION (AK) STATE OF ALASKA ALASKA O AND GAS CONSERVATION. COMMI ON ~~~~iv ~,~: ; 0 ~ 2010. . WELL COMPLETION OR RECOMPLETION REPORT AND 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1 b. ®Developmei~bht~~ploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 1/13/2010 12. Permit to Drill Number: 190-006 ° 309-392 '' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 02/21/1990 13. API Number: 50-029-21998-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 03/03/1990 14. Well Name and Number: MPL-02 3207 FSL, 5056 FEL, SEC. 08, T13N, R10E, UM Top of Productive Horizon: 3951' FSL, 1565' FEL, SEC. 07, T13N, R10E, UM g, KB (ft above MSL): 56' GL (ft above MSL): 15. Field /Pool(s): Milne Point Unit / Kuparuk River Total Depth: 4023' FSL, 1765' FEL, SEC. 07, T13N, R10E, UM 9. Plug Back Depth (MD+TVD): 7560' 7034' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 544825 y_ 6031397 Zone- ASP4 10. Total Depth (MD+TVD): 7936' 7346' 16. Property Designation: ADL 025509 TPI: x- 543030 y- 6032130 Zone- ASP4 Total Depth: x- 542829 Y- 6032201 Zone- ASP4 11. SSSV Depth (MD+TVD): N!A 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and rioted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): NGT / CNL / LBT / DIL 22. Re-Drill/Lateral Top Window MDlfVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING Wi. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE .CEMENTING RECORD PULLED 13-3/ " 48# H-40 urfa 82' Surfa To Surfa e " 7' rf 1 -1/4" 11 I I 7" 26# L- urf 79 1' Surf 7317' 8-1/2" 2 B I CI s' ' 24. Open to production or injection? ^ Yes ®No 25. TuewG RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ! TVD MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ `t ~'°: ~ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED ~,a ~~,~,~~~~~ ~~~ 1 .~. ~ ~ 7560' Set Whipstock ~ 7560' P&A w/ 22.5 Bbls Cement ~ 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acquired? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS FEB 0 5 2010 ~~ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only at ~~• /e ,~~ia/rn 29. GEOLOGIC MARKERS (List all formations and ma encountered): 30. NATION TESTS • NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 3517 3516' None Schrader Bluff 4057' 4043' Top HRZ 7044' 6602' , Base HRZ 7089' 6640' Kuparuk 7392' 6894' Kuparuk C 7554' 7029' Kupaurk A 7652' 7110' Miluveach 7789' 7224 Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. 0~~ ~~ Signed: Terrie Hubble Title: Drilling Technologist Date: MPL-02 190-006 309-392 Prepared ByName/Number. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Sean McLaughlin, 564-4387 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only MPL-02, Well History (Pre Rig Sidetrack) Date Summary 11/26/09 T/I/0= 400/260/360, Temp= S/I. Freeze Protect. Pumped 15 bbls diesel down Tbg. Pumped 2 bbls 60/40, 3 bbls diesel, 2bbls 60/40 down Production Line. Bled off psi. Pumped 2 bbls 60/40, 3 bbls diesel, 2 bbls 60/40 down Test Line. Bled off psi. FWHP= 400/260/360. SV,WV,SSV =Closed. MV =Open. IAV, OAv = OTG. 11/29/09 WELL S/I ON ARRIVAL. RAN 1.72" CENT, S. ABSORBER, DUAL SPARTEK GAUGES. 15 MIN GRADIENT STOP C~ 6,906' SLM (6,937' MD). TAG PUMP C~3 7,375' SLM (7,406' MD) -31' CORRECTION TO SLM. 3 HR BHP STOP C«~ 7,372' SLM (7,403' MD). PULLED DGLV FROM ST#1 C~3 7253' MD. PULLED DPSOV FROM ST#2 C«~ 168' MD. SET 1" BK DGLV IN ST#2 C~ 168' MD. ASSIST WELL SUPPORT TO SET BPV. JOB COMPLETE. WELL LEFT S/I. BPV INSTALLED. Nabors 4ES moved on this well to pull the ESP and run workstring (11/21/09 - 11/27/09). 12/19/2009 WELL S/I ON ARRIVAL. ASSIST SUPPORT TECHS W/CRANE & PULLED BPV. R/U SLICKLINE EQUIPMENT FOR POST RIG. 12/20/2009 PULL BALL & ROD FROM 7338' MD. PULL DCK SHEAR VALVE/SET 1" BK DUMMY C~ 3014' MD. PULL RHC PLUG BODY FROM 7338' MD. DRIFT TUBING W/ 20' x 3.70" DUMMY WHIPSTOCK S/D C~3 7710' SLM. WELL S/I ON DEPART. 12/21/2009 T/I/O = 0/0/0. Temp = SI. MITIA PASSED to 2500psi. Fluid packed IA w/ 18.7bbls diesel. Pressured up w/ additional 0.8bbls (19.5 total.) IA lost Opsi in 30min. Bled to zero. FWHP's = 0/0/0. IA, OA =open to gauge. Rest of tree shut (Post RWO, no flowline.) 12/22/2009 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = O/O/O, MV = C, SW = C, WV = C, IA/OA = OTG SET BAKER 4-1/2" X 7" WHIPSTOCK AT 7560', ORIENTATION WAS 2° LOHS. (REFERENCED SLB DUAL INDUCTION LOG DATED 3-MARCH-1990) POSITIVE SURFACE INDICATION OF SETTING. TWO RADIOACTIVE PIP TAGS PLACED 10' BELOW TOP OF WHIPSTOCK AT 7570' ELMD. FINAL T/I/O = 0/0/0, WV = C, MV = C, WV = C, IA/OA = OTG, WELL SHUT-IN ON DEPARTURE. JOB COMPLETE. 1/7/2010 MIRU coil tubing unit. Perform weekly BOP test. MU and RIH cementing BHA displacing well with 1% KCL then swapping to Diesel. O-ring leak on lubricator forced us to POOH to repair. RIH w/ BDN BHA. Pump 22.5 bbls 15.8 ppg cement. Bullheaded 7 2 bbls cement past whipstock to achieve 500 osi bump. then layed in 15 3 bbls cement 1 to 1 up to 6745'. Pressure up to 1200 psi for 30 minutes. Pressure held constant, no bleed off. Dropped ball and cleaned out to top of whipstock tray with 1.5# biozan. 1/8/2010 Clean out cement to whipstock tray. POOH at 80% washing all jewelry and BOP stack. Freeze protect well with 60/40 McOH from 2500'. RDMO. Job Complete. Page 1 of 1 BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: 1AE9~R~4~1FEf} ~~~ L~~Ruf) `mart: 12/9/2009 End: 7'9 Release: 2/1/2010 Contractor Name: ~`~ .. Rig Name: ~ ~4~('S 4'F,5 Rig Number: N2 .Date From- To ~' Hours Task .Code NPT Phase l Description of Operations 12/9/2009 11:30 - 12:30 1.00 RIGD P PRE SCOPE DOWN DERRICK AND LAY OVER -PREP RIG FOR MOVE 12:30 - 14:30 2.00 MOB N WAIT PRE WAIT ON TRUCKS TO MOVE RIG. DOYON 15 BLOCKING SPINE ROAD. 14:30 - 18:00 3.50 MOB P PRE PJSM WITH PEAK AND RIG CREW -MOVE CAMP, PIPE SHED, PITS AND SUB OFF OF WELL L-36 -GAVE AOGCC 24-HRS. NOTIFICATION OF BOPE TESTING 18:00 - 21:30 3.50 MOB P PRE -SPOT PITS & PIPE SHED -MOVE CAMP AND SPOT IN FRONT OF RIG 21:30 - 00:00 2.50 RIGU P PRE RAISE DERRICK AND SCOPE UP -RIG UP FLOOR AND PITS 12/10/2009 00:00 - 01:00 1.00 RIGU P PRE CONTINUE TO RIG UP FLOOR AND PITS -RIG ACCEPTED C~ 0100 HRS ON 12-10-09 01:00 - 02:00 1.00 RIGU P PRE RU, SPOT TIGER TANK AND HOOK UP LINES. -RU CIRCULATING LINES TO TREE WING VALVE AND IA. 02:00 - 03:00 1.00 WHSUR P DECOMP PICK UP DSM LUBRICATOR AND FILL WITH DIESEL -TEST TO 500 PSI -PULL BPV AND LAY DOWN 03:00 - 04:30 1.50 KILL P DECOMP TAKE ON 580 BBLS OF 8.6 PPG SEAWATER 110 DEGREE INTO PITS -HOLD PJSM WITH CREW AND CH2MHILL DRIVERS FOR WELL KILL ~! 04:30 - 05:30 1.00 KILL P DECOMP TEST LINES TO 3500 PSI -OPEN WELL TAKE PRESSURES -IA=330 - OA=80 - T=310 05:30 - 08:30 3.00 KILL P DECOMP -PUMPED 150-BBLS. 110E SEAWATER DOWN TUBING AT 5.0-BPM AT 300-900 PSI. WITH NO RETURNS TO SURFACE. -CAUGHT FLUID AT 3800' FROM SURFACE. -SHUT DOWN PUMPING. TUBING AND IA ON VACUUM. -SHUT IN TUBING AND BULLHEAD 350-BBLS OF 110E SEAWATER DOWN IA. -SHUT DOWN PUMPING AND MONITORED WELL FOR 30-MINUTES. TBG. AND IA ON VACUUM. 08:30 - 11:30 3.00 WHSUR N WAIT DECOMP WAIT ON CAMERON WELLHEAD TECH TO ARRIVE ON PAD. CAMERON WELLHEAD TECH. UNABLE TO ARRIVE ON TIME DUE TO BEING HELD UP BY NORDIC 2 RIG MOVE ON SPINE ROAD. 11:30 - 12:30 1.00 WHSUR P DECOMP CAMERON WELLHEAD TECH SET TWC WITH "T" BAR ENSURING PROPER TRAVEL INTO TUBING HANGER PROFILE. PRESSURE TEST TWC FROM BELOW BY PUMPING AT 3.0-BPM AND CHARTING TEST FOR 10-MINUTES. NO PRESSURE OBTAINED FROM BELOW. PRESSURE TESTED TWC FROM ABOVE TO 3500-PSI FOR 10-MINUTES CHARTED. 12:30 - 14:00 1.50 WHSUR P DECOMP CAMERON WELLHEAD TECH PRESSURE TESTED TUBING HANGER VOID TO 5000-PSI. N/D TREE AND ADAPTER FLANGE. CAMERON WELLHEAD TECH. PRESSURE TESTED CASING PACKOFF TO 3000-PSI. 14:00 - 17:00 3.00 BOPSU P DECOMP NU BOPE. AOGCC -CHUCK SCHEVE WAIVED TEST WITNESS. Nnntea: uuzuiu s:eu:~~ rnn • • $P EXPLORATION Page 2 of 6 Qperations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 12/9/2009 End: Contractor Name: Rig Release: 2/1/2010 Rig Name: Rig Number: N2 Date From - To ~ Hours j Task Code NPT ~ phase Description of Operations 12/10/2009 17:00 - 23:30 6.50 BOPSU P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: . BOP CONFIGURATION: -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. -SPACER SPOOL. -2 7/8" X 5" VARIABLE BORE RAMS. -TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" TEST JOINT. -TESTED ANNULAR W ITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. 200 PSI BUILD UP FROM 1700 PSI = 45 SECONDS. -FULL BUILD UP TO 3000 PSI = 166 SECONDS. -4 BOTTLES x 1670 PSI. -CHUCK SCHEVE WAIVED AOGCC RIGHT TO WITNESS BOPE TEST AT 15:00-HRS ON 12-10-09. 23:30 - 00:00 0.50 BOPSU P DECOMP R/U DUTCH SYSTEM AND P/U WELL SUPPORT LUBRICATOR TO PULL TWC 12/11/2009 00:00 - 01:00 1.00 BOPSU P DECOMP CONTINUE R/U LUBRICATOR -TEST TO 500 PSI AND PULL TWC -L/D LUBRICATOR AND DUTCH SYSTEM 01:00 - 04:30 3.50 PULL N WAIT DECOMP CLEAR ICE FROM DERRICK -BLOCKS WOULD NOT LOWER TO FLOOR DUE TO FROST ON LINES -BLOCK OFF PAD ENTRANCE AND CLEAR FLOOR -DERRICK HAND SENT UP TO CLEAR ICE AND FROST FROM LINES AND DERRICK 04:30 - 06:00 1.50 PULL P DECOMP JT. INSTALL CLOSED TIW VALVE -SCREW INTO HANGER WITH 8-1/2 TURNS -CAMERON REP. BOLDS -PULL HANGER TO FLOOR -PU WT.=70K TO BREAK FREE -PULLED AT 57K -DID NOT ATTEMPT CBU. CANNOT FILL HOLE. 06:00 - 06:30 0.50 PULL P DECOMP CREW CHANGE. -SERVICE RIG AND CLEAR ICE FROM DERRICK -CHECK PVT'S AND ENVIRO WALKAROUND 06:30 - 13:00 6.50 PULL P DECOMP POH WITH COMPLETION. -POH STANDING 2-7/8" TUBING IN DERRICK. -CONTINUOUS HOLE FILL WITH 20-BPH PLUS PIPE AND ESP CABLE DISPLACEMENT WHILE POH. -78 STANDS PIPE IN DERRICK. -TUBING IN GOOD CONDITION AND NO FOREIGN MATERIAL DEPOSITION ON TUBING INSIDE OR OUTSIDE. -RECOVERED 234 JTS. 2-7/8" 8RD. TUBING, 2 X 2-78" X 1" GLMS, "XN" NIPPLE, 1 X 10' 2-7/8" SRD. PUP, 1 X 8' 2-7/8" ~~ Panted: vzizoto ~:zo:zs ran • BP EXPLORATION Page 3 of'6 ..Operations Surnmalry Report: Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 12/9/2009 End: Contractor Name: Rig Release: 2/1/2010 Rig Name: Rig Number: N2 .Date From - To Hours Task Code NPT Phase Description of Operations 12/11/2009 06:30 - 13:00 6.50 PULL P DECOMP 8RD. PUPS AND 1 X 2' 2-7/8" 8RD. PUP AND WKM TUBING HANGER. 13:00 - 16:00 3.00 PULL P DECOMP ENTRILIFT BROKE OUT AND LAYED ESP BHA DOWN. ~ -RECOVERED PUMP DISCHARGE HEAD, PUMP, PUMP, GAS SEPARATOR, SEAL SECTION, SEAL SECTION, MOTOR, PUMPMATE SENSOR AND CENTRALIZER. NO FOREIGN MATERIAL DEPOSITION ON ESP BHA. 16:00 - 17:00 1.00 PULL P DECOMP CLEAR AND CLEAN RIG FLOOR AND PREP. TO RIH WITH SCRAPER BHA. 17:00 - 18:00 1.00 PULL N WAIT DECOMP CLEAR ICE FROM DERRICK 18:00 - 18:30 0.50 PULL P DECOMP CREW CHANGE. -SERVICE RIG AND CLEAR ICE FROM DERRICK -CHECK PVT'S AND ENVIRO WALKAROUND 18:30 - 19:00 0.50 CLEAN P DECOMP PUMU 6-1/8" BIT, 7" CASING SCRAPER, 2 X 4-3/4" BOOT BASKETS AND XO TO 2-7/8" 8RD. TUBING. TTL LENGTH = 14.86' 19:00 - 23:30 4.50 CLEAN P DECOMP RIH WITH CASING SCRAPER BHA ON 77 STANDS OF 2-7/8" 8RD. TUBING FROM DERRICK. P/U 11SINGLES FROM PIPE SHED. SCRAPE FROM 7,332' TO 7,425' & 7,522' TO 7,613', 3) TIMES EACH. PUW=43K SOW=38K. FEED WELL WITH CONTINUOUS HOLE FILL AT 20-BPH. 23:30 - 00:00 0.50 CLEAN P DECOMP R/U POWER TONGS AND FLOOR FOR POH AND STANDING BACK 2-7/8" 8RND TBG. 12/12/2009 00:00 - 01:00 1.00 CLEAN N WAIT DECOMP CLEAR ICE FROM DERRICK 01:00 - 04:00 3.00 CLEAN P DECOMP POH STANDING BACK 80 STANDS OF 2-7/8" 8RND TBG IN DERRICK 04:00 - 05:00 1.00 CLEAN P DECOMP UD BHA #1 SCRAPER ASSY. -CLEAR AND CLEAN RIG FLOOR 05:00 - 06:00 1.00 CLEAN P DECOMP BRING 7" HALCO RBP TO FLOOR -MAKE UP RBP BHA 06:00 - 06:30 0.50 CLEAN P DECOMP CREW CHANGE. -SERVICE RIG AND CLEAR ICE FROM DERRICK -CHECK PVT'S AND ENVIRO WALKAROUND 06:30 - 13:00 6.50 DHB P DECOMP RIH WITH 7" RBP ON 2-7/8" 8RND TBG TO 7510'. - CHECKING EVERY 2-7/8" CONNECTION ON THE WAY IN TO 2300 FT/LBS. SFT THE RBP AND PRESSURE TEST TO S CHARTED. GOOD TEST. ~' 13:00 - 14:00 1.00 DHB P DECOMP RIG UP AND REVERSE CIRCULATE TO CLEAN UP INSIDE OF TUBING. 14:00 - 15:00 1.00 DHB P DECOMP PRESSURE TEST THE 7" CASING AND THE RBP TO 2000 PSI FOR 30 MINUTES CHARTED. GOOD TEST. 15:00 - 16:30 1.50 DHB P DECOMP LAY DOWN A SINGLE AND 3 STANDS OF 2-7/8" 8RND TBG. MAKE UP STORM PACKER RIH AND SET AT 25.5'. PRESSURE TEST THE 7" STORM PACKER TO 2000 PSI FOR 20 MINUTES CHARTED. GOOD TEST. 16:30 - 18:00 1.50 CLEAN P DECOMP PULL OUT THE VBR's AND HAVE REDRESSED WHILE N/D BOP STACK. ONCE THE STACK IS N/D, INSTALL THE NEW FMC TBG SPOOL ONTO THE EXISTING CAMERON WKM TBG SPOOL. 18:00 - 19:00 1.00 CLEAN P DECOMP CREW CHANGE. -SERVICE RIG AND CLEAR ICE FROM DERRICK -CHECK PVT'S AND ENVIRO WALKAROUND 19:00 - 21:00 2.00 CLEAN P DECOMP CONTINUE N/U DSA AND STACK -PAD STUDS ON FMC Printed: 2/2/2010 3:20:23 PM • • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 12/9/2009 End: Contractor Name: Rig Release: 2/1/2010 Rig Name: Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/12/2009. 19:00 - 21:00 2.00 CLEAN P DECOMP TBG HEAD TOO LONG TO GET ANY TYPE OF WRENCH ON -CONSULT FMC, CAMERON, AND TOWN ENGINEER. 21:00 - 00:00 3.00 CLEAN N WAIT DECOMP SET BACK BOP'S AND REMOVE FMC TBG SPOOL, SHORTEN PAD STUDS 1/2" -INSTALL REBUILT VBR'S 12/13/2009 00:00 - 02:00 2.00 BOPSU P DECOMP N/U FMC TBG SPOOL AND TO. NUTS -INSTALL BOP STACK AND TO. NUTS 02:00 - 05:00 3.00 BOPSU P DECOMP R/U AND TEST 2-7/8"X5" VBR'S WITH 2-7/8" & 4-1/2" TEST JT -TEST BREAKS, CHOKE AND KILL LINES -ALL TESTS TO 250 PSI LOW AND 3500 PSI HIGH -5 CHARTED MINUTES EACH -R/D TEST EQUIPMENT 05:00 - 07:30 2.50 DHB P DECOMP P/U 24' 3-1/2" IF PUP JT WITH STORM VALVE RETRIEVING TOOL -CHECK FOR PRESSURE -RELEASE STORM VALVE -PULL AND UD 07:30 - 12:30 5.00 DHB P DECOMP M/U 3 STANDS AND 1 JT. OF 2-7/8" TUBING AND RIH TO LATCH UP ON THE 7" RBP. RELEASE THE RBP (SHOWED SIGNS OF BEING ON A VAC) PUMP 150 BBLS DOWN THE HOLE AND BEGIN PULLING OUT OF THE HOLE LAYING DOWN THE 2-7/8" TUBING. -CONSTANT HOLE FILL OF 20 BBUHR. 12:30 - 13:30 1.00 DHB N WAIT DECOMP HIGH LEVEL H2S ALARM ON THE RIG. SECURE THE WELL AND EVACUATE THE RIG AND SECURE THE PAD. CONTACT THE RWO SUPERINTENDENT AND NABOBS SUPERINTENDENT. BEFORE THE DRILLER LEFT THE FLOOR THE SIERRA MONITOR READ NO H2S. THEREFORE AFTER CONSULTING WITH THE SUPERINTENDENTS THE DRILLER AND LEAD FLOORHAND PUT ON SCBA'S AND "SNIFFED" THE RIG AND IT SHOWED NO SIGNS OF H2S. OPERATIONS RESUMED AS PLANNED. 13:30 - 18:30 5.00 DHB P DECOMP CONTINUED TO PULL OUT OF THE HOLE LAYING DOWN THE 2-7/8" 8RND TUBING. -UD 239 JTS OF 2-7/8" 8 RND TBG. -UD 7" HALCO RBP AND RUNNING TOOL -CONSTANT HOLE FILL OF 40 BBUHR. 18:30 - 19:30 1.00 BUNCO P RUNCMP CREW CHANGE. -SERVICE RIG -CHECK PVT'S AND ENVIRO WALKAROUND 19:30 - 20:00 0.50 BUNCO RUNCMP R/U TONGS FOR RUNNING TBG -LOAD JEWELERY INTO PIPE SHED & INSPECT 20:00 - 00:00 4.00 BUNCO RUNCMP MAKE__UP TAIL P_I_PE ASSY & BAKER S-3 PACKER RUNNING ORDER -AVERAGE MAKE UP TO. = 3800 FT LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. -40 JOINTS IN HOLE ~ 00:00 HRS -CONSTANT HOLE FILL OF 40 BBUHR. Panted: 2/2/2010 3:20:23 PM • BP EXPLORATION 'Page 5 of 6 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 12/9/2009 End: Contractor Name: A Rig Release: 2/1/2010 Rig Name: Rig Number: N2 Date From - To Hours. Task Code NPT Phase Description of Operations 12/14/2009 00:00 - 01:00 1.00 BUNCO RUNCMP SHUT DOWN FOR LUNCH AND HOLD WEEKLY SAFETY MEETING 01:00 - 04:30 3.50 BUNCO RUNCMP CONT. TO RUN 4-1/2", 12.6 LB/FT, L-80, IBT-M COMPLETION PER RUNNING ORDER -AVERAGE MAKE UP TO. = 3800 FT LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. -122 JOINTS IN HOLE ~ 04:30 HRS -CONSTANT HOLE FILL OF 40 BBUHR. 04:30 - 05:30 1.00 BUNCO RUNCMP R/U SHEAVE AND CONTROL LINE SPOOLER 05:30 - 06:00 0.50 BUNCO RUNCMP CONT. TO RUN 4-1/2", 12.6 LB/FT, L-80, IBT-M COMPLETION PER RUNNING ORDER -AVERAGE MAKE UP TO. = 3800 FT LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. -CONSTANT HOLE FILL OF 40 BBUHR. 06:00 - 06:30 0.50 BUNCO RUNCMP SERVICE RIG AND PRE-TOUR CHECKLIST. 06:30 - 07:00 0.50 BUNCO P RUNCMP RIG UP THE CONTROL LINE SPOOLER AND SHEAVE. STRING THE CONTROL LINE. 07:00 - 12:30 5.50 BUNCO P RUNCMP CONT. TO RUN 4-1/2", 12.6 LB/FT, L-80, IBT-M COMPLETION PER RUNNING ORDER -AVERAGE MAKE UP TO. = 3800 FT LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. -CONSTANT HOLE FILL OF 40 BBUHR. 12:30 - 14:30 2.00 BUNCO RUNCMP TERMINATE THE CONTROL LINE AT THE FLOOR. MAKE UP THE TUBING HANGER, RUN IN THE HOLE AND LAND, WHILE HOLDING CONSTANT PRESSURE ON THE CONTROL LINE TO KEEP THE SSSV OPEN. DROP THE BALL AND ROD . COMPLETION CONSISTS OF THE FOLLOWING: -4-1/2" WLEG -BAKER LOK'D 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING JT. -4-1/2" X NIPPLE W/ RHC SLEEVE -BAKER 7" X 4-1/2" S-3 PRODUCTION PACKER -BAKER 80-47 PBR ASSEMBLY -4-1/2" X NIPPLE (3.813" ID) -JTS (1-105) 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING -4-1/2" X 1" KBG GLM W/ DCK SHEAR -JTS (106-122) 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING JT. -4-1/2" TRM-4PE-CF SSSV -JTS (123-178) 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING JT. -SPACE OUT PUP 7.82' -JT (179) 4-1/2", 12.6 LB/FT, L-80 IBT-M TUBING JT. -FMC 10" X 4-1/2" TUBING HANGER -CONTROL LINE FROM 2300' TO SURFACE -62 SS CONTROL LINE BANDS 14:30 - 17:00 2.50 BUNCO RUNCMP PUMP DOWN THE TUBING AND PRESSURE UP TO 3500 PSI TO SET AND TEST THE PACKER. HOLD 3500 PSI FOR 30 CHARTED MINUTES. BLEED OFF THE TUBING TO 0 PSI AND BOLDS AND PULL THE HANGER TO THE FLOOR Printed: 2/2/2010 3:20:23 PM • BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Event Name: WORKOVER Contractor Name: Rig Name: Date From - To Hours Task Co 12/14/2009 114:30 - 17:00 I 2.501 BUNCO 17:00 - 18:00 I 1.001 RU 18:00 - 18:30 0.50 RU 18:30 - 20:00 1.50 RU 20:00 - 21:00 1.00 BOPSU~ P 21:00 - 22:00 1.00 WHSUR P 22:00 - 00:00 2.00 WHSUR P 12/15/2009 100:00 - 01:00 I 1.001 WHSUR I P Spud Date: 2/21 /1990 Start: 12/9/2009 End: Rig Release: 2/1 /2010 Rig Number: N2 NPT Phase Description of Operations RUNCMP TO VERIFY THE PBR SHEARED. GOOD SHEAR. RUN IN AND LAND THE HANGER AGAIN. RILDS, PRESSURE UP TUBING TO 1500 PSITHE IA TO 2000 PSI FOR 30 CHARTED MINUTES. BLEED OFF THE PRESSURE AND PRESSURE UP THE ANNULUS TO SHEAR THE DCK VALVE. SHEARED AT 1875 PSI. RUNCMP PUMP THROUGH DCK VALVE BOTH WAYS -PUMP DOWN TBG ~ 3 BPM WITH 1500 PSI -PUMP DOWN IA ~ 3 BPM WITH 1500 PSI RUNCMP SERVICE RIG AND PRE-TOUR CHECKLIST RUNCMP FMC INSTALL TWC AND TEST FROM ABOVE TO 3500 PSI -TEST FROM BELOW TO 1000 PSI FOR 10 CHARTED MIN EACH RUNCMP E DOWN BOP'S RUNCMP NIPPLE UP TBG HEAD ADAPTER AND TREE RUNCMP TERMINATE CONTROL LINE THROUGH ADAPTER TEST CCL AND ADAPTER VOID TO 5000 PSI FOR 30 MIN EACH RUNCMP TEST TREE TO 5000 PSI -NO VISUAL LEAKS 01:00 - 02:00 1.00 WHSUR P RUNCMP RIG UP LUBRICATOR AND TEST TO 500 PSI -PULL TWC AND UD SAME 02:00 - 05:30 3.50 WHSUR P RUNCMP PJSM WITH LRS AND PRESSURE TEST LINES TO 3500 PSI -PUMP DIESEL DOWN IA WITH LRS -PUMPED 2 BPM WITH 1000 PSI WITH 47 BBLS AWAY PRESSURED UP TO 2000 PSI -SHUT DOWN CHECK SURFACE EQUIP. NOTHING FOUND ~ SURFACE -CONTINUE PUMPING ~ 0.7 BPM WITH 1100 PSI -PUMPED 85 BBLS OF 70 DEGREE 05:30 - 07:30 2.00 WHSUR P RUNCMP U-TUBE DIESEL -SECURE CELLAR 07:30 - 08:30 1.00 WHSUR P RUNCMP PICK UP AND RIG UP THE LUBRICATOR. PRESSURE TEST TO 500 PSI. SET THE BPV. 08:30 - 11:00 2.50 WHSUR P RUNCMP SECURE THE TREE AND CELLAR -BLOW DOWN AND R/D LINES 11:00 - 12:00 1.00 WHSUR P RUNCMP AFTER ACTION REVIEW WITH CREW. -RIG RELEASE AT 12:00 HRS 12/15/2009. Printed: 2/2/2010 3:20:23 PM s • BP EXPLORATION Page 1 of~3 Operations Summary Report Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: REENTER+COMPLETE Start: 1/8/2010 End: Contractor Name: NORDIC CALISTA Rig Release: 1/8/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/12/2010 00:00 - 00:10 0.17 MOB P PRE SAFETY MTG 00:10 - 04:10 4.00 MOB P PRE MOVE RIG FROM MPC-24 TO MPL PAD 04:10 - 07:00 2.83 MOB N WAIT PRE WO ROADS AND PADS TO RELEVEL IN FRONT OF WELL CREW CHANGE r'~ ,\ SAFETY MTG ~/ 07:00 - 09:00 2.00 MOB P PRE MOVE RIG OVER WELL AND SET DOWN 09:00 - 11:00 2.00 MOB P PRE ACCEPT RIG FOR OPERATION AT 0900 HRS 1/12/2010 SET CUTTINGS BOX, BERM CELLAR W/ SNOW, GENERAL RU R X P MOVE SNOW PILES AT EDGE OF PAD TO GIVE MORE ROOM 11:00 - 14:00 3.00 BOPSU P PRE DIFFICULT DUE TO WELLHEAD NOT BEING VERTICAL MOVE OFFICE TRAILER FROM MPC PAD AND SPOT SET BULLRAIL AND SWAP TO RIG POWER 14:00 - 20:00 6.00 BOPSU P PRE NU MPD LOOP, CONTINUE TO RU BOPE. SHELL TEST ROPE. 20:00 - 00:00 4.00 BOPSU P PRE P AOG BEGS 250PSI / 3500PSI. JOHN CRISP ST. 1/13/2010 00:00 - 04:10 4.17 BOPSU P PRE CONTINUE TO PRESSURE TEST BOPE PER AOGCC BEGS, 250PSI/3500PSI. 04:10 - 04:25 0.25 BOPSU P PRE BLOW DOWN STACK, KILL LINE &MPD LOOP. 04:25 - 04:40 0.25 RIGU P PRE PJSM REGARDING RU TO PULL BPV. 04:40 - 06:45 2.08 RIGU P PRE RU LUBRICATOR. FILL STACK WITH DIESEL. PRESSURE TEST 250PSI/1100PSI. PULL 4" BPV AND FOUND 275 PSI. CREW CHANGE/SAFETY MTG REMOVE LUBRICATOR AND TOOLS FROM FLOOR. RDMO MPU DSM 06:45 - 08:50 2.08 BOPSU P PRE SAFETY MTG RU INJECTOR. FILL CT W/ KCL AND TAKE DIESEL AND NaCI TO CUTTINGS BOX PT PACKOFF AND VALVE IN REEL 250/3500 08:50 - 10:30 1.67 RIGU P PRE PUMP SLACK BACK INTO REEL 3.12/2280. BLOW CT BACK W/ AIR. RU HYD CUTTER AND CUT 324' BEFORE FINDING WIRE. RD CUTTER 10:30 - 13:45 3.25 STWHIP P WEXIT INSTALL CTC. PT 40K CT IS 13006', CTV=49.1, 440K RF INSTALL BHI LOC. PT 4000 HOOK UP HYD PANEL TO TRSSSV AND VERIFY FLAPPER IS OPEN OPEN WELLBORE TO CLOSED CHOKE. IAP 7, OAP 6. BLEED DOWN 10 PSI WHP TO TIGER TANK AND BLOW DOWN LINE 13:45 - 14:30 0.75 STWHIP P WEXIT MONITOR WELL FOR FLOW. SET INJECTOR OVER BUNGHOLE. PUMP 1.5 CT VOLUMES FORWARD 2.75/1640 WHILE HAVE PRESPUD MTG. THEN HAVE MEETING TO MU BHA 14:30 - 16:00 1.50 STWHIP P WEXIT HA #1. SET BHA IN WELLBORE AND CONFIRM SPACE OUT 16:00 - 17:25 1.42 STWHIP P WEXIT BIH w/ BHA #1 CIRC THRU MILL 1.0/540 17:25 - 17:40 0.25 STWHIP P WEXIT LOG TIE-IN DOWN FROM 7200' TO 7540'. MINUS 26' CORRECTION. 17:40 - 17:45 0.08 STWHIP P WEXIT DRY TAG WS AT 7567'. MQL ~ ~./L1 + ~ ~ rnrnea: vzarzuiu icuo:au rrn Tree: 29/16" 5M ~ MPL-02A L1 L2 Wellhead: 13 5/8" x 11" 5M ~ ~ 'DGB' tbg spool w/ 11" x 2 7/8" CIW Tubing Hanger, 2 7/8" EUE 8 rd threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 48#/ft , H-40 Weld ' +-80 Set. KOP @ 3,200' Max. hole angle =33.58' deg. f/ 7700' to TD' Hole angle thru' perfs = 33 eg. Orig. K v. = 56.0' (N 27E) Pad Glv. = 21' CTD sidetrack 02/01 /2010 Nordic 2 412' 9 5/8", 36#/ft , J-55 Btrc. 5,076' 7" 26 #/ft, L-80, Btrc. production casing (drift ID = 6.182", cap. = 0.0383 bpf ) 4-112" Warkstring Stimulation Summary 11/11/90 -185.3 M lbs. 16 / 20 Carbolite TOWS at 7560' Perforation Summary Ref log: DIL / GR 03/03/90 Size SPF Interval (TVD) 4-112" x 7 packer at 7360' X NIP (3.813" iDa at 7380' -Top of 3-3116" liner at 7404' -End of tubing at 7460' 7985' - 3-3116" uncemented Drill Liner ;: 2-3{8" slotted liner ~, DATE REV. BY COMMENTS 11 / 16 / 90 JBF Drilled and Completed by Nabors 27E 05 / 28 / 96 MDO Recompleted by Nabors 4 ES 05 /30 /01 BMH RWO by Nabors 4 ES 02/28/06 MDO ESP RWO Nabors 3-S MILNE POINT UNIT WELL L-2A, L1, L2 API NO: 50-029-21998-01 BP EXPLORATION (AK) 7" float collar 7 808' and 7" 26 #/ft float shoe 7 9 1' and i L SEAN PARNELL, GOVERNOR U , ALASKA OIL AND GAS 33 H. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 0c)(0 Re: Milne Point Unit, Kuparuk River Oil Pool, MPL-02 Sundry Number: 309-392 WANN EV D ELI 8 2009 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 0 K. mi kioner DATED this 30 day of November, 2009 Encl. © ,O CI STATE OF ALASKA RECEIVED ��� 11� ALASOIL AND GAS CONSERVATION COMMIIbN NOV 1 8 1009 1k, 20 0 APPLICATION FOR SUNDRY APPROVAL 1 k 20 AA 25.280 41ask a Oil 8t Gas ions. Commission 1. Type of Request: Anchorage ® Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Specify: ❑ Change Approved Program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 190 -006 • ® Development, ❑Exploratory 3. Address: ❑ Service ❑ Stratigraphic 6. API Number. 2,1 9� c P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 -21 0 -00 It I' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: MPL -02 Spacing Exception Required? ❑ Yes ® No - 9. Property Designation: 10. Field / Pool(s): ADL 025509 Milne Point Unit / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7936' 7346' 1 7808' 7240' None None Casing Lenoth Size MD TVD Burst Colla Structural Conductor 2' 1740 7 Surface 5076' /8" 5076' 4 520 2020 Intermediate Production 7901' 1 7" 7317' 7240 541 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7555' 7030' 7182' 2 - 7/8 ", 6.5# L - 80 7473' Packers and SSSV Type: None M�� d SSSV None TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑Exploratory 19 Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 5, 2009 ❑ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ® Abandoned 16. Verbal Approval: Date: ❑ WINJ ❑ GINJ ❑ WAG ❑ Plugged ❑ SPLUG Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin 564 -4387 Printed Name John NyefVl II Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564 -4711 Date (�' Terrie Hubble, 564 -4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness 16 Sundry Number - Cd Plug Integrity 12 Test ❑ Mechanical Integrity Test ❑ Location Clearance * - 3 Sock ps` �— Other: ie` Z,� Db �o Sc: �hwwC -•w `�s � ��+'.'..�. Subsequent Form Required: /D • y Approved By: COMMISSIONER APPROVED BY THE COMMISSION Date ��'� - 40 Fo 1 07/20 Submit In Duplicate ��� RIGINA To: Tom Maunder Petroleum Engineer O bp Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: November 11, 2009 Re: Milne Point L -02 Sundry Approval Sundry approval is requested to abandon perforations on well MPL -02 in preparation for a CTD sidetrack. MPL -02 was drilled 11/16/90 and completed as an "A" sand KUP producer. The well was frac'ed Nov 1990 with 185K# Carbolite behind pipe. The well is seeing some support from MPL -09i with a quick response time but not get getting good sweep. The well is currently online making low oil rate and high water cut. A tri- lateral (MPL -02A, AL1, and AI-2) will be drilled to a more optimum location. The sidetracks, MPL -02A, AL1, and AL2, is scheduled to be drilled by Nordic 2 starting January 12, 2010 using the managed pressure drilling technique. The horizontal laterals will target Kuparuk Al, A2, and A3 reserves to . capture currently nonrecoverable resources. The perforations in the parent well will be abandoned with cement downsqueezed past the whipstock. The sidetrack lateral will exit the parent well at 7,560' and in the B shale and drill 3 laterals, each targeting a different "A" sand. Slotted liner will be run into each of the laterals. An aluminium liner top billet will facilitate the kick off for the second and third laterals. A liner top packer and solid liner across the build /turn section will slow water production from near the parent well. The following describes work planned. A schematic diagram of the proposed sidetrack is attached for reference. C 1'q/"r `V,;,/- /kv -,-I 9 fi+,41e/ �EV Iv 44 rjn� {moo.,. /7"G, LC, /- �, r /PCV -;, O,� t � i �o.�e wed Tys �rr, vv � CTD Sidetrack Summary Prior to drilling operations a workover rig will lay down the ESP completion and run a 4 -1/2" workstring. After the coil drilling unit is rigged down the workover rig will return to pull the kill string and rerun the ESP completion. Nabors 4ES RWO operations: The RWO is slated to begin about December 05, 2009 1. MIRU. Test BOPE to 3500 psi. 2. Kill Well 3. Pull 2 -7/8" ESP completion n i � s� ��r, 4. Perform a scraper run in the 7" csg c 5. RIH with 7" test packer. Test 7" csg integrity to 2000 psi. l�'Z EMW 6. Run 4 -1/2" workstring with a 7" pkr and PBR. 7. RDMO to allow Nordic II to sidetrack well ztr 7_147 Pre -CT Rig Work: The pre CTD work is slated to begin immediately following the RWO 1. Pull ball and rod 2. Pull RHC sleeve 3. Run dummy WS drift to 7,650' 4. Set Baker whipstock at 7,560' 5. Downsqueeze cement past whipstock, 20 bbls of 15.8 ppg cement 6. Drill mousehole extension �- r c st- ao Rig idetrack Operations: Scheduled to begin on January 12, 2010 using Nordic rig 't S 9 P ( 9 rY 9 9) 2 1. MIRU Nordic Rig 2 2. NU 7- 1/16" CT Drilling BOPE and test. 3. Mill 3.8" window in 7" liner from mechanical whipstock set at 7,560'. 4. Drill build section with 4 -1/8" bicenter bit, and land well in target A sand. 5. Drill lateral section to 9,430'. IT 6. Run 2 -7/8" slotted liner with aluminium billet at 8220'. 7. Kick off billet and drill 2 nd lateral section to 9,430'. 1 4 7 8. Run 2 -7/8" slotted liner with aluminium billet at 8100'. 9. Kick off billet and drill 3 nd lateral section to 9,430'. 10. Run 2 -7/8" slotted x 3- 3/16" solid to 7,420'. 11. Run liner top packer 12. FP well to 2000'. i 13. ND 7- 1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 2. Nabors 4ES RWO operations: The RWO is slated to begin after the sidetrack 1. MIRU after Nordic II finishes 2. Test BOPE to 3500 psi. 3. Shear PBR and pull 4 -1/2" workstring 4. Run new ESP on 2 -7/8" tubing 5. RDMO Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Pull BPV. Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble Tree: 2 9/16" 5M MR& 02 Ong. KB Elev. = 56.0' (N 27 Wellhead: 13 5/8" x 11" 5M CIW Pad GL Elev. = 21' 'DGB' tbg spool w/ 11" x 2 7/8" CIW Tubing Hanger, 2 7/8" EUE 8 rd threads top and bottom and 2.5" ' CIW 'H' BPV profile 13 3/8" 48 #/ft , H-40 Weld + 80 Set. Camco 2 -7/8" x 1" 168' KOP @ 3,200' sidepocket KBMM GLM Max. hole angle = 33.58' deg. f/ 7700' to TD' Hole angle thru' perfs = 33 eg. 9 5/8 ", 36 #/ft , J -55 Btrc. 5,076' 7" 26 # /ft, L -80, Btrc. production casing ( drift ID = 6.182 ", cap. = 0.0383 bpf ) Camco 2 -7/8" x 1" sidepocket KBMM GLM 7,253' 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00592 bpf) 7" RA TAG @ 7,288' XN 2 7/8" "XN" Nipple 7,392' Centrilift pump 151 Stage GC 1700 / 19GC8200 7,406' GPMTAR 1:1 Tandem Gas Separator 7,431' GRSFTXARH6 (400 Internal) Tandem Seal Section Stimulation Summary GSB3 DB UTABHSNPFSA 7,436 11/11/90 -185.3 M lbs. 16 / 20 Carbolite GS83DBLTABHSNFSACL5 Centrilift 209 HP KMH 7 450' 2385 volt / 53 amp Perforation Summary a Pumpmate w/6 fin Centralizer 7,470' Ref log: DIL / GR 03/03/90 Size SPF Interval (TVD) 4.5 5 7,555'- 7,209' - 5 7,614' 7,080' 4.5 5 7,654'- 7,112' - 5 7,680' 7,134' 4.5 7,686'- 7,139'- " 7,714' 7,162' 4.5 7,730'- 7,175'- " 7,738' 7,181' 7" float collar 7 808' and 7" 26 #/ft float shoe 7 901' and DATE REV. BY COMMENTS MILNE POINT UNIT 11/16/90 JBF Drilled and Completed by Nabors 27E WELL L -2 05/28/96 MDO Recompleted by Nabors 4 ES API NO: 50 -029 -21998 05/30/01 BMH RWO by Nabors 4 ES 02/28/06 MDO ESP RWO Nabors 3 -S BP EXPLORATION (AK) Tree: 2 9/16" 5M M P U L - 02 Orig. lev. = 56.0' (N 27E) 1v�CV Wellhead: 13 5/8" x 11" 5 Pad ev. = 21' 'DGB' tbg spool w/ 11" x 2 7/8" CIW Tubing Hanger, 2 7/8" ELIE 8 Proposed CTD sidetrack rd threads top and bottom and 2.5" ' CIW 'H' BPV profile 13 3/8" 48 #/ft , H-40 Weld +-80 Set. KOP @ 3,200' Max. hole angle = 33.58' deg. f/ 7700' to TD' Hole angle thru' perfs = 33 - 7e - g. 9 5/8 ", 36 #/ft , J -55 Btrc. 5,076' I 7" 26 # /ft, L -80, Btrc. production casing ( drift ID = 6.182 ", cap. = 0.0383 bpf ) 4 -1/2" Workstring Stimulation Summary 4 -1/2" x 7 packer at 7360' 11/11/90 -185.3 M lbs. 16 / 20 Carbolite X NIP (3.813" ID) at 7380' TnWS at 7560' Liner top packer at 7400' Perforation Summary Top of liner at 7420' Ref log: DIL / GR 03/03/90 End of tubing at 7460' 8000'- 3- 3/16" uncemented liner A Size SPF Interval (TVD) 2 - 7/8" slotted liner 4.5 5 7,555'- 7,209' - 5 7,614' 7,080' 4.5 5 7,654'- 7,112' - 5 7,680' 7,134' AL1 4.5 7,686'- 7,139'- " 7,714' 7,162' AL2 4.5 7,730'- 7,175'- A lateral - 7,560' - 9430' 7,738' 7,181' AL1 lateral - 8220' - 9430' AL2 lateral - 8100' - 9430' 7" float collar 7 808' and 7" 26 #/ft float shoe 7 901' and DATE REV. BY COMMENTS MILNE POINT U NIT 11 /16/90 JBF Drilled and Completed by Nabors 27E WELL L -2 05/28/96 MDO Recompleted by Nabors 4 ES API NO : 50 -029 -21998 05/30/01 BMH RWO by Nabors 4 ES 02/28/06 MDO ESP RWO Nabors 3 -S BP EXPLORATION (AK) nc oraae 1. Operations Performed: -º.hange Out ~§~-=-_____ o Abandon o Suspend o Operation Shutdown o Perforate 1m Other , o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 1m Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 190-006 r 1m Development o Exploratory 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21988-00-00 ,; 7. KB Elevation (ft): 56 r 9. Well Name and Number: MPL-02 8. Property Designation: ~ 10. Field / Pool(s): , ADL 025509 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary I Total depth: measured 7936 feet true vertical 7346 I feet Plugs (measured) None Effective depth: measured 7808 feet Junk (measured) None true vertical 7240 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 13-3/8" 82' 82' 1740 750 Surface 5076' 9-5/8" 5076' 4950' 3520 2020 Intermediate Production 7901' 7" 7901' 7317' 7240 5410 Liner , ,;4, f ";!,cUi,": ¡- t\)\- Perforation Depth MD (ft): 7555' - 7738' Perforation Depth TVD (ft): 7030' - 7182' 2-7/8", 6.5# L-80 7473' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily AveraQe Production or Injection Data ~ Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: 0 0 0 260 Subsequent to operation: 145 46 830 400 342 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 1m Daily Report of Well Operations o Exploratory 1m Development o Service 1m Well Schematic Diagram 16. Well Status after proposed work: 1m Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to the best Of my Knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 Printed Name Sondra Stewman Title Technical Assistant Phone Prepared By Name/Number: Signature 564-4750 Date Sondra Stewman, 564-4750 .. STATE OF ALASKA I ALAS~IL AND GAS CONSERVATION C MISSION MAR 2 4 ¡U06 REPORT OF SUNDRY WELL OPERATIQfki~I&GasCons.C(}ffimiSSiOn A h RECEIVED Form 10-404 Revised 04/2004 4 I~L ~ f I')~ Submit Origi'Jil Only R8DMS BFL MAR 2 8 Z006 ") ~"'~¡-~ A 'f'¡'Ob Tree: 2 9/16" 5M Wellhead: 135/8" x 1 ~ CIW 'OGB' tbg spool wI 11" x 27/8" CIW Tubing Hanger, 2 7/8" EUE 8 rd threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 48#/ft , H-40 Weld Set. 1 'I +-801 KOP @ 3,200' Max. hole angle =33.58' deg. fl 7700' to TO' Hole angle thru' perfs = 33 ego 95/8", Btre. I 5,076' 7" 26 #/ft, L-80, Btre. production casing ( drift 10 = 6.182", cap. = 0.0383 bpf ) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift 10 = 2.347", cap. = 0.00592 bpf) Stimulation Summary 11/11/90 -185.3 M Ibs. 16/20 Carbolite Perforation Summary Ref log: DIL I GR 03/03/90 Size InleNal (TVD) 4.5 5 7,555'· 7,209'- 5 7,614' 7,080' 4.5 5 7,654'- 7,112'- 5 7,680' 7,134' 4.5 7,686'· 7,139'- 7,714' 7,162' 4.5 7,730'- 7,175'- 7,738' 7,181' MPU L - 02 ~ .KB Elev. = 56.0' (N 27E) GL Elev. = 21' Cameo 2-7/8" xi" side pocket KBMM GLM 168' Cameo 2-7/8" x 1" sidepoeket KBMM GLM I 7,253' I 7" RA TAG @ 7,288' 27/8" "XN" Nipple 7,392' Centrilift pump 151 Stage I 7,406' I GC1700/19GC8200 GPMTAR 1:1 Tandem Gas Separator I 7,431 ' I GRSFTXARH6 (400 Internal) Tandem Seal Section I I GSB3 DB UTABHSNPFSA 7,436 GSB3DBLTABHSNFSAeL5 Centrilift 209 HP KMH I 7,450' I 2385 volt I 53 amp Pumpmate w/6 fin Centralizer I 7,470' I 7" 26 #/ft float shoe 04 I 28 I 84 05 I 28 1 96 05/30/01 02/28/06 JBF MOO BMH MOO COMMENTS Orilled and Completed by Nabors 27E Reeompleted by Nabors 4 ES RWO by Nabors 4 ES ESP RWO Nabors 3-S MILNE POINT UNIT WELL L-2 API NO: 50-029-21998 BP EXPLORATION (AK) e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-02 MPL-02 WORKOVER Start: 2/25/2006 Rig Release: Rig Number: Spud Date: 2/21/1990 End: 3/1/2006 2/25/2006 17:00 - 21 :30 4.50 MOB P PRE Spot Rig over well, move other Rig Components inlo position and connect 10 Rig Sub. Raise and Scope Derrick. H/U hardline 10 Tiger Tank and pressure test. Rig accepl @ 1700 hrs. 21 :30 - 23:00 1.50 WHSUR P DECOMP Held PJSM. Bleed OA pressure from 500 psi 10 110 psi. P/U Lubricator, pull BPV, UD same. T/I/O = 250/250/0. 23:00 - 00:00 1.00 WHSUR N DECOMP Fuel contaminated with high water cut. Wail on Deisel 911. 2/26/2006 00:00 - 03:00 3.00 WHSUR N WAIT DECOMP Fuel contaminated with high water cut. Wait on Deisel 911. 03:00 - 04:30 1.50 WHSUR P DECOMP PJSM. Line up & pump 45 Bbls. down tubing wI heated seawater, laking returns up IIA, thru choke 10 tiger tank. Close choke and bullhead 50 Bbls heated seawater. Open choke and pump 90 Bbls down tubing wI heated seawater, laking returns up lA, to liger tank. 04:30 - 06:00 1.50 WHSUR N SFAL DECOMP SSV shut. Waiting on new shear disc. 06:00 - 07:00 1.00 WHSUR P DECOMP Well lech repair SSV, hold PJSM wilh LRS and crew. Hook control line into SSV from LRS truck. Discuss kill procedure. Discuss rig up and the effect of thermal expansion of fluid packed, closed systems. Discuss having gauges to monitor pressures. WHP's: IA - 320 psi, OA - 220 psi, 0 psi on tbg. 07:00 - 09:30 2.50 WHSUR P DECOMP Pump 50 bbls 135 degree seawater, bull heading down tubing, open choke to tiger tank, returns gas. At 70 bbls away, fluid with gas to surface. Circulate and kill well at 5 bpm, 1100 psi - tbg, maintaining maximum 150 psi downslream of choke wilh 280 psi on IA. Circulate to clean fluid. Shul down and observe for 30 minules. Well dead wilh 0 psi on Ibg an annulus, and on vacuum. Total pumped 475 bbls (includes volume pumped prior to shearing disc in SSV), 185 bbls returns, crude and seawater. 09:30 - 10:30 1.00 WHSUR P DECOMP Install TWC, pressure test to 3500 psi. Test hanger packoff to 5000 psi. ok. 10:30 - 23:00 12.50 WHSUR P DECOMP PJSM. Remove tree, inspect and clean, service lock down screws and spool etc. Screw 2 7/8" EUE pup joint into hanger (10 turns). Nipple up BOPE. Notify John Crisp with AOGCC of impending BOP test. 23:00 - 00:00 1.00 BOPSU P DECOMP BOPE test to 250 psi low and 3,500 psi high. Tests witnessed by N. Frazier I R. Bjorhus I R. Miller/John Crisp wI AOGCC. 2/27/2006 00:00 - 04:00 4.00 BOPSU P DECOMP BOPE test to 250 psi low and 3,500 psi high. Tests wilnessed by N. Frazier I R. Bjorhus I R. Miller/John Crisp wI AOGCC. 04:00 - 06:00 2.00 BOPSU P DECOMP PUMU lubricator. Pull TWC. SITP = O. SICP=O. UD lubricator. PUMU landing jt. Screw into tubing hanger. BOLDS. Unland Tubing Hanger. P/U wt. to unland Hanger = 55K. P/U wt. after Hanger free = 45K. Loaded hole with 50 bbls seawater prior to UD Tubing Hanger (no returns). Pit volume after fill - 200 bbls. Pull and UD landing jt. and Tubing Hanger. Cameron to redress Tubing Hanger. 06:00 - 19:30 13.50 PULL P DECOMP PJSM. POH with 2 7/8" tubing, standing back in derrick. Load hole with 10 bbls after first 10 joints, then double pipe displacement every 10 joints thereafter. 19:30 - 22:00 2.50 PULL P DECOMP Break out, Service and UD ESP components. Pump was locked up and motor was burned out. RID Elephant Trunk. Add 50-Bbls of seawater. 22:00 - 00:00 2.00 RUNCO RUNCMP P/U, Service, and M/U new ESP completion assembly. 2/28/2006 00:00 - 06:00 6.00 RUNCO RUNCMP RIH wI new Centrilift ESP completion using Best-O-Life Pipe Printed: 3/6/2006 12:51 :24 PM e e .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-02 MPL -02 WORKOVER Start: 2/25/2006 Rig Release: Rig Number: Spud Date: 2/21/1990 End: 3/1/2006 06:00 - 08:00 Dope and Optimum Torque of 2,300 ft-Ibs on all connections. Test electrical integrity of ESP cable and downhole ESP unit each 2000' ran in hole. Every 2000 ft. pump 10 bbls through ESP per program. RUNCMP 65 Slands in hole, ESP @ 4505'. Centrilift test electrical integrity of ESP cable and downhole unit. BOP drill wilh rig crew, changeout and continue RIH wI ESP assembly. RUNCMP 100 Stands in the hole, load drill pipe and with 10 bbls of brine, calch fluid at 8 bbls. pump 2 bbls through pump at 1.5 bpm, 300 psi. Shut down, DP on vacuum. Continue to RIH with 2 7/8" tubing. PUMU 5 joints new tubing to replace bad joints. Make up top GLM with DSOV installed. RIH with 4 joints and pup joints (below hanger). Load DP wilh 15 bbls of brine and flush ESP. 1.5 bpm, 950 psi. Catch fluid at 12 bbls, well on vacuum. PU/MU tbg hanger and penetrator. Make lower wellhead ESP cable connector splice. Centrilift check conductivity. Good test. Load well with 35 bbls seawater. Land tubing, RILDS, install TWC and lest to 2500 psi. Test O.K. PJSM N/D BOPE. N/U tubing head adapter and production tree. Final downhole ESP eletrical checks performed. Good tesl results. (phase to phase - 3.2 balanced, phase to ground - infinity, 500 megs in 1 minule) SBHP measured from downhole ESP pressure gauge = 2251 psi. Conlinue N/U tubing head adapler and production tree. PIT tubing head adapter and tree to 5000 psi. Good test. P/U lubricator. Pull TWC. Set BPV. UD lubricator. Secure well. Secure cellar. Release rig at 03:00 hrs. PJSM. RDMO well. Prepare to move to GPB C-21. Move rig and componenets off of pad. Had to wait on Peak Trucks (they were moving 27E), and weather to lower derrick ambient of -42 below. Rig down, lower derrick, move rig and eomponenls 10 GPB C-21 08:00 - 11 :00 11 :00 - 13:00 2.00 RUNCMP 13:00 - 14:00 1.00 RUNCMP 14:00 - 20:00 6.00 BOPSU P RUNCMP 20:00 - 22:30 2.50 WHSUR P RUNCMP 22:30 - 00:00 1.50 WHSUR P RUNCMP 3/1/2006 00:00 - 02:30 2.50 WHSUR P RUNCMP 02:30 - 06:00 3.50 RIGD P PRE 06:00 - 12:00 6.00 RIGD P PRE 12:00 - 00:00 12.00 RIGD P PRE Printed: 3/6/2006 12:51 :24 PM STATE OF ALASKA .... ALASKA L.,,L AND GAS CONSERVATION COMMI,_ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56' [] 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 3207' NSL, 5056' WEL, Sec. 8, T13N, R10E, UM MPL-02 At top of productive interval 9. Permit Number / Approval No. 190-006 3951' NSL, 1566' WEL, Sec. 8, T13N, R10E, UM 10. APl Number At effective depth 50-029-2-t-988-00 ~ 3999' NSL, 1699' WEL, Sec. 8, T13N, R10E, UM 11. Field and Pool At total depth Kuparuk River Field 4017' NSL, 1748' WEL, Sec. 8, T13N, R10E, UM 12. Present well condition summary Total depth: measured 7901' feet Plugs (measured) true vertical 7317' feet Effective depth: measured 7808' feet Junk (measured) true vertical 7240' feet Casing Length Size Cemented MD TVD Structural Conductor 82' 13 3/8" 260 sx Arctic Set (Approx.) 115' 115' Surface 5043' 9 5/8" 565 sx Class 'G' 5076' 4950' Intermediate Production 7868' 7" 1045 sx Perf 'E' 7901' 7316' Liner Perforation depth: measured 7555'-7614', 7654'-7680', 7686'-7714', 7730'-7738'RECEIVED true vertical 7030'-7079', 7112'-7133', 7138'-7162', 7175'-7182' JUN ?- 0 ?_001 Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 7458' Alaska Oil & Gas Co~s. Commission Anchorage Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze eummary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregping is true and correct to the best of my knowledge Signed son~ : Title Technical Assistant Date .~)i,.O' Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 flP IGINAL Submit In Duplicate,,, , Legal Well Name: MPL-02 Common Well Name: MPL-02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 5/29/2001 End: Contractor Name: NABORS Rig Release: 513112001 Rig Name: NABORS 4ES Rig Number: ;::::.i:.::iFro~.':.:To: :;::ii.:.Ho~:rs: Activi~ Code: NP¥ ::.: 'phase Description of Operations .... 5/29/2001 09:00 - 18:00 9.00 RIGU PRE MI/RU & SAFE OUT EQUIPMENT.ACCEPT RIG @ 1800 HRS. 512912001 18:00 - 19:30 1.50 WHSUR DECOMP RIG TIGER TANK & LINES TO SAME & TEST EQUIMENT. 19:30-21:30 2.00 WHSUR DECOMP PULL BPV & FILL PITS WIT 8.5 PPG. FLUID TEST LINES TO 3500 PSI. 650 PSI.. ANNULUS & 150 PSI. TBG. 21:30 - 23:30 2.00 KILL DECOMP ClRC WELL BORE WITH 8.5 PPG. SEA WATER. 23:30 - 00:00 0.50 WHSUR DECOMP SET TWC & NIPPLE DOWN TREE. 5/30/2001 00:00 - 01:00 1.00 WHSUR DECOMP NIPPLE DN TREE 01:00 - 02:30 1.50 BOPSUF DECOMP NIPPLE UP BOP 02:30 - 03:30 1.00 BOPSUF DECOMP TEST BOP TO 3500 PSI.TEST WAIVED BY JEFF JONES WITH AOGC 03:30 - 06:00 2.50 BOPSUF DECOMP PULL TWO & PULL HANGER TO FLOOR & LAY DN SAME. 06:00 - 13:30 7.50 PULL DECOMP POOH WITH TBG. STD. BACK 45-STDS IN DERRICK AND TBG. WAS OVERTORQUED AND FOUND TO NOT PASS DRIFT AND CONNECTIONS WERE GALLED WHILE BREAKING OUT BEGIN LAYING REMAINDER OF 2-7/8" DOWN & LAY DN ESP. 13:30 - 23:30 10.00 EVAL COMP RIG SWS & LUBRICATOR & RUN RST LOG & LOG WELL BORE FROM 7742' TO 7500' DUE TO FILL FIRST READING OBTAINED WAS @ 7732' & RIG DOWN SWS. 23:30 - 00:00 0.50 PULL DECOMP RUN TBG. IN HOLE TO LAY DN. 5/31/2001 00:00 - 04:30 4.501 PULL DECOMP RUN 45-STDS TBG. IN HOLE & POOH LAYING DN SAME. 04:30 - 16:30 12.00 RUNCOk COMP MU ESP & CHECK OUT & RIH ON 2-7/8" TBG/& INSTALL HANGER & LAND & RILDS. 16:30 - 19:00 2.50 BOPSUF COMP SET TWC & TEST & NIPPLE DOWN BOP. 19:00 - 21:30 2.50 WHSUR COMP INSTALL TREE & TEST SAME TO 5000 PSI. & PULL TWC & INSTALL BPV. 21:30 - 00:00 2.50 RUNCOI~! COMP FREEZE PROTECT WELL WITH HB&R USING DEAD CRUDE & INSPECT TREE AREAS. Printed: 6/4/2001 1:28:19 PM MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julia Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: December 22, 2000 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne Point Field L Pad December 22~ 2000: I traveled to BPX's Milne Point Field L Pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arrived on location. Wellhouses on L Pad are heated & have lights, this makes for safe working conditions & minimal SVS failures. Wellhouses are clean & in good condition. The AOGCC test report is attached for SVS failure reference. SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. 1 Failure witnessed. 2.5% failure rate. 20 wellhouses inspected. No failures to report. Attachments: SVS MPU L pad 12-22-00jc ,cc; .N .O..N-CONFIDENTIAL SVS MPU L Pad 12-22-OOjc.doc Alaska Oil and GaS Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU MPU L Pad Separator psi: LPS 140 Date: 12/22/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE L-01 1840050! L-02 1900060 140 100 90 P P OIL L-03 1900070 L-04 1900380 140 100 105 P P OIL L-05 1900390 140: 100 100! P P OIL L-06 1900100 140 100 1001 P P OIL L-07 1900370 140 100 100l P P ~)IL L-08 1901000 4000 2000 1950 P P WAG- L-09 1901010 L-Il 1930130 140 100 115 P P OIL ,, L-12 I 1930110 140 100 100 P P OIL L-13 1930120 140 100 100 P P OIL , L-14 1940680 140 100 95 P P OIL L-15 1940620 L-16A 1990900 L'17 1941690 L-20 1971360. 140 100 100 P P · " ~)IL L-25 1951800 140! 100 105 P P OIL L-28A 1982470 1~0! 100 ' 110 P P OIL ,, L-29 1950090 1401 100 95 P P OIL L-32 1970650 140' 100 100 P P OIL L~33 1971050 L-35 1970920 140 100 105 P P OIL L-36 1971480 1401 100 105 P P OIL L-37A 1980560 L-40 1980100 140 100 100 P P gff,~bM:~¥.~ OIL , L-45 1981690 140 100 105 P P [xS' OIL , L-34 1970800 4000 2000 1900 P 4 WAG ,! Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% [290 Remarks: 12/26/00 Page 1 of 2 SVS MPU L Pad 12-22-OOjc.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Replacement 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3207' NSL, 5056' WEL, Sec. 8, T13N, R10E, UM At top of productive interval 3951' NSL, 1566' WEL, Sec. 8, T13N, R10E, UM At effective depth 3999' NSL, 1699' WEL, Sec. 8, T13N, R10E, UM At total depth 4017' NSL, 1748' WEL, Sec. 8, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-02 9. Permit Number / Approval No. 90-6 10. APl Number 50-029-L;Z.l.888 11. Field and Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 7901' feet true vertical 7317' feet Effective depth: measured 7808' feet true vertical 7240' feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size Cemented 82' 13 3/8" To surface 5043' 9 5/8" 565 sx Class 'G' 7868' 7" 1045 sx Perf 'E' MD TVD 115' 115' 5076' 4950' 7901' 7316' Perforation depth: measured true vertical 7555'-7614',7654'-7680',7686'-7714',7730'-7738' 7030'-7079',7112'-7133',7138'-7162',7175'-7182' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 7448' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure APR i $ i998 0~1 & Gas ~s. ~mmi~io~ ~o~qe 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord ..... ~~,,,,,,,~L Title Engineering Supervisor Date Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplica~' SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPL-2 Rig Name: N-4ES AFE# 339012 Accept Date: 05/27/96 Spud Date: . Release Date: 05/29/96 MAY 27, 1996 ACCEPT RIG @ 0400 HRS. RIG UP LEVEL, BERM, SAFE OUT EQUIPMENT. TAKE ON BRINE & RIG HARD LINES TO TREE. MAY 28, 1996 CONT TAKING ON SOURCE H20 & TEST LINES TO 2000 PSI. SPOT 25 BBL PILL DOWN TUBING & DISPLACE WELL BORE W/8.4 PPG. SOURCE H20 & MON WELL & INSTALL BPV. ND TREE & NU BOP'S & PULL BPV TEST BOP'S TO 250 LOW & 5000 HIGH (TEST NOT WITNESSED BY AOGCC - DID NOT RETURN CALL). PULL TWC & MU LANDING JT & BOLDS. PULL PACKER FREE & POOH W/ESP COMP. LD ALL PROD EQUIP IN STRING & ESP POWER CABLE BLOWN 1s~ JT ABOVE PUMP & POT HEAD BLOWN BANDS REC 539 + 9 FLAT GUARDS LOST IN HOLE 2 SLIP SEGMENTS FROM OTIS PACKER. RIG CAMCO & RIH W/6" GR/JB ON SLICK LINE FOR PBTD DEPTH. MAY 29, 1996 CONT TO RIH 6" GR/JB TO 7705', POOH, RIH W/5 Y:~" MAGNET ON WIRE LINE TO 7765' (4ES KB). POOH & REC SLIPS FROM PACKER RD CAMCO RIG UP TO RUN ESP, MU SAME, SERVICE, MAKE SPLICE ON MTR LED. CONT TO RIH ESP COMP MU SPLICE IN CABLE & HANGER LD TUBING RILDS BK OUT LD JT & LD SAME. ND RISER & BOP'S NU TREE, TEST HANGER, TREE TO 5000 PSI PULL TWC FREEZE PROTECT WELL W/OIL & DIESEL MIXTURE. SET BPV & SECURE WELL. RIG RELEASED @ 0600 HRS. Page 1 of 1 Alaska Oil Gas Conscrcation Commission 300i Porcupine DriYe Anchorage, Alaska 99501-3192 g07-2?g-1 433 Permit The following data is hereby acknowledged as being received: RECEIVED Dated: JAN I 9 1993 ~ A/aska Oil & Gas Cons. CommissiOI1 Anchorage _ onoco Inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchoracje, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed ..~cord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 December 22, 1992 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Miine Point Well Log Magnetic Tapes L-6, L-5, and L-2. Quantity Contents 1 each L-6 Magnetic Tape. GCT Directional Survey (LIS Format), APl #50-029-22003, Log Date: 03-May-90, Ref #73866. ~aagnetic Tape. GCT Directional Survey (LIS Format), APl #50-029-22030~'Log Date: 02-May-90, Ref #73865. L-2 Magnetic Tape. GCT Directional Survey (LIS Format), APl #50-029-21998, Log Date: 08-Nov-90, Ref #74189. Signed By C_:'~-~,~. ' Transmittal Approved By C_~;7.~- Date '-December 22, 1992 Instructions= .ease acknowledge r~-~-e-ip~pro~b'~ signing and returning second copy. R E C E IV E D ,,m~r~, DEC 2 2 1992 Transmittal Copy Only To Alaska 0il ~ Gas Cons. Commission Anchorage ~--'" STATE OF ALASKA AL, .... ,,A OIL AND GAS CONSERVATION COMMt, 3N REPORT OF SUNDRY WELL OPERATIONS ,. 1, Operations performed: Ooerat~on snu~own __ Pull tubing __ Alter casing __ ReDa~r well __ 2 .."4~~(~e,~:)~. / 5. Type of Well: · Development __X I Exploratory ~ 1 Stratigraphlc __ .3 Ad~r~s. Box 340045, Prudhoe Bay, AK 99 4 Serv,ce__ Stimulate __ Plugging __ Pedorate __ __RED1_ ace ESP Other 4 Location of welt at surface 2072' FNL, 222' FEL, SEC 8, T13N, RtOE, UH At top of productrve ~nterval 1350' FNL, 1550' FEL, SEC 7, T13N, RIOE, UN 6. Datum elevabon (DF or KB) 56' KB feet 7. Unit or Property name llilne Point Unit 8. Well number L-2 9. Permit number/approval number 90-6 At effectwe depth At total depth 1277" FNL, 1728' FEL, SEC 7, T13N, RIOE, UN 12. Present well condition summary Total depth~ measured true vertical Effective aepm: measured true vertical 7936 ' feet Plugs (measured) 7335' feet 7808' feet Junk (measured) 7244' feet 10. APl number 5o- 029-21998 11. Field/Pool Kuparuk River Field N/A N/A Casing Length Structural - Conductor 80 ' Surface - Intermea,ate 5041' Production 7866 ' Liner Perfora[~on depth: Size Cemented Measured depth . . 13-3/8" Surface 115' . . -- 9-5/8" 301BBLS Class 'E' 5076' 7" 112 BBLS Class 'G' 7901' 54 BBLS Class 'G' measured 7555' -7738' truevertical 7029' - 7181' Tubing(slze, graae, and measured aeptn) 2-7/8", EUE, 6.5#/FT, L-80, 8RD e7443' True vertical depth . 115' 4949' 7321' RECEIVED DEC 1 4 1992 Alaska Uil & Gas Cons. 60mm Anchorage ~ Fackers and SSSV (type and measured depth) Oti s 7" F~X.~ TRSV (lil510' ) ,..j. Stimulabon or cement squeeze summary NONE 26-32#/FT 'RDH' PACKER (@ 533' ), OTIS 2-7/8" SERIES Intervals treated (measured) - Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniect~on Data Oil-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations !6 Status of well classification as: Oil X_ Gas_ Suspended __ Service 17. I hereby certify that the foreg(3ng is true and correct to the best of my knowledge. .o,m 0-,;04kev 8 5/88 Date SUBMIT IN DUPLICATE ss),0r~ 10 CONOCO INC. I WELI~ I'V~ 0 ACTIVITY AT REPORT TIME: aAILY WELL ACTIVITY REPOR'i ~"~"~ J~L.., ~ ~,~'~ ALASKA RIG: 6~S- ~ ~ ~THER:~ ~ ~ TEMP~C:~ /~ F ~L~ ~-- t ~ CURRENT DEPTH: 78 [ MO ACTIVITY SERWCE PERSONNEL- NO. ~ 5-- ~H ~ ~ ~~ -- ~ ~ ~~ ~ ~~- ,,~ s.~,~,~o.~.c~ ~~ costs ,,~s -- . i! , ,, scssv DAYS WITHOUT ~ ~t~ b~ ~%~ $ ~%, ¢~ PLUGDESC. Y~RTODATE! ~ J~ ~0~0~L~¢$ ~. ~O COST SUMMARY DAILY ENVIRONMENT~INCIDENTS ~%~(~~ $ [ Ot"O~ PR~IOUSTOTAL $ DAYS WITHOUT ~ ~~~~[~$ q~ P~NNED $ ~,,~ Y~R TO DATE ~ ~~ ~ ~ O ~ $ ~1 ~ ~ TROUBLE $ BOPE TEST DUE -- ~E~L~~ $ ~ ~ AFECOST $ AOGCC VIS~? ~0 ~0~ $ %~,3~% EST. FIN~COST $ ENGINEER ~t~ ~~~ ISUPERVISOR ~% ,, ,,, ! ¢/aska Oil & Gas Cons. Col missi( TO: MEMORANuUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Sm~~ DATE: JUly 2, 1991 Commissioner ~ FILE NO: LG7291 THRU: TELEPHONE NO: SUBJECT: RIG/BOPE Inspection Conoco L- 2 Milne Pt. Unit Workover qO-~)~ FROM: Louis R. Grimaldi~<J Petroleum Inspector June~26. 199~: I performed a RIG/BOPE inspection on EWS rig #4 working over L-2 in the Conoco Milne Pt Unit. All previous violations have been corrected and I was quite impressed with the repairs to the mud--gas separation system. I found no non-compliances and made a very thorough inspection. I feel that EWS has made an honest effort to conform to the Alaska State regulations and API RP 53. Because there is so much new equipment on the rig and more difficult moves resulting from this, I feel continued inspections are warranted to ensure proper maintenance and upkeep. It shoUld be noted that it was passed onto me to thank the Commission for their assistance in making the rig a much safer work atmosphere. In summary: compliances. The RIG/BOPE inspection revealed no non- Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERATION: Drlg Wkvr ~ UIC Operator C~2/~¢~(~ ~ Permit # ~) Location: Sec_ ~ T /~ R /~ M Drlg contr ~ ~ ~ Rig~ Location (gen'l) ~0~ Well sign IN COMPLIANCE; yes n~ n/a A. DIVERTER 1. ( ) ( ) ) line sz & length 2. ( ) ( ) ( ) line conn& anchored 3. ( ) ( ) ( ) bifurcated & dwn wind 4. ( ) ( ) ( ) 90° targeted turns 5. ( ) ( ) ( ) vlvs: auto & simultaneous 6. ( ) ( ) ( ) annular pack-off 7. ( ) ( ) ) condition B. BOP STACK 8. (~ ( ) ( ) wellhead flg wkg press 9. (~ ( ) ( ) stack wkg press 10. ~ ( ) ( ) annular preventer 11. (~) ( ) ( ) pipe rams 12. ~')~ ( ) ( ) blind rams 13. (~ ( ) ( ) stack anchored STATE OF ALASKA ..,ASKA OIL AND GAS CONSERVATION COMMISSI~. BOPE Walk-Thru Inspection Report DATE: Wel 1 name /~ - c~ Representative Fy_) ~/~j I~ ~'I~CHS~_.' , I N COMPL I ANCE; ~/.~_~,, no n/a 33. ~--~[]~' (--[ ( ) firewall 34. (~,;?(())(()) nitrogen power source (back-up) 35. condition (leaks, hoses, etc) (~'~, D. MUD SYSTEM 36. ( )- ( ) pit level floats installed 37. (~ ( ) ( ) flow rate sensors 38. ~)~ ( ) '( ) mud gas separator 39. ~ ( ) ( ) degasser 40. ~7/~ ( ) ( ) separator bypass 41.(~ ( ) ( ) gas sensor 42. ~)~ ( ) ( ) chke I n conn 43.(~ ( ) ( ) trip tank E. RIG FLOOR (~;lly cocks (upper,lower,IBOP) qs. (~ ( ) 14. (~... ( ) ( ) chke/kill line sz ( ) floor vlvs (dart vlv, ball vlv) 15. (~) ( ) { ) 90° turns targeted {chke & kill ln) 46. (~× ( ) ( ) kelly & floor vlv wrenches 16. (//i¢. ( ) ( ) HCR vlvs (chke & kill) 47.(/~/ ( ) ( ) driller's console (flow monitor, 17. (~'? { } ( ) manual vlvs {chke & kill) flow rate indicator, pit level 18. ~?!/' ( ) ( ) connections (flgd, whd, clmpd) 19.(~ ( ) ( ) drl spool 20. (,Y).,. ( ) ( ) flow nipple 21. (~[' ( ) ( ) flow monitor 22. (~)' ( ) ' ( ) control lines fire protected C. CLOSING UNITS 23. ~ ( } ( ) wkg press 24. ~- ( ) ( ) fluid level 25. ~ ( ) ( ) oprtg press 26. (~' ( ) ( ) press gauges 27. (~ ( )' ( ) sufficient vlvs 28. ({z)" ( ) ( ) regulator bypass 29. (~/)[. ( ) ( ) 4-way vlvs (actuators) · ( ) ( ) blind handle cover 31. ~)// ( ) ( ) driller control panel 32 (~ ( ) ( ) remote control panel indicators, gauges) 48. (~/, ( ) ( ) kill sheet up-to-date 49. (~" ( ) ( ) gas ~etection monitors (H S & methane) 50. ( ) ~ ( ) ~,~ hydr chke panel 51. (Z~ ( ) ( ) chke manifold F. MISC EQUIPMENT 52. I~ ()( ) flare/vent 1.ine 53. ( ) ( ) 90° turns targeted .~ (dwn strm choke lns) 54. I~/~ ( ) (~reserve pit tankage 55. ( ) ( ) personnel protective equip avail 56. xJ~)~ ( ) ( ) all drl site suprvs trained ~ for procedures 57. p, ( ) (~'/H2S probes 58. ( ) ( ) rig housekeeping REMARKS: RECORDS: Date of last BOP inspection: Date of last. BOP test: Resulting non-compliance: ./L~ 0,"-~.'.~" 2:~F'" ,~r'?~,~"~/,..~'~',~ ~.~yf~O¢ Non-compliances not corrected & why: Date corrections will be completed: BOP test & results properly entered on daily record? Kill sheet current? C.0013 (rev 04/29/91 ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLTCATTON FOR SUNDRY APPROVALS U lf I IL 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well ~ Plugging __ Time extention ~ Stimulate Change approved program Pull tubing Vadance Perforate Other X Name of Operator 5. Type of Well: 6. Conoco Inc. Development X Address Exploratory 7. 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Location of well at surface 8. 2072' FNL, 222' FWL, Sec. 8, T13N, R10E, U.M. At top of productive interval 9. 1328' FNL, 1569' FEL, Sec. 7, T13N, R10E, U.M. At effective depth 1289' FNL, 1674' FEL, Sec. 7, T13N, R10E, U.M. At total depth 1255' FNL, 1769' FEL, Sec. 7, T13N, R10E, U.M. Replace ESP Datum elevation (DF or KB) 56' KDB Unit or Property name Milne Point Unit Well number L-2 feet 12. Present well condition summary Total depth: measured true vertical 7936' feet Plugs (measured) 7346' feet Effective depth: measured true vertical 7757' feet Junk (measured) 719 7' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 82' 5043' 7868' measured Size Cemented Measured depth 13-3/8" To Surface 115' 9-5/8" 565 sx Class G 5076' 1045 sx Permf E 7" 251 sx Class G 7901' 7555-7614'; 7654-7680'; 7686-7714'; 7730-7738' true vertical 7030-7079'; 7112-7133'; 7138-7162'; 7175-7182' Tubing (size, grade, and measured depth) 2-7/8", L-80, 7482' Packers and SSSV (type and measured depth) Permit number 10. APl number 50- 029-21988 11. Field/Pool Kuparuk River Field True vertical depth 115' 495O' 7316' Otis FMX SCSSV @ 510'; RECEIVED 13. Attachments r, AAY 2 0 t99 Alaska 0/1 & Gas Cons. Commission Otis RDH Pkr. 533' Anchorage Description summary of proposal X Detailed operations program __ BOP sketch 15. Status of well classification as: Gas __ Suspended Date May 13, 1991 FOR COMMISSION USE ONLY 14. Estimated date for commencing operation June 15, 1991 16. If proposal was verbally approved Oil X Name of approver, Date approved Service 17. I hereby frtify t~'lf,/the foregoing is true and correct to the best of mY knowledge. Si~ned \_//~ [-'~/ J.H. Andrew Title Production Engineer Conditions of approval: Notify Commission so representative may witness JApproval Noc~/ Plug integrity BOP Test Location clearance - Mechanical Integrity Test Su----bsequent form required 10---~ !%eturned,.,~.. ~ / ORIGINAL S!GNED BY Approved by order of the Commission LONNIE C. SMITH commissioner--'"--- Date ---~'-"'(:~/- ~"/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point Unit L-2 Well ESP Replacement Procedure Summary le · · · · · · · · 10. 11. 12. 13. 14. MIRU workover rig. Kill well by circulating hole full with 10.0 ppg NaBr/NaCl brine. Spot salt-based LCM pills, if necessary, to control fluid losses. ND tree. NU and test BOP's. Shear open annular vent valve by pressuring up on the 2-7/8" tubing x 7" casing annulus to 3500 psig with the valve closed. MU landing joint to tubing hanger. PU 20,000# above pipe weight to release Otis RDH retrievable packer at 533'. POOH and LD 2-7/8" production tubing and ESP. PU workstring. TIH with sand bailer. Tag proppant and bail to clear perf interval and rathole. POOH and LD workstring. MU new ESP assembly and TIH on 2-7/8" production tubing. MU an Otis RDH packer with annular vent valve. Install a 2- 7/8" tubing retrievable SCSSV in the production string above the packer and space out to place SCSSV at least 500' below ground level. Land production tubing hanger and freeze protect annulus. RU wireline and set a plug in an otis X nipple located below the production packer. Pressure up against the plug to set the packer. POOH with plug and RD wireline. Pressure test packer and annular vent valve by pressuring up on annulus to 500 psig. Freeze protect tubing. ND BOP's, NU and test tree. RDMO workover rig. RU and test flowline. Return well to production. t ECEIVF. Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA AL~,`SKA OIL AND GAS CONSERVATION COMM,,,,sION REPORT OF SUNDRY WELL OPERATIONS Stimulate __ Plugging __ Repair well __ I 5. Type of Well: Development Exploratory Stratigraphic 9973 Service 1. Operations performed: Pull tubing __ Alter casinc~ __ 2. Name of Operator CONOCO ZNC feet AK Operation shutdown __ 3. Address Box 340045 Prudhoe Bay, 4. L~ationofwellatsudace 2072'FNL 222'FEL, Sec. 8, ~topo~roductiveinterval 1350'FNL 1550'FEL,Sec. 7, At effective depth T13N,R10E,U.M., NSB T13N,R10E,U.M., NSB Attotaldepth 1277'FNL,1728'FEL, Sec. 7, ~13N,R10E, U.M. 12. Present well condition summary Total depth: measured 7936 true vertical 7335 feet Plugs (measured) feet Perforate __ Other~' 6. Datum elevation (DF or KB) 56'KB MSL 7. Unit or Property name Milne Point Unit 8. Well number L-2 9. Permit number/approval number 90-6 10. APl number 50-- 029-21998 11. Field/P0ol Kuparuk River Field Effective depth: measured 7808 feet Junk (measured) true vertical 7244 feet Casing Length Size Cemented Measured depth Structural Conductor 80' 13-3/8" ~o Surface 115' True vertical depth 115' Surface Intermediate 5041' 9-5/8" 301 bbls Class E 5076' Production 7866' 7" 132 bbls Class G 4949' Liner Perforation depth: measured 7555'-7614' 7654-7714' 7730'-7738' truevertical 7029 ' -7080 ' 7712 ' -7162 ' 7175 ' -7181 ' Tubing (size, grade, and measured depth) 2- 7/8" 6.5 # L- 80 8RD @ 7525 ' Packers and SSSV (type and measured depth) 8510' OTIS 7" RD]] PKR 8532 ', OTIS2-7/8 "FM~?~r~95~. :~ scssv 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 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 350 Tubing Pressure 0 887 192 1 0 360 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ~ Oil~_..._ Gas __ Suspended __ -17. I heieby certify that the foregoing is true and correct to the best of my knowledge. Service 1'0f-404 ( ' / Form Rev 06/15/88 TitleSenior Production Foreman Dat~/17/91 SUBMIT IN DUPLICATE ~, SUMMARY OF WELL ACTIVITY REPORT CONOCO MILNE POINT UNIT L-2 March 3, 1991 MIRU CTU, vac truck, and hot oil truck. Hold safety meeting. Pressure test lines to 4000 psi. RIH w/1.5" coiled tbg while pumping diesel and reciprocating. RIH to 6900'and displace coil and tbg w/9.6 ppg NaCl. Recovered 35 BBL oil and haul to CFP oil tank. RIH 50' intervals circulating out frac prop at 3900 psi/1.2 BPM while reciprocating. Tag ESP check valve at 7467' CTM. PU 50' and re-tag check valve. Circulate bottoms up 3 times and pump HEC pill. POOH to 2000' and switch pumping to diesel to freeze protect tbg. POOH and RDMO all equipment. Recovered 3-4 BBL frac prop from tbg. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abanaon Suspend m Operation shutdown Re-enter suspended well Alter casing __ Repair well __ Plugging __ Time extention __ Stimulate __ Change approved program __ Pull tubing __ Variance Perforate ~ Other 2. Name of Operator Conoco Inc. 3. Address P.O. BOX 340045 Prudhoe Bay, Alaska 99734 4. Location of well at surface 5. Type of Well: Development __.X Exploratory __ Stratigraphic __ 2072' FNL, 222' FEL, Sec. 8, T13N, RIOE, U.M., NSB R E C E IV E D At top of productive interval 1350' FNL, 1550' FEL, Sec. 7, T13N, RIOE, U.M. At effective depth 2 rD 1'391 At total depth Alaska Oil & Gas Cons, l;omm't$sio~ 1277' FNL, 1728' FEL, Sec. 7, T13N, RIOE, U.M. Anchorage 6. Datum elevation (DF or KB) 56' KB MSL feet 7. Unit or Property name Milne Point Unit 8. Weli number L-2 9. Permit number 10. APl number 50-029-21998 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical 7936 feet Plugs (measured) 7335 feet Effective depth: measured true vertical 7808 feet Junk (measured) 7244 feet Casing Structural Conductor Surface Intermediate Production Perforation Depth: Length Size Cemented Measured depth 80' 13-3/8" TO Surface 115' 5041' 9-'5/8" 301 bbls Class "E" 5076' 7866' 7" 112 bbls Class "G" 54 bbis Class "G" 7901' measured 7555' - 7614',7654' - 7714',7730' - 7738' true vertical 7029' - 7080', 7712' - 7162', 7175 - 7181' True vertical depth 115' 4949' 7321' Tubing (size, grade, and measured depth)2-7/8" 6.5# L-80 8RD @7525' Packers and SSSV (type and measured depth) OTIS 7" RDH PKR @532', OTIS 2-7/8" FMX TRDP SCSSV @ 510' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation March 3, 1991 16. If proposal was verbally approved Mike Minder Name of approver 3-1-91 Date approved 15. Status of well classification as: Oil X Gas Suspended Service Title Senior Production Foreman FOR COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed oate 3/5/91 Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test __ Location clearance Mechanical Integrity Test Subsequent form required 10- ' ~,pproveCt C~oPY . ._.., ~,/'Returned ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Commissioner~Date "~ ~/-- ~ / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE-~j~' SUMMARY L-2 COILED TUBING CLRAN-OUT . . . . ~ 10. SET AND BERM 300 BBL VOLUME TANK. FILL W/lO0 BBLS 9.6 PPG. SET UP F/L CHOKE. SLOP TANK. S/I WELL AND BLOCK IN SCSSV. CAP SSV ACTUATOR W/FUSIBLE CAP. MIRU 1.5" CTU, MANIFOLD, HOT OIL TRUCK W/DIESEL, VAC TRUCK. HOLD PRE-JOB SAFETY MEETING. TEST LINES TO 3500 PSI. HEAT BRINE AND DIESEL TO 85 F. RIH PUMPING DIESEL W/1.5" COIL TO 6900'. CIRCULATE CRUDE OUT OF 2 7/8" TBG TO SLOP TANK TO CLEAN RETURNS. VAC OUT CRUDE AND HAUL TO CFP. REVERSE CIRCULATE W/9.6 BRINE AND RIH TO FILL AT +/- 7000'. REVERSE OUT PROPPANT TO 300 BBL TANK. RIH 50~ INTERVALS AND WORK DOWN TO ESP CHECK VALVE AT 7477J. PU 50~ ABOVE CHECK VALVE AND WAIT. RIH AND REVERSE CIRCULATE BOTTOMS UP X 3. CIRCULATE GELLED PILL ON LAST CIRCULATION. POOH WHILE REVERSE CIRCULATING. STOP AT 2000' AND SWITCH TO DIESEL TO FREEZE PROTECT. RDMO ALL EQUIPMENT. t E'CEiVED Alaska Oil & 6as Cons. Commission Anchorage Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-76(X) January 29, 1991 Mr. Bob Crandall Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Milne Point Unit Well L-2 Drilling and Completion History Dear Mr. Crandall: Enclosed in triplicate are the drilling and completion histories for Milne Point Unit Well No. L-2 which were requested by your office today. They are to be attached to Form 407 - Well Completion, submitted earlier. If you have any questions pertaining to this well please call me at 564-7625. Very truly yours, C. Van Lineberger Sr. Production Engineer cc: CVL, PMS, DEH, Sr. Production Foreman, L-2 Well File ."-' "'-, ORIGINAL ~ , STATE OF' ALASKA ALASKA o'iL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLF. TION REPORT AND LOG Classd~catton of Serwce We~', tatus at Well -- A B A N DON E D~"~__~ .... _SERV~ Name of Ooerator , · . CO~OCO ~C . _ _ ~ '~ .... -' - ~' '~ 8 APl NumOer s0- 029-21988 4. Location pt welt at surface ~ 2072~ E~ 222' E~ 8~C~[O~ 8~ ~3~ ~ 10. Well NumOe, At TOP Producing Interval [ ~--2 1350' FNL, 1550' FEL, SECTION 7, T13N, R10E, ~ ~11.F,etOandPool At Total DePth ~ KUP~UK RI~R FIELD 1277~ FNL, 1728~ FEL, SECTION 7~ T13N~R10E, 5. Elevat,on ,n tee, ,,no,cate KB. DF. etc.) ~ 6. Lease Des,gnat,on and Serml 56 ~R~ MBL ~ ~L25509 12. Date SOuOOed ~3. Date T.D. Reacmec~ 14. Date ComP.. Suso. or Amana. ~ 15. Water Depth. ~t oHsnere 116 Nc at Completions 7936 ~7346 ~ T757 ~7198 ~ ~ YES~ NO "22. Type 6lectrm or Other Logs Run N~T C~L L~T DIL CASING. LINER AND CEMENTING RECORD 23. 1 SETTING DEPTH MD GRADE --"i- i CEMENTING RECORD ',AMOUNT PULLED ' L 24. Perforations open to Procluctlon (MD+TVD of TOD and Bottom and HOLE SIZE 25. TUBING RECORD '-'-'---'-- DEPTH SET (MDI PACKER SET IMDI SIZE interval, sizeancl number) I~ ,'/ loll ~_ ~: I ! I MD TVD' S ~ I ...... - ~CTURE. CEMENT SQUEEZETETC _ I 26. ' '------------ --'- -. 7555' TO 7584' (~[~ZD'S)7029: 70_5_3_, ~OUNT & KIND OF MATERIAL USE '7~R4" TO 7614' 7055 - 7uuu , , 73o, "'' - · I1~ PRODUCTION TEST 27. i Method of Operation (Flowing, gas lift, etc.) Date First Procluct~on I R AT I O I-Iours Testeci PRo--CHOKE SIZE iGAS'OIL D.,. o, est __ I ~TEST PERIOD ~ , ~ ; ~MA'TF~.RRI lOlL GRaVITY-APl tcorr) ~o~re iCALCULATED _~ IOIL'BBL ! GASMCF F IOW /UOlnCJ t bit$1ny , ' ' !2-~-. _____.__-- ..... -- CORE DATA . ' ~ - Bt'el clescriptlon of htnoiog¥, porositY, ~ ~ clips ,nct presence of oil, gas or ware r. SuDmit~ri~Gftys' Submit ir1 auDllC8',,~' Form 10-407 CONTINUED ON REVERS: SIDE GEOLOGIC MARK[.. 30. ,JRMATION TESTS NAME KUPARUK ~ LAMINATED ZONE LOWER KUP. MEAS. DEPTH iTOP 7555" 7654" LOWER KUP. 2 LOWER KUP. 3 7686" 7730" 31. LIST OF ATTACHMENTS Gyro Log, Cement Detail TRUE VERT. DEPTH TOP 7029" 7112" 7139" 7175 Include interval tested, pressure data, all fluids recovered and gr;..vlty, GOR, and time of each phase. N/A 32. I t3ereby certify that the foregoing ~s true and correct to the Pest of my i<nowladge Date 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 iniection, salt water disposal, water supply for iniection, observation, injection for in-situ combustion. Item 5: Indicate which eieva~ion 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 comDtetion), so state in item 16, and in item 24 show the producing intervals for ontv the intervai 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 e{evation (DF, KB. etc.). Item 23' Attached supplemental records for this well should show the details of anv multiple sta~.e cement* lng and the location of the cementing tool. Item 27' Method of Operatio,~' Flowing, Gas Lift, Rod Pump.. Hvarautic Pump, Sui~mersiDie, Water I~,- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-40'~ Milne Point L No. 2 DRILLING HISTORY Page 1 Milne Point L No. 2 DRILLING HISTORy Kuparuk River Field - North Slope Borough, Alaska Milne Pt. L No. 2 (P) CONFIDENTIAL Location: 2,072' FNL, 222' FWL, Sec 8, T13n, R10E, Objective: 7896' - Kuparuk River W.I. 100% AFE 10-61-1190 Umiat Meridian 2-19-90- Moving Rig · · 2-20-90: Finished moving in rig. NU & test diverter system. PU BHA. Accept rig @ 2200 hrs. Unthaw standpipe. Mud wt. 8.7 Viscosity: 80 Cum. mud cost: $3,038 Nabors 27E (0-1-0) Drilling Foreman: Fox 2-21-90: Finished unthawing standpipe. Pick up MWD and install probe. Drld from 50' to 1160. Short trip. Drld from 1160' to 1933. Now drlg. Mud wt. 9.0 Viscosity: 57 Cum. mud cost: $4,990 Nabors 27E (0-2-0) Drilling Foreman: Fox 2-22-90: Drld f/ 1933' to 3200'. Circ, POOH, PU new BHA, Orient MWD, RIH, and Drld f/ 3200' to 3432'. POOH with 5 singles..Ream 3274 to 3316 to remove excessive dogleg. Mud wt. 9.0 Viscosity: 48 Cum. mud cost: $6,831 Nabors 27E (0-3-0) Drilling Foreman: Fox 2-23-90: Reamed f/ 3316' to 3432'. Drld f/ 3432'to 4192'. Survey and short trip. Drlg f/4192' to 4509'. MWD SURVEYS DEPTH ANGLE DIRECTION 3327 4.3 N55.5W 3581 10.0 N68.9W 3801 13.0 N69.6W 3931 14.0 N68.3W 4405 25.3 N68.7W Mud wt. 9.2 Viscosity: 52 Nabors 27E (0-4-0) Cum. mud cost: $9,755 Drilling Foreman: Fox 2-24-90: Now short trip to drill collars. MWD SURVEYS Drld f/ 4805' tto 5095'. Circ. and condition the hole. DEPTH ANGLE DIRECTION 4564 28.4 N68.0W 4691 29.1 N68.2W 4820 32.0 N67.1W 5023 31.8 N65.2W Mud wt. 9.4 Viscosity: 51 Cum. mud cost:$13,684 Nabors 27E (0-5-0) Drilling Foreman: Fox Milne Point L No. 2 DRILLING HISTORY Page 2 2-25-90: Continue to POOH· Work through tight spot f/1900' - 2000' RIH to 5095' circ and condition hole POOH, LD BHA RU · f .· . · · to run csg. Run 117 jts. 9.625 #/ft, J-55 Arctic grade, BTRS csg. Circ and condition hole. Mud_wt., ~9~4 . ~i~'_.~.i.~.~iscosity: ~46 .... Cum. mudcost:$16,498 Nabors 27E (0-6-0) Drillinq Foreman: Fox 2-26-90: Continue to circ. and condition hole. Pump preflush - 40 BBL sepolite & 50 BBL water. Pumped 1st Stage cement job - 178.1 BBL Perfmafrost E and 96.6 BBL Class G. Displace w/ 381.7 BBL mud. Open stage collar, circ. and condition hole. Pumped 15 BBL water. Pumped 2nd Stage - 188.1 BBL Permafrost E and 15.1 BBL Class G. Displace w/ 132 BBL mud, close stage collar. Had Full returns on both stages. RD csg & cmt equipment. ND Diverter. NU wellhead and BOP. Test BOP. Mud wt. 8.3 Viscosity: 27 Cum. mud cost:$17,986 Nabors 27E (0-7-0) Drilling Foreman: Fox 2-27-90: Complete BOP test. Install wear bushing. P/U and test turbodrill & M/U BHA. TIH to 1700' & circ. bottoms up. TIH to 1799' and tag cmt. Drl. cmt. F/1799' to 1803' & Drl. stage collar F/1803' to 1807'. TIH to 4984' and tag cmt. Circ. hole & Drl. out float equip~& 10, of new hole to 5105'. Perform EMW test to.13.2 ppg @ 1100 psi. Drlg F/5105' to 5184'. Mud wt. 8.9 Viscosity: 35 Cum. mud cost:$19,794 Nabors 27E (0-8-0) Drilling Foreman: Fox 2-28-90: 6597'. Mud wt. Nabors 27E Drlg F/ 5184' to 5868'. Short trip. Short trip - No hole problems. MWD SURVEYS DEPTH ANGLE 5290 32.1 5638 32.5 5921 32.9 6204 33.7 6425 32.9 9.5 Viscosity: 35 (o-9-o) Drlg F/5868' to DIRECTION N64.3W ?~ !',~ .i,,,~ 'i N64.5W ~ "'"~" N64 5W !~I~ ,~ ~:, N6 5.2W Ancho.r~_~:io N66.6W ' Cum. mud cost:$25,550 Drillinq Foreman: Polya 3-01-90: Drlg F/ 6597' to 7162'. Short trip. 9.5 to 10.0 ppg. Drlg F/7162' to 7344'. MWD SURVEYS DEPTH ANGLE DIRECTION 6612 33.0 N66.8W 6836 32.9 N68.5W 7017 32.8 N68.9W Increased MW from Mud wt. 10.1 Viscosity: 38 Nabors 27E (0-10-0) Cum. mud cost:$30,711 Drillinq Foreman: Polya Milne Point L No. 2 DRILLING HISTORY Page 3 3-02-90: Drlg F/ 7344' to 7354'. Service rig. Drlg. F/ 7354' to 7480'. Short trip to shoe. Wash & ream F/ 7435' to 7480'. Drlg F/ 7480' to 7766'. Short trip, no problems. Mud wt. 10.3 Viscosity: 36 Nabors 27E (0-11-0) Cum. mud cost:$35,112 Drilling Foreman: Polya 3-03-90: Drlg F/ 7766' to 7812'. Took 2 bbl. gain, monitor well & circ. out trip gas. Drlg F/ 7812' to 7896'. Circ. & condition hole. Short trip, 17' fill. C/O to 7896'. POOH & L/D MWD & turbine. R/U Schlumberger to log well. Mud wt. 10.4 Viscosity: 38 Nabors 27E (0-12-0) Cum. mud cost:$38,530 Drilling Foreman: Polya 3-04-90: Finish logging log well. R/D Schlumberger. Make up BHA & RIH to 7883'. Wash & ream from 7838' to 7896'. Drlg F/ 7896' to 7936'. Short trip. Circ. & condition mud. POOH laying down drillpipe & BHA. R/U to run csg. Start in hole w/ 7", 26#/ft, L- 80, BTRS, csg. Mud wt. 10.4 Viscosity: 39 Nabors 27E (0-13-0) Cum. mud cost:$41,815 Drilling Foreman: Polya 3-05-90: Continue to RIH w/ 7', 26#/ft, L-80, BTRS csg. to 7812'. R/U Halliburton and pressure test lines. Pump 60 BBL, 11.0 ppg sepolite spacer. Pump 51.5 BBL Premium cement, drop plug, pump 10 BBL water followed by 225 BBL 10.2 ppg NaCL/NaBr brine and 70 BBL diesel. Bump plug w/ 2000 psi. Release pressure - floats not leaking. Pressure test csg @ 3000 psi - OK. RD Halliburton. ND BOP. Install tbg. hanger, spool and presure test to 5000 psi - OK. NOTE: Total of 182 jts of 7' csg. run. PBTD @ 7812' RKB. Mud wt. 10.4 Viscosity: 39 Nabors 27E (0-14-0) Cum. mud cost:$41,815 Drilling Foreman: Polya 3-06-90: Finish pumping mud into 7 5/8" X 9" annulus and displace with 60 BBLS diesel for freeze protection. Clean mud tanks. Release rig at 0800 hours. This well will be dropped from the daily drilling report until it is completed Mud wt. N/A Viscosity: N/A Cum. mud cost:$41,815 Nabors 27E (0-15-0) Drilling Foreman: Polya Milne Point L No. 2 COMPLETIONHISTORY Kuparuk River Field - North Slope Borough, Alaska W.I. 0.7214934 Milne Point L No. 2 (P) CONFIDENTIAL AFE 10-61-1190 Location: 2072' FNL, 222' FWL, Sec 8, T13N, R10E U.M. NeB AK Location: Bottom Hole 1245' FNL, 1670' FEL, Sec 7, T13N, R10E, U.M. 11~5-90: MIRU,~ Repair. Swaco~-.choke~panel, PVT..system & heater. Mud wt. 10.2 ppg Viscosity: N/A Cum. Cost: $ 14,800 POOL 102 (0-0-0) Drilling Foreman: BRADY 11-6-90: Continue to rig up. Rig accepted @ 0400 hrs. N/D tree; remove TBG HGR; N/U ROPe. Test same. P/U bit / scraper / 12 DC and RIH. Mud wt. 10.2 ppg Viscosity: N/A Cum. Cost: $ 30,083 POOL 102 (0-0-1) Drilling Foreman: BRADY 11-7-90: P/U 3-1/2" DP & RIH to 1050'. Drlg ice plug f/ 1050' to 1650'. P/U 2 joints of 2-7/8" TBG (X/O f/ drillpipe) RIH to 1713'. Pressure test csg. @ 1713' to 3000 psi for 30 min. Lost 25 psi in 30 min. P/U 2-7/8" TBG & RIH. Tagged fill @ 7750' (33' below proposed bottom perf). Mix HEC pill & R/U to reverse circulate. Pump 25 bbls of HEC pill; Mix & pump 50 bbl pill w/ 1 bbl dirt magnet; mix & pump 25 bbl HEC pill; continue to reverse w/ brine & filter returns @ 3 bpm. Mud wt. 10.2 ppg Viscosity: N/A Cum. Cost: $ 1,481,530 POOL 102 (0-15-2) Drilling Foreman: BRADY 11-8-90: Reverse CirCulate to clean brine thru 10 micron filters. POOH standing 2-7/8" TBG in derrick. Mud wt. 10.2 ppg Viscosity: N/A Cum. Cost: $ 1,499,808 POOL 102 (0-15-3) Drilling Foreman: BRADY 11-9-90: L/D 3-1/2" drill pipe & 4-3/4" drill collars. RU E/L. P/U 4.5" O.D. perf. gun, loaded w/ 5 SPF, 37gm charges & GR/CCL; RIH-tie in & perforate LK-3 f/ 7730' - 7738'. POOH. P/U gun #2 & CCL, RIH, tie-in & perforate LK-2 f/ 7686' - 7714'. POOH. P/U gun #3 & CCL. Perforate LK-1 sand from 7654' - 7680'. POOH. Observe well, well took +/- 3/4 bbls. P/U gun #4 & CCL. RIH &.tie-in. Perforate LZ sand f/ 7584' - 7614'. POOH. Observe well. P/U gun #5 & CCL. RIH & Tie-in. Perforate LZ sand f/ 7555' - 7584'. POOH. L/D lubricator. R/D Schlumberger. Re-arrange frac tanks on location for frac job. Change 2-7/8" rams to 3-1/2". Haul water into frac tanks. Begin heating water to 105° F. Mud wt. 10.2 ppg viscosity: N/A Cum. Cost: $ 1,569,216 POOL 102 (0-15-4) Drilling Foreman: BRADY/KOTARA/ANDREWS 11-10-90: R/U frac equipment. Begin to gel up 2250 bbls water. 11-11-90: Prime pumps - test lines to 6000 psi. Pump 200 bbls pre-pad @ 40 bpm. ISIP - 2050. Pump 1100 bbls pad @ 40 bpm. Pump sand slurry per schedule; 2-4-6-8-10-12 ppg slurry; Pump 285 bbls 11.0 ppg NaBr/C1. ISIP - 1580. Monitor well pressure. ?~ ~!~i~ ~ ~/~ ~% Milne Point L No. 2 COMPLETION HISTORY Page 2 11-12-90: Continue to R/D & R/U slickline. RIH w/ sinker bar. Tag fill @ 7650'. POOH. Top of perfs @ 7555'. PBTD @ 7757'. Estimated fill in hole - 7.5 bbls. R/D wireline. P/U bailer assby: Saw-tooth collars, XO, flapper valve, 37 jts 3-1/2" D/O., XO, bailer pump, XO, 3- 1/2" DP. Capacity of 37 jts. 3-1/2" DP - 7.5 bbls. Tag fill @ 7565'. Bail from 7565 to 7601. P/U wt - 120,000# s/o wt - 100,000#. Mud wt. 11.0 ppg Viscosity: N/A Cum. Cost: $ 1,917,862 POOL 102 (0-15-7) Drilling Foreman: KOTARA 11-13-90: Bail from 7601 - 7676. Well taking fluid (~115 bbls). Monitor well. Attempt to keep hole full. Level dropped to +/- 850' and stabilized. Bail from 7676 - 7757 (PBTD). Make short trip to 7543'. Shut down and monitor well. TIH to check for fill tagged @ 7757. No fill. Take on 150 bbls diesel. Fill hole w/ 14 bbls diesel. POOH L/D drill pipe. Fill hole on 3-1/2" DP displacement w/ diesel. Knock sand out of DP below bailer (packed tight). Mud wt. 11.0 ppg Viscosity: N/A Cum. Cost: $ 2,026,042 POOL 102 (0-15-8) Drilling Foreman: KOTARA 11-14-90: Finish POOH. Recovered 4 bbls sand. L/D drill pipe & DC's in derrick. Test pipe rams. P/U ESP & separator. M/U tool & service. Purge bearings w/ oil. Install cable. M/U bands to pump. Check ESP motor from rig floor & spool unit. OK. RIH w/ ESP. Part of slips set on cable. POOH w/ ESP. Cut off bands and wait on high voltage unit to test cable. Hook up high voltage unit to cable. Test cable. OK. Install check valve, sliding sleeve, run 190 jts 2-7/8", 6.5#/ft, L-80 EUE 8rd. Mud wt. 11.0 ppg Viscosity: N/A Cum. Cost: $ 2,053,662 POOL 102 (0-15-9) Drilling Foreman: KOTARA 11-15-90: P/U 2-7/8", 6.5#/ft, L-80 TBG & RIH. M/U Otis PKR, SCSSV. Splice ESP cable, M/U control line to SCSSV & function test. Test line to 5000 psi. OK. TIH w/ 15 jts 2-7/8", L-80 TBG. Total jts 2-7/8" in hole - 235. P/U TBG HGR. Splice ESP; land TBG. Screw in tie-downs on TBG spool. Pressure up on TBG to 2500 psi. Set Otis PKR. Close annular vent valve. Test backside to 500 psi for 15 minutes. OK. Back out landing joint. Set 2-way check valve. N/D BOP's, N/U Tree. Mud wt 7.6/11.0 ppg Viscosity: N/A Cum. Cost:$ 2,111,889 POOL 102 (0-15-10) Drilling Foreman: KOTARA 11-16-90: N/U Tree. Test to 5000 psi for 15 min. Pull two-way check & set BPV. Rig released @ 0600 hrs on 11/15/90. Operations suspended pending flow test. Mud wt. 6.9/ll.0ppg Viscosity: N/A Cum. Cost:$ 2,130,990 ~ 1 ~g Foreman: KOTARA Attachment No. III MPU L-2 Primary Cmt 13 3/8tm Conductor Csg.: 9 5/8- Surface Csg.= Production Csg: Cemented to Surface Stage 1:178.1 Bbls of 12.2 ppg Permafrost Type E w/5# SK Gilsonite 96,6 Bbls of Class G w/3% S2H & 0.2% CFR-3 Stage 2~ 188.1 Bbls of 12.2 ppg Permafrost Type E w/ 5#/SK Gilsonite followed by 15.1 Bbls Class G w/ 3% Salt & 0.2% CFR 51.5 Bbls of 15.8 ppg Class G Premium w/ 0.2% Halad 344 & 0.2% CFR3 & 0.05% LWL ORIGINAL SUB - S URFA CE DIRECTIONAL SURVEY UIDANCE ~ ONTINUOUS ' ['~-100L RECEIVED NOV 2 '~ 1990 Alaska Oil & Gas Cons. Commission Anchorage Company CONOCO INC. Well Name MPU L-2 (2072' FNL,222' FWL,SEC 8,T13N,R10E) Field/Location MILNE POINT, NORTH SLOPE, ALASKA Job Reference No. Date 74189 ~-NOV-90 Locjcjed By: iC-.ROFILME GCT DIRECTIONAL SURVEY C[ISTO~ F.~ [,!ST I~qG FO R INC. POINT {INIT 51~RV~.y PATE: 8-NOV-1990 ?'OOI~ bOCATIOt:: ';'Ab'CE~4TI/~I,- Averaqed deviation and azimuth I ~? ~7P PObAT 1/.J[, I !,INF;~¢ VERglCAI. SECTION: HrJ~IZ. DIS'I. PROJiTCTED ONTO A TARGET AZIMUTH OF N{'IRTH 67 DEG 32 MIN WEST DATE: 18-NOV-90 PAGE CONOCO It,lC. MTLNE POINT !!NIT L-2 ~ILNE POINT NORTH SLOPE, AbASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZImUTh DEPTH DEPTH DEPTH DEG MIN DEG 0 00 100 O0 200 O0 300 00 40O O0 5OO o0 60O O0 700 O0 80O 00 900 O0 DATE OF SURVEY: 8-NOV-Iggo KELLY BUSHING EbEVATION{ 56.00 FT ENGINEER~ T' WEST INTERPOLATED VALUES FC;R EVEN 100 FEET OF ~EASURED DEPTH VERTICAl.. DOGLEG RECTANGUIjAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST HIST, AZIMUTH FEFiT bEG/lO0 FEET FEET FEET DEG ~IN 1000 O0 1.100 1200 1300 1400 1500 1600 1700 1900 0 O0 -56,00 0 0 N 0 0 E 0.00 0,00 0,00 N 0,00 E 0 O0 N 0 0 E 100"00 44,00 0 8 S 23 1! W 0.24 0'00 0.18 S 0,33 W 0:38 S 61 22 W 200:00 ~44,00 0 3 S 2 17 w 0.22 0,00 O,]b S 0,38 ~ O' 52 S 47 47 W 300.00 244.00 0 3 S 70 2 W 0.23 0,00 0,38 S 0,41 w 0 56 S 46 39 W 400.00 344.00 0 4 S 69 25 W 0.31 0.00 0,41S 0,51 w 0:65 S 51 16 W 500.00 444,00 0 6 S 11 44 W 0.36 0,00 0,52 S 0,60 ~ 0~79 S 49 26 W 600.00 544,00 0 16 S 62 ] E 0.11 0,00 0,74 S 0,43 W 0,86 S 29 59 W 700 O0 644.00 0 18 ~ 87 4 E -0.44 0,38 0,85 S 0,13 E 0,86 $ 8 33 E 709:99 743,9~ 0 17 N 52 bl E -0.82 0,50 0,62 S 0,63 E 0,89 S 45 37 E 899.99 843,9q 0 14 N 25 !8 E -0.93 0,06 0,30 S 0,88 E 0,93 S 70 52 E 0 ~ ~: 2 31E -0.89 0,00 0,02 $ 0,96 0 3 N 14 21. ~ -0.81 0,00 0,14 N 0,94 0 5 N 61 24 E -0.82 0 12 0,20 N 0.97 0 12 N 6~ 36 ~: -0.99 0:17 0.32 N 1,20 0 17 N 61 54 g -1.27 0,00 0,54 N 1,59 0 IR N 66 5 E -{.60 0,00 0 77 N 2,05 0 14 N 6b 18 E -1.93 0,00 0:95 N 2,48 0 12 N 63 54 E -2.1~ 0,00 1~11N 2,fl2 0 19 r~ 70 23 F~ -2.5~ o.,O0 1,29 N 3,25 0 3 S 41 54 ~: -2.74 0,22 1,37 N 3,53 gOO 90 943,99 O0 1099:99 104.3.99 00 1~99 99 ]143.99 O0 ~299:9o 1243.99 00 14gq 99 1443o9n O0 J599 99 1543.99 00 1699 99 1643.o¢~ O0 1709 99 1743.99 O0 1899 99 1~43.~9 0 lo S 11 29 ~ -2.91 0.00 1.10 N 3 61 O 19 S 8 59 E -3.ltl 0.00 O,5fl N 3:68 0 19 S 14 10 E -3.48 0.00 0,05 N 3,79 ¢) 12 S 26 2 E -3.7A 0,00 0 36 S 3,94 0 7 S 2! 33 E -4.on 0.00 0:63 S 4.07 0 10 S 16 27 w -4.08 0,32 0,82 S 4,08 () ]1 S 50 16 ~ -4.05 o,15 1,14 S 3,91 0 19 S 6~ 27 ~ -3.76 0,30 1.36 S 3,51 0 37 N 11 ~5 W -3.~3 0,81 1,01 S 3,08 () 58 a 14 54 P -2.79 0.44 0.40 N 3,18 2000,00 1990.90 1943.9q 2100.00 209Q.99 204~.09 2~00 O0 2199.9~ 2~43.9~ 2300'00 2299.98 2243,qE 2400'00 2399.98 2343.9~ 2500 00 ~499.9~ ~443.9~ 2600 O0 25Q9.98 2543.9~ 2700 O0 2699 08 26a3.oa 2800 0(; ~799:9~ ~7d3.q~ 2000 O0 289q.97 ~E43.97 ~0 3099.91 3(,43.9! 1 t6 O0 3190.87 3143.87 1 20 o0 3299.75 3243.75 4 4 O0 33qq.45 3343.45 5 10 O0 3498.~3 3d~.~3 7 13 oO 3597.~o 35~1.~o lO lq O0 3605.00 3fi3q.q() 1~1 45 O0 3703.82 3737.~ lP 43 O0 3~91.1~ 3~35.1~ 13 40 6] 30 2O E -2.87 0.29 2.31 N 4,07 N 38 32 E -3.4o 0,27 4,58 N 5,57 ~.~ 39 0 E -4.36 le52 6.61 N 7,46 ~{ 57 24 W -0.82 1,!8 9,70 N 4,90 e! 61 50 ~ 6.92 3.23 13,58 N 1,87 ~ t)9 47 ~ 18.oo 1.92 17,92 N 12,07 f'., 69 0 W 33.52 0,95 23,43 N 26,58 ~ 68 53 w 51.54 0.63 30,01N 43.68 N 6Q fi ~ 72.10 0,86 37.28 N 62,61 N 67 53 W 94.94 0,94 45,57 N 83,89 3000 O0 299q.95 7943.Q5 3100 320O 3300 340O 35OO 3600 3700 ~800 3900 0.96 S 89 0 E 0,95 N 81 33 E 0,99 N 78 8 E 1,24 N 75 16 E 1,68 N 71 22 E 2,19 N 69 20 E 2,66 N 68 58 E 3,03 N 68 32 E 3,50 N 68 16 E 3'79 N 68 49 E 3,77 N 73 2 E 3,73 N 81 2 E 3,79 N 89 12 E 3,95 S 84 43 E 4,12 S 81 12 E 4,16 S 78 34 E 4,07 S 73 47 E 3,76 S 68 52 E 3,24 S 71 47 E 3,21 N 82 46 E 4,68 N 60 24 E 7,21 N 50 37 E 9,97 N 48 26 E 10,86 N 26 49 ~ 13,71 N 7 50 W 21,60 N 33 57 W 35,43 N 48 36 W 53,00 N 55 30 w 7. 2 87 N 59 14 w .) C[~,~,~PI..JTATIO. N [:,ATE: 1.8-NOV-OO PAGE 2 CONOCO INC. MILNE POINT UNIT [..-2 ~I, NE POINT NORTH SLOPE, ALASKA INTERPOLATED VA TRUE ~E~SURED VERTICAL DEPTH DEPTH S!)B-SEA VERTICAL DEVIATIOt! DEPTH DEG MIN D 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3988.12 O0 4084.24 00 4179.10 OR 427~ 25 O0 4363~8o O0 4453.56 O0 4541.76 O0 46P9.34 O0 4715 95 O0 4800:63 3032,12 14 49 N 4028.24 17 1 N 4~23,10 19 57 N 4216,25 22 29 N 4307,80 25 4 N 4397,56 27 21 N 4485,76 28 32 N 4573.34 29 11 N 4659.95 31 19 h 4744.63 32 ~7 N 5000 200' 0 54O0 o0 5500 O0 5600 ON 5700 O0 5~00 O0 5900 O0 4885 41 4970~45 5055 39 5140:05 5224.45 5308.73 5392.06 5477.10 5561.16 5645.17 4~29.41 3l 48 N 4914,45 31 40 N 4099.39 3~ I h 5084,05 32 18 N 5168.45 32 33 N 5252.73 ]2 35 N 5336.96 ]2 40 N 5421.,lt) 32 45 h 5505.16 32 51 N 55~9.~7 32 53 h 6000 O0 61 O0 6200 O0 630O O0 6400 O0 650C 6600 6700.00 6RO0.O(~ 6900,00 57?0.04 5812,57 5895.~0 597~,67 6062.1~ 6145.q9 6229.74 6313.50 6397,32 64fl~.13 5673.oa ]3 ~ rJ 5756.57 33 32 ~ 5E39.80 33 45 r. 5o22.~(7 33 56 h 6173.74 3-~ ! r; o~57.%r, 33 If) t~ 6341 .]P 32 5R h 6425. ~ 3 33 9 ~ 70OO 7~00 72OO 7300 7400 75OO 7600 7700 7800 7900 O0 OO O0 O0 O0 O0 O0 O0 O0 O0 6564.7~ 664~,a4 6732,32 68~0,16 6900,05 6983.83 7067.08 7150 O4 723~i99 7315 95 ~592.4a 33 1 ~' 6676.32 33 3 N 6760.!6 33 2 N 684.t.05 3~ 58 ~ 6927.~% 33 i9 ~ 7011.(',~ 33 4q N 7094.0~ 33 58 ~ 7176.o0 33 56 ~ 7?59.95 33 56 N DATE OF SURVEY: ~ELLY BUSHING ELEVATIONI ENGINEER~ FEET OF MEASURED DEPTH E Vk;RTICAL DOGLEG ZI~UTH SECTION SEVERITY 67 0 w 119.46 66 1.5 w 147.01 66 0 w 178,61 66 47 W 214.94 67 37 W 255.16 ~7 39 W 67 9 W 346.33 66 26 w 394.50 65 26 W 444.55 64 48 w 497.69 64 21W 550.65 65 17 ~ 603.1q 65 50 W 655.q3 66 8 w 709.14 66 25 W 762,76 66 27 ~ 816.57 66 29 W 870.47 66 51W 924.5o 67 8 W 078.66 67 25 W 1032.91 67 ~2 w 1.087.]7 67 14 ~. 1142.34 67 8 w 1197.7~ 67 4 W 1253.4K 67 58 W 1308,75 68 2o w 1363.31 63 50 w 1417.~a. 69 14 W 1472.55 70 [9 w 15~7.04 70 ,!O w 1581,52 71 0 w 1636.23 71 i7 ~ 1090.9n 71 12 W 1745.2] 71 1 w 1799.62 69 52 W 1853.9~ 69 48 ~ 1908.53 70 1 W 1963.Rq 70 12 ~ 20~9.67 76 11 ~ 2075.45 70 11 W 2131,22 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST FEFT FEET HORI D157, FEET Zt 2,33 1,81 3,09 1,90 2,21 2,80 0,74 0,73 3,38 0,78 55,0] N 65,97 N 78 80 N 93:36 N 108,94 N 125,68 N 143.76 N 162 79 N 183i19 N 205 61N 106 52 131 80 160 69 193 99 231 07 271 83 315 ]3 359 68 4O5 31 453,54 119 89 147:39 178,97 215,28 255,46 299 47 ]46:55 ]94,80 444,78 497,97 U,46 0,93 0 27 0~31 0,25 0,17 0,29 0,21 0,19 0,22 228 250~ 272 294~ 315 337: 359 3~0! 401 422, 39 N 93 N 71 N 37 N 96 N 46 N 01 N 40 N 58 N 52 N 501 43 548:96 597,03 645 65 694 75 744 09 793 50 843 12 892 97 943,02 550 99 603 59 656 ]6 709 59 763 22 817 04 870 9] 924 97 979 11 1033 35 0,46 0,29 0,24 0,18 0,90 40 g:s2 0,47 0.18 0.30 443. 464, 486, 507. 529. 549. 569. 588. 607. 625. 47 N 993,29 67 N 1044,00 19 h 1095,09 84 N 1146 38 09 N 1197~44 36 N 1248,10 34 N 1298,96 91 N 1349.96 72 N 1401.14 96 N 1452.55 1087,79 1142 74 1198 17 1253 83 1309 13 1363 65 1418'25 1472,82 1527,26 158~.69 0.17 0,49 0.32 0.53 0.48 0,47 0.64 1.00 0.00 0.00 643 661~ 679, 696, 714 733i 752 771 790, 809, 97 N 1504,32 66 N 1556.16 15 N 1607,72 74 N 1659.30 98 N 1710.58 85 N 17b1.81 91N 1813,83 92 N 1866,34 86 N 1918,86 80 N 1971,39 1636.]6 1690.98 1745,28 1799,65 1853 99 1908:54 196],89 2019.67 2075.45 2131.23 8-NnV-1990 56.0O FT T. WEST DEPARTURE AZIMUTH DEG N 62 41 w N 63 25 w N 63 53 W N 64 18 W n 64 46 W N 65 11W N 65 30 W N 65 39 W N 65 41W N 65 37 W N 65 31 W N 65 26 W N 65 27 W N 65 29 W n 65 33 W N 65 36 W N 65 39 W N 65 43 W N 65 47 W N 65 52 W N 65 56 W N 66 AW N 66 4 W N 66 6 W N 66 10 W N 66 15 W N 66 20 W N 66 26 W N 66 33 W N 66 41W N 66 50 W N 66 58 W N 67 6 W N 67 13 W N 67 19 W N 67 23 w N 67 27 W N 67 32 W N 67 36 W N 67 40 W CU~,~P~ITAT IO~ DATE: PAGE: 3 CONOCO INC., MILNE POINT I~MIT ~ILPF POINT NORTH SLOPE, ALASKA DATE OF SURVEYI 8-NOV-lg90 KELI, Y BUSHI~4G ELEVATIONS 56.00 FT ENGINEERS T. WEST INTERPOLATED VALUES FOR E~/EN 100 FEET OF MEASURED DEPTH TRUF SI)B-SEA PEAS~IRFD VERTICAL VEPTICAL DEVIATIOr.i AZI~,~UTh DEPTI~ DEPq'lq DEPTH DEG ~:RTICA!., DOGLEG RECTANGLILAR COORDINATES HORIZ, DEPARTURE $~CTI, Or: SEVERITY ~!ORTH/SOIITH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FFET FEET DEG ~IN 7901,00 7316,7S 7260,7~ 33 56 ~; 70 11 w 2131..7P 0,00 809,99 N 1971,9! W 2131,79 N 67 40 W CONOCO INC. MILNE POINT UHIT MILNE POINT NORTH SLOPE, ALhSKA PAGE 4 DATE OF SURVEY1 8-NOV-1990 KEbLY BUSHING ELEVATIONI 56,00 FT INTERPOLATED VALttES FO~ EViaN 1000 FEET OF ~EASURED I)E:PTH TRUK SUB-SEA ]~:EASURFD VERTICAL VERTICAL DEVIATIO~ DEPTH DEPTH DIKPT~ DEG N 0 0 E ~ P 31 E $ 11 29 E 0 O0 -56,00 0 0 O0 999:99 943,99 0 8 O0 1999 99 1943,99 0 16 O0 2999:95 2943,95 1 31 O0 398~,12 3932,12 14 49 O0 48~5,41 ~829,41 31 48 O0 572~.04 5~73.04 33 8 00 6564 7~ 6508.78 33 20 O0 7316:78 7260'78 33 56 ENGINEER: T. WEST 0 O0 1000 2O00 3000 4000 500o 60OO 7000 7901. VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIM£]TH FEE7' PEG/lO0 FEET FEET FEET DEG MIN 0.00 -0.80 -2,91 ~ 30 20 E -2.87 N 67 0 ~ 11.9.46 ~ 64 21 W 550.65 ~ 67 22 w 1087.37 ~ 7! 0 w 1636.23 N 70 Il w 2131.78 0.00 0,00 0,00 2~33 0,46 0,46 0,17 0,00 n.oo N o.00 E 0 O0 N 0 0 Z o 02 $ 0.96 E 0 96 S ~9 0 £ 1 10 N 3 61 E 3 77 N 73 2 £ 2 3! N 4:07 E 4 68 N 60 24 E 55 03 N ~o6~52 ~ 119 89 N 62 4t W 228 39 N 501 43 W 550 99 N 65 31W 4a3 47 N 993:29 W 1087 79 N 65 56 W 643 97 N 1504,32 W 163b 36 N 66 50 W 809:99 N 1971.91 ~ 213! 79 N 67 40 W CONOCO INC. MIbME POINT UNI~~ L-2 MILNE POINT NORTH St, OPE, AbASKA C(:,/~:PUTATIOtJ DATE: IR-Nc)V-90 TRUE NUB-SEA CO~JRSE ~EASURED VF, RTICA[, VERTICAl, DEVIATIOn,; AZt~1)TH DEPTH DEPTH DEPTH DEG PAGE 5 ~ATE OF SURVEY~ 8-NOV-1990 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER.: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAl. DOGI. EG RECTANG[!LAR COORDINATES HORIZ, DEPARTURE SECTIOh SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/~O0 FEET FEET FEET DEG 0 O0 56 156 ?56 356 O0 456 556 O0 656 O0 756 856.01 0 O0 -56.00 0 0 N 0 0 E O.Oe 0,00 0,00 N 0,00 E 0,00 N 0 0 E 56~00 0.(}0 0 7 S 37 14 w 0.22 0.04 0 10 S 0,28 ~ 0,30 S 71 0 W 156.00 100,o0 0 7 S 17 11 ~ 0.24 0,06 0:30 S 0,38 w 0,48 S 51 50 w 256 O0 200.00 0 I S 43 45 W O.2P 0,00 0,38 S 0,39 ~ 0,54 S 46 10 W 356:0~ 300,00 0 4 S 80 14 W 0.27 0.00 0,39 $ 0,46 k 0,60 S 49 16 W 456.00 400.00 0 5 S 37 37 w 0.36 0.00 0 46 S 0 57 w 0 7] S 51 25 w 556.00 50~.00 0 11 S 37 53 E 0.28 0,20 0:63 S 0:57 w 0~85 S 41 55 W 656.o0 600,o0 0 21 S 81. 39 E -0.20 0.00 0,83 S 0,13 W 0i84 S 8 42 w 756.0o 700,00 0 21 N 62 4b E -0.67 0,14 0,76 S 0,41 g 086 S 28 39 M R56.00 800.00 0 14 N 36 24 F -0.90 0.00 0,40 S 0,78 g 0,91 S 59 47 E 9 ~ 13 22 E -0.92 0.00 0.13 S 0,94 E 5 f, 13 55 ~ -0.84 0,00 O,OO N 0,95 E 3 ~ 34 49 E -0.80 0,00 0.18 N 0,94 E 9 N b5 23 E -0.90 0,00 0,25 N 1.08 E 16 h 59 5 E -1.1.4 0,00 0,44 N {,41E l~i t~ 62 18 E -1.45 0,00 0,67 N 1,84 E 16 ~ 68 39 E -1.70 0,00 0,88 N 2 30 E 1.2 f) 65 7 E -~.OP 0,00 1,04 N 2:68 g 16 N 66 29 E -2.35 0,00 1,21 N 3,04 E 8 N 77 {5 E -2.69 0.25 1,37 N 3.48 E 956 01 1056 1.156 1256 1356 1456 1.556 1656 1756 1056 0 !o S 1.3 3 E -2.82 0,14 1.27 N 3,57 ~ lq S R 22 ~. -3.o6 0,00 0,82 N 3,65 0 19 S lO 39 E -3.35 0,00 0.28 N 3,74 0 16 5 ?o 45 Y -3.65 0.00 0,20 S 3 87 o ]1 S 27 22 E -3.92 0,07 0.53t S 4102 0 7 S .2 3 ~ -4.06 0 02 0,72 S 4~09 ~ 13 S ~5 o w -4.OR 0100 1.02 S 3,99 ¢) lB $ 62 4q v; -3.91 0,17 1 25 S 3.72 ~ 20 ~ 4~ 4~ W -3.5(, 0.90 1:33 S 3,23 0 51 ~ 5 39 F: -2.93 0.51 0,28 S 3,06 956,00 a()o.o0 01 1056.00 1000,00 01 1156,00 1100.(;0 O1 1256.00 1200,00 O1 1356 O0 1300,00 Ol 145b~00 !400.oo Oi 1556.0o 1500.00 O1 1656.0() !600.o0 01 1756.00 170~.00 01 185f..00 lRO0.Oo lq56.01 1956.00 19C~0,00 2056.01 2056,00 2000.00 2156.01 2156,n0 2t0(,.00 2256 02 2256 O(? ~?00.0n 2356 02 2456 02 2456.oo 2556 02 2656 02 2656,00} 2756 02 2756.01~ 2700.0n ~56 03 2n56.00 ;.. 25 1.7 E -2.76 0.67 1,38 N 3,56 E c: 33 41 F -3.12 0,28 3,60 N 4.87 E f'.: 44 41 E -3.95 0,21 5.76 N 6,66 E t. 45 9 ~ -3.49 5.86 8.04 N 7.11 E ~ 60 33 w 3.35 0,39 11.84 h 1,27 E ~ 67 57 V: 1.2.RO 1,56 16'07 N 7.20 w r. 69 9 ~ 26.25 3,34 20~3 N 19,79 W N 68 57 k 44.33 0,31 27,31 N 36,67 W N 69 ~ W 63.7R 2,96 34.31 N 54,83 k N 68 39 w 86.45 1,70 42,42 N 76,01 W 2956 04 2956.00 3056 07 3056.00 3156 3256 3356 3456 3557 3659 376~ 3863 2qO0. O0 1 I 2 30r)O.OO I 33 11 3156.00 310C). ()(, I 41 16 3256.00 3200.¢)r~ 2 52 40 3356.00 3300.e0 4 '29 86 3456.0,0 3400.00 f. 40 77 3556.0() ]bOO, 0() q lq 39 3656.00 3600.00 lO 36 77 375~.0~) 37o0.oo 12 O 81 3856,0o 3BO0, c,O t3 21 0.95 S 82 3 E 0,95 N a4 20 g 0,96 N 79 19 E 1,11 N 76 42 E 1,48 N 72 51. E 1,96 N 69 56 E 2 46 N 69 8 E 2:87 N 68 44 E 3: 27 N 68 19 E 3 74 N 68 30 E 3,79 N 70 29 E 3,74 N 77 19 E 3 75 ~ 85 42 E 3:87 S ~6 58 E 4 06 S 82 30 E 4 16 S 79 57 E 4 12 S 75 44 E 3 50 S 4 £ 3,07 S 84 41 ~ 3,82 N 68 48 E 6,05 N 53 33 E 8,81 N 49 6 E 10,73 N 41 28 E 11,91 N 6 8 E 17,61 N 24 9 W 28,74 N 43 32 W 45,72 N 53 19 W 64,68 ~ 57 58 W 87,04 N 60 50 W CO~.'iPUTATIOt~ DATE: !8-NOV-g0 PAGE 6 CONOCO INC T MILNE POIN~ UN! L-2 MILNE POINT NORTH SI,OPE, ALASKA DATE OF SURVEYI B-NOV-1990 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER{ T. WEST INTERPO{.ATED VALISES FOR EVEN 1:00 FEET OF SUB-SMA DEPTH TR[~F SUB'SEA CO~)RSE ~EAS[!~ED Vf]RTICAL VERTICAL DEVIATIO[~ AZIMPT~{ DEPTH DEPTH DEPTH DEG MIN DEG ~IN VERTICAL DOGLEG RECTANGULAR COORDINATES MORIZ, DEPARTURE 6ECTI[)N 6EVERITY NORTH/SOUTF! EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 3966 ~2 395~,n0 3gO0,O0 14 15 4070 51 4056.00 4000,00 16 28 4175 439~ 450~ 4616 4730 4847 4965 49 4~.51, OO 4!o0.00 19 12 43 4256~o0 4200,00 22 7 38 4356.00 4300,00 24 53 75 4456 00 4400,00 27 26 ~ 4556!0,, 4500.00 28 38 4656 O0 4600,00 29 27 16 4756,00 4700,00 32 ~4 37 4856,00 4800,00 31 57 N t7 7 w N 66 27 W N 65 b~ W m 6e 4O W N 67 35 W N 67 38 W N 67 1W ~'~ 66 9 W N 65 4 W N 64 29 W 111.1d 1,01 138.52 1,86 170.4p 3,12 208.2~ ~,98 251.49 2.37 ]00.49 2,67 354,08 0,8~ 409.55 1,36 469,42 1,10 532,]9 0,64 51.78 N 62.56 N 124,02 W 138 75 46 M 153,20 70 90 72 N 187,87 W 208 107 54 N 227,67 W 251 126 16 N 273 O0 W 300 146 77 N 322 47 W 354 168 38 W 409 193 61N 427 220 98,85 W 111,59 N 62 21 W 91 N 63 14 W 78 N 63 47 W 63 N 64 1] W 79 N 64 4] W 74 N 65 12 W i 30 N 65 3~ W 81 N 373 77 N 65 40 W 91 469 68 N 65 39 W 49 N 484,94 W 532,71 N 65 33 W 5083 02 4956.00 4900,00 31 41 5~00 72 5056,00 5000.00 32 ! 5318 5a37 5556 5674 5793 5912 6032 6152 88 5156 O0 51.00.00 32 21 43 5256:00 5200,00 32 33 l{ 5356,00 5300,00 32 ]7 92 5456,00 5400,00 32 44 86 5556,00 5500.00 32 51 90 5656.00 56O0.00 32 55 23 5756 O0 5700,00 3] 17 15 5856:00 5800.00 33 41 N 65 2 W 594.28 N 65 50 W 656.31 N 66 11 W 719,24 N 66 30 ~ 782.90 N 66 25 W 846,80 N 66 47 W 910.94 ~ 67 7 W 975.33 N 67 25 W 1039,92 N 67 22 ~ 1105,0~ N 67 9 W 1171.21 1,32 0,26 0,35 0,02 0,07 0,25 0,18 0,32 ~:45 247 !9 N 540 87 W 594,68 N 65 26 W 272:87 N 597:38 W 656,74 N 65 27 W 298'45 N 654'89 W 719,69 N 65 30 W 324,0~ N 713.21 W 783,36 N 65 34 W 349,55 N 771,80 W 847,26 N 65 3~ W 375,06 N 830 66 W 9!.1,41 N 65 42 W 400 28 N 889 90 W 975'78 N 65 47 W 4~5:21N 949 49 W 1040,35 N 65 53 W 450~26 N 1.009 57 W 1105 43 N 65 58 W 475,87 N 1.070 62 w 1171:61 N 66 2 W 677~ 44 5956.00 5900.00 33 54 63g~ 62 6056 O0 6000.00 33 651~ 96 6~56]00 6100,00 33 6631 33 6256i O0 6200.0o ]] 5 6750 74 6356.00 630o.00 3] 2 6869 99 6456.00 6400.00 ]3 6 6989 50 6556,00 65n6.On 7109 O{ 6656.00 661i0.0(~ 7~2~ 25 6756.{,~ ~700.On 33 7347.50 6856.00 6fiot).Of~ 32 5~ b 67 7 W 1238.07 N 67 54 W 1304.72 h 68 22 W 1369.86 N 68 57 ~ 1435.02 D 69 53 ~ 1500.24 i~ 70 39 W 1565.~4 N 70 57 z 1630.48 pi 71 17 ~ ~695.80 ~i 7~ 12 ~ ]760.60 ~' 70 2~ W 18~5.44 0,35 1,10 0.27 0.39 0,91 0,35 0,11 0,54 0,26 0.76 501 86 N 1132,22 W 1238,46 N 66 6 W 527 58 N 1193 71 W 1305,10 N 66 9 W 551 78 N 1254:18 W 1370,20 N 66 15 W 575 49 N ~3~4 QO W 1435,32 N 66 22 W 598 60 N 1375:92 W 1500,49 N 66 29 W 620.51 N 1437,08 W 1565,32 N 66 39 W 642 09 g 1498,86 W ~630 60 N ~6 49 W 663:24 N 1560,8! W 1695:88 N 66 59 W 684,11 N 162~,30 W 1760,64 N 67 8 W 705,27 M 1683,71 W 1825,46 N 67 16 W 7466 72 6956.00 mn()O.OC 33 B 7586 66 705b,o0 700o.0o ]3 50 7707 ~o 7!56.00 7~0o.0o 33 56 7827 73 7256.00 7?00.o0 33 56 7901 O0 73~6.78 7260.7s 33 56 Pi 60 48 W 1890.31 N 70 0 ~ lg56.46 N 7(, ]{ W 2023,69 N 70 ]1 m 2090.92 ~ 70 1! ~ 2131.78 0,76 0,54 0.00 727 56 N 1744,70 W 1890,32 N 67 22 W 750:36 N 1806,85 W 1956.47 N 67 27 W 77],29 N 1870,11 w 2023,69 N 67 3~ W 796,11N 1933,43 W 2090,92 N 67 37 W 809,99 N ]971.91 W 2131,79 N 67 40 W DATE: 18-r'~OV-90 PAGE '7 CONOCO I~C. MILNE POINT UNIT L-2 ~ILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 8-NOV-1990 KELLY BUSHING ELEVATIONI 56.00 FT ENGINEERI T. WEST INTERPOLATED VAL!~k[$ ¥0~ CHOSEN MORIZONS SURFACE LOCATION = 2072' FNL & 222' FWL, SEC8 T13N RIOE TVD FR(}P. KB S!IB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST LAST READI~iG (]F GC~ 7" CASING S~OF:-D~ILLER 7702.59 7757.00 7901.00 7~52.18 7096,18 7~q7.32 7{41.32 7316.78 7260.78 772 41 782:72 809.99 1867 70 w · 971,9! W CO~,iPUTATI.r]N DAIE; :}8-NOV-90 PAGE 8 CONOCO ~ILNE P[]IMT !!NIT [.-? ~ILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: KELLY BUSHIMG ELEVATION[ 56,00 MT ENGINEER[ T, WEST ~[J~FACE I,OCgTION = 2072' FNL & 222' FWL, SEC8 T13N RIOE MARKFR MEASURe. iD DEpTFi TVD BEI.,O~ 8:}':'. FROt~ ~8 SLIB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST L~S~' RFADING OF GCT PBTD 7" CASING SHOE-DRILLER 7702.59 7152.18 7096,18 772,41 N 1867,70 7757,00 7197.32 7141.]2 782,72 N 1896,27 7901,0¢) 7316,78 7260,78 809,99 N 1971,91 FINAL WELl.., [..,()CATION AT TD: ~'POE SUB-SEA MFASlIRED VERTICAL VERTICAL DEPTH DEPTH DEPTH hORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 7901,00 7316,78 7260.7~ 2131,7q ~.! 67 40 W SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY CONOCO I NC. WELL MILNE POINT UNIT L-2 FIELD MILNE POINT COUNTRY USA RUN ONE DATE LOOOEO 08 - NOV - 90 REFERENCE 74189 WELL' .MPU L-2 (2072' FNL, 222' FWL, SEC 8, T13N,.R10E) HORIZONTAL PROJECTION S~UTH - -2600 I, IEST ~:d::lqI. E = 1 / ~ IN/FT -2000 - I SOO - 1000 -ISO0 0 500 1000 I SOO Eta6T ,W'ELL: 'MPU L-2 '(2072' FNL, 222' FWL, SEC 8, T13N, RIOE) VERTICAL PROJECTION - 1L]00 -SOO 0 0 ~ il i ~ I i , i ~,~'~; . , , , '?'~-' . . , .,.,~. ~buu 2000 ' 2S00 -~000 ~-~.+.,+...~ .+~+.+..,_. ~ . , ~ ~ ~, ~ · ~ ~.~.. 4..?-~ ..... ~...~ ......... ,4 ........ ~...~..~ . , , _: ...... ~ ~.~-4.- ~. .~ .... % .,.. ,~ ~ ,~, ..... ~ .~ ~.~..:..?... ...... ...... ...... .... .......... ........... .... --~-~--~ ...... f.-~-.+%., k+.4..%.;...,-~..~.-~.4-.-$ L.L..[ l. ~ ~ ~ ?T"FT' 'T'?T"~ ...... ~"t-?'T'~-'~'"+"~"'~ ...... f..~.$..~...~.4...;..~...;.. ~...;...~ ... ~ 1 ....... ~..~. 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T'"T'"T'"T, ' 4 ..... t" T'"?T.. ..... ~ "+""f'"~ ..... k-t .......... , ~--.t-..+.,.~ ........ ...... , , ~ ~ ~ -:.-~..~ ........ ?.-?.~ .......... ~....~...~...~....~...~...~...~ ....... ~.~ ,, J il ?' :i:i T'~ ..... ~ i i i i-~..i.-.e.-~+-i.-+-. ,.?-i--~-~ ...... ~.4.~.~..~-~_-.i4~..-~..i~,..i ...... ~..i-4...~ : ~ i ~ ~ ~ ~~ ~ ~ ~ ~ . : : ~ I ~ / .......... ~i : ~ ~ : , ~ ~ ~ , : ~ ~ i ' ' ; ~ ~ ~ ~ t ~":'"?'t"t .............. ~"t ............ t"'t' , , , , , , , i , , ' , i i ~ ~ ~ ~ : ~ [ ' ~ I PROdECTION ON VERTICRL PLi:INE 292. - ] 12. SCRLEO IN VERTICAL DEPTHS HORIZ SCALE = I/SO0 IN/FT r PERMIT · ~ ~ - COMPLETION DATE /~ / ~ / ~ CO, CONTACT check off or list data as it is rcceived.*list received date for 407, if not drillin, history' survey well tests cored intc~als core analysis ditch intc~als uired list as NR core dcscri; ital data i ' ' "~'~ i I rL- L,.,,~ ~nd' i RLj j~j J INTERVALS SCALE NO. {to thc nearest, foot]. . [inchll O0'J ,, i ii Al ' ' ' " J ' sl C~ / 7~ ~ Z~~ 1~l , ~ ~i"m. ...... SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY ' LOCATION · ATTENTION · COMPUTING CENTER PRINT CENTER WELL NAME SERVICES WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · : ADD'L TAPES · NO. OF BOXES' JOB NO. ' ADD'L TAPES ' WELL NAME · SERVICES ' WELL NAME · SERVICES ' NO. OF BOXES' JOB NO. · ADD'L TAPES · NO. OF BOXES' JOB NO. · ADD'L TAPES ' WELL NAME · SERVICES · WELL NAME · SERVICES · NO. OF BOXES· JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: NO. OF BOXES: JOB NO. ' ADD'L TAPES · RECEIVED BY: STATE OF ALASKA /-__ ,SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS * Type bt Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well Alter casing __ Repair well __ Plugging __ Time extensIon __ Stimula-~'e X Change approved program __ Pull tubing __ Variance __ Perforate X Other ~ 2. Name of Operator . ~ 5. Type of Well: 6. Datum elevation (DF or KB) i OeveloomentX COD. bOO Tt1. c. Exoloratory__ 56 ~ RRB 3. Address 99503 Stratlgrapnic __ 7. Unit or Property name Suite 200, Anchoraae, AK Serwce__ Milne Point Unit 3201 C St 4. Location of well at sudace 2072' FNL, 222' At top of productive interval FWL, Sec. 8, T13N, R10E, U.M. At effective depth Gyro Survey At total depth Data to be submitted on Form 10-407 8. Well number 'f.-2 9. Permit number 90-6 10. APl number 5O-- 029-21998 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical 7936 feet 7335 * feet Effective depth: measured 7808 feet true verticat 7244 * feet Casing Length Size Structural Conductor 80 ' ' 13-3/8" Sudace 5041 ' 9-5/8" Intermediate Production 7866 ' 7" Liner Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A Plugs(measured) PBTD - 7808' MD Junk (measured) N/A Cemented Measured depth To surface 115' 301 bbls Class E 5076' 112 bbls Class G 54 bbls Class G 7901' True vertical depth 115' 4949' 7321' TVD depths are based on MWD directibal data not from Gyro. RECEIVE NOV 1 91990 13. Attachments Description summary of proposal __ Detaded operations program ~ BOP sketch __ 14. Estimated date for commencing operation November 3~ 1990 16. Il proposal was vemalty appro_ved /'~..-/ Oil}( Name of aoprover ~ ,.5~ ¢ u~r~p Date aoproved Service 17. I here~y cen, ly t/~at the ,o/ego,ng ,s true ana correc, to the des[ o, my Know,edge. / Signed ~_~ /~F~ Title Production Engineer FOR COMMISSI©N USE OHLY 15. Status of well classdication as: Gas __ Suspended __ Date Nov. 2, 1990 Conditions of aooroval: Notify Commission so representative may w~Iness Plug ~ntegnty __ BOP Test __ Location clearance ~ Mechanical Integnty Test ~ Subsequent form required 10- ORIGINAL SIGNED B~ 'E'* LONNIE C. SMITH poroved by order of the Commission Form 10-403 Rev 06/15/88 - 43 - Approved Copy Returne~! _ .~ ~. ! ~,m .Goner SUBMI f IN TRIPLICAfE MPU L-2 WELL Milne Point Unit PROPOSED COMPLETION PROCEDURE AFE No. 10-61-1190 10/9/90 - CVL Objective: Clean wellbore fluids; perforate the LK-3, LK-2, LK-1, and LZ sands; fracture stimulate; run an ESP and postpone start-up until surface equipment hook-up is completed. Surface Location- 2072' FNL & 222' FWL of Sec. 8, T13N, RIOE Depths' All depths are measured from original RKB (49.0') and open hole logs dated 3/3/90. Casing' Surface: 9-5/8", 36 #/ft, J-55, btrs. set @ 5076' Production: 7", 26 #/ft, L-80, btrs. set @ 7901'. Capacity = 0.0382 bbl/ft Drift ID : 6.276" Burst Pressure : 7240 psi Tubinq/workstr' 2-7/8", 6.5 #/ft, L-80, EUE 8rd (approx. 7800' required). Capacity : 0.00579 bbl/ft tubing; 0.0302 bbl/ft annulus ID : 2.441"; Drift ID : 2.347" Burst Pressure = 10,570 psi Torque (ft-lb): Min = 1730; Optimum = 2300; Max = 2880 Misc' PBTD : 7808' RA Tag @ 7288' Pore pressure : 9.6 ppg equivalent (3550 psi) Fluid in well : 10.2 ppg NaBr/C1 Proposed completion fluid : 11.0 ppg NaBr/C1 (10 deg F TCT) Max Angle : 33 deg; Angle through pay: 33 deg Proposed RU and Wellbore Cleanup Procedure- NOTE: Hold frequent on site safety meetings prior to all potentially hazardous tasks. · Skid rig to the L-2 well and RU on well. ND tree and tubing hanger. NU BOP's. Install pipe rams for 2-7/8" tubing. Test rams to 250/4000 psi and test Hydril to 350/3500 psi. Record tests on AOGCC and Conoco daily reports. · MU bit w/o jets and full gauge nominal rotatable casing scrapers on tubing. · PU tubing and GIH below proposed bottom perfs @ 7738'. Pressure test casing to 3000 psi for 30 minutes(if necessary). Reverse circulate the following cleansing pill at maximum pump rates. a· c· Lead pad - 25 bbls of 3.5 #'s HEC/bbl of brine Chemical pad - 50 bbls of brine + 1 drum of surfactant/dispersant(Safe-Kleen, Dirt Magnet, etc..) Tail pad - 25 bbls of 3.5 #'s HEC/bbl of brine Post flush - circulate with filtered brine (10 microns) at maximum rates until less than 50 NTU NOTE: 1. Safety and environmental precautions must be taken when handling brine and chemicals. Review MSDS sheets prior to handling. · Chemicals must be mixed and maintained above 70 deg F. Monitor brine clarity every 50 bbls during post flush with a Turbidity Meter. Submit results to engineering. 4. POOH and L/D bit. RECEIVED NOV 1 91.%0 hiaska Oil & Gas Cons. {',ommission Proposed LK-3, LK-2, LK-I~ and LZ Perforating Procedure: 1. RU Schlumberger electric line. Hook up down-joint w/ pack-off and place in Hydril for pressure control. Run Gyro survey(if necessary). 2. Hold safety meeting and discuss hazards and required precautions associated with wireline perforating. Pressure test lubricator. NOTE: All Conoco and Schlumberger (see attached) perforating safety procedures must be strictly adhered to. These procedures and safety meetings shall be repeated with each subsequent gun run. 3. MU 8' x 4.5" OD gun assembly (5 SPF, 37gm, 51B deep penetrating charges) with GR/CCL for depth control. GIH and correlate w/ open hole logs. Place guns on depth and shoot LK-3 @ 7730'-38'. POOH and monitor hole. L/D spent guns. NOTE: Measure OD and length of all tools to be run in the hole. Measure and record distance from top shot on gun assembly to GR/CCL. 4e Repeat step 3. four additional times as follows w/ CCL as depth control, if first run proves CCL correlation feasible. Run No. Length Interval Sand 2 28' 7686'-7714' LK-2 3 26' 7654'-7680' LK-1 4 30' 7584'-7614' LZ 5 29' 7555'-7584' LZ ,,, ,, RD electric line. Monitor fluid level. Do not attempt to keep the hole full to surface. This may result in large volumes of fluid lost to the format i on. Proposed Hydraulic Fracturinq Procedure: · Spot seven 500 bbl frac tanks on location. Elevate the rear of the tanks approximately 8". Visually inspect the interior of the tanks for cleanliness. DO NOT ENTER THE TANKS. Fill five tanks with 450 bbls clean injection water. Check pH of injection water in each tank and neutralize if necessary. Fill the sixth and seventh with 225 bbls filtered 11.0 ppg NaBr/Cl completion fluid w/ 4 gal/lO0 bbl Unitreat 3900 biocide/inhibitor for flush. The water/brine should be heated and filtered to 10 microns absolute with a hot oil truck and maintained at 75 to 80 degrees F to insure proper hydration of the gelling agent. Water from the central facility, carried in clean transports is acceptable. 2. Rig up Dowell Schlumberger to perform the frac treatment. NOTE: a. Use of threaded connections, crossovers, swedges, etc. in the treating 1 ine is not acceptable. b. Use two in-line densitometers. c. Use two shut-off valves on the wellhead. d. Set the backup pumps for the crosslinker and diesel. ee Standby pumps (50%) are required. These pumps must be manned and primed to come on line immediately if needed. A standby blender should be hooked up and ready to come on line in case of primary blender failure. fe BOP saver installation shall be coordinated by Conoco and DS personnel on-site prior to frac RU. Insure that "donut" is butted against 4" pipe rams prior to pumping. ge Tank bottoms are included in the volumes listed. Plan for 75 bbl tank bottoms. he Use the in-line densitometer during the treatment. rate, pressure, and density on a chart. Record i · Take samples of the crosslinked gel during the treatment. Place these samples in a bath at 155 deg F. Note the actual break time. Note the pre-pad is not crosslinked and does contain diesel. j · Shut down after pre-pad for meter to tank verification and 15 minute pre-job ISIP. k. DO NOT OVERDISPLACE THE TREATMENT UNDER ANY CIRCUMSTANCES. · Batch mix 2250 bbl gelling agent at 50 lb/1000 gal with additives. The pre-pad consist of non-crosslinked gel (no diesel). Particulate fluid loss additive (40#/1000 gal) should be added in the pre-pad and pad fluids Page4 R ECEIVED NOV 1 91990 Oil A Gas Cons. Commissio~ AnchoraG, a only. Diesel (5%,,) and crosslinker activator are the only additives that should be mixed on the fly. Sand (Carbo-Lite) will be added in the prescribed stages through the blender. 4. Hold on-site safety meeting with rig personnel and frac crew to communicate hazards of the operation. 5. Pump the frac job as follows at 40 BPM: Stage Name Stage Barrels Cumulative Treat Pump Proppant Gel Pumped Barrels Press Time (Lbs) (Ea. stage) Slurry Pumped (psi) (Mini Pre-Pad 0 200 200 3100 5.0 PAD 0 1100 1100 4100 27.5 2 PPG Slurry 4860 63 1160 4000 1.6 4 PPG Slurry 10000 70 1230 3800 1.8 6 PPG Slurry 20900 105 1340 3500 2.6 8 PPG Slurry 34300 138 1480 3200 3.5 10 PPG Slurry 49300 169 1650 2900 4.2 12 PPG Slurry 59000 179 1820 2700 4.5 FLUSH 0 285 2110 2500 7.1 e 7~ Shut down. Allow the pressure to bleed off into the formation. Record the ISIP, and pressure for 30 minutes (5, 10, 15, and 30 minute readings). Close all surface valves and leave the well shut in. Insure well is dead. Monitor the break time of the last sample collected. Rig down pumping equipment. After the frac treatment there is a possibility of proppant in the wellbore. Rig up slickline and RIH with a sinker bar to insure the perforations are clear. Tag bottom to identify the amount of proppant in the casing. Rathole should be sufficient to prevent proppant from covering the perforations. If the bar tags proppant in the perforation interval then GIH with bailer to remove proppant from the well to clear the perforation interval. Use the tubing bailer with sufficient barrel length. Rig down slickline unit when complete. Page 5 Proposed ESP and Tubing Runninq Procedure: · MU ESP assembly on 2-7/8" tubing as illustrated on the attached Otis completion guide. Strap and record the length of each component. Run a standard Centrilift motor centralizer for 562 Series motors and 7", 26 #/ft casing on the bottom of the motor. · RIH w/ ESP no faster than 30' per minute. RIH w/ sliding sleeve in open position. Maintain sufficient hydraulic pressure on the control line while RIH to maintain valves in the open position. Attach two cable bands per joint. Attach additional bands above and below each cable splice. Set the bottom of the motor at 7520'. · Locate packer and safety valves such that the tubing retrievable SCSSV is at a depth of 500' or greater. Packers should be pinned to begin setting at approximately 1100 psi. · Pump 55 bbl of diesel down annulus for 1800' of freeze protection prior to setting packer. · RU slickline and RIH w/ plug and set in "X" nipple located below packer. Pressure up to 1000 psi. Set packer by gradually increasing pressure from 1000 psi to 2500 psi in 500 psi increments. Retrieve plug and POOH. RD slickline. · Pump 11 bbl of diesel down tubing for 1800' of freeze protection prior to closing SSSV's. 0 Bleed off control line pressure to close the annular vent valve and SCSSV. Pressure test the packer and vent valve system w/ 500 psi of annular pressure for 10 minutes. Bleed off pressure. 8. ND BOP's. NU tree· RD and move to next well. Await surface facilities connection for production· Prepared by' ~-~-~_.~~ ~ / ~//~( (? C. Van Lineberg~.j~ Sr. Prod· Engineer Reviewed by: Approved by: Marc Shannon Supervisin~ Prod. Engr. / · 4 . / .', } D. E. Howell Production Supt. cc: DEH, PMS, MPU Sr. Fro. (2), CVL, Original to File: L-2 Well File Page 6 ENTRILIFT EQUIPMEN , QUOTATION A Baker Hughes company 200 W. Stuart Roosa Dr. · Claremore. Oklahoma 7401 7 · I918) 341-9600 F'. 4..'9 DATE 8-03-90 . PRESENTED BY S. }{ester CONOCO, [NC, - 3'20I '~C~ Street' -- AncHorage, AK 99'503 , ._ -- '~TTN: Van Line.bet ge .r.. , WELL NA~'4E': L-2 'F'~'ELO N'AM~ Kupa~k - LOCATION: Deadhorse, AK , , _ ,,, _ mm _ , _ . . ,, _ . - , . ,, m - iii . SP. GR, B.H,T. 175 G.O,R. 145 NET LIFT .97 PERFS Below mir. PRIMARY VOLTAGE ..... ~---CA$1N G O.D. 7" 48O SURFACE PSI 8E'1'1'1NG DEPTH H REQ. SURFACE VOLTAGE ~ REQUIRED KVA TUBING SIZE 2-7[8 THREAD 8rd ~RtCT~ON LOSS TD.H. 9aries [~ VARIABLE FREQUENCY MOTOR H.P, I00 :RATING VOLTAGE 2145 SER~ES 562 60 HERTZ '-' 50 HERTZ AMPERAGE 27 NO. PCS. MODEL [~l~ LENGTH 12.0 PUMP STAGES PUMP INTAKE 230 TYPE FC-650 HSG, NO. I2 NO. PCS, SERIES 400 MODEL FPU LENGT~ 19,2 SERIES MODEL L~NGTH 842 582 PUMP DSOHRG. SERIES MODEL LENGTH (]ON N, GAS SEPARATOR SERIES 400 MODEL FRSX LENGTH 2-;-8~)' SEAL SECTION SERIES 513 MODEL O~B-i LENGTH 6,3 POWER CABLE AWG TYPE L E NGTH ARMOR FLAT CABLE SERIES 544 FLATaUARO~ TYPE KT-3 _ENG;'~ 35 ' ARMOR Galv. Adaptor 400 x 513 CABLE CABLE BANDS SWAGED NIPPLE CHECK VALVE DRAIN VALVE EQUIPMENT COATING: MOTOR CONTROLLER ACCE880RIES INCLUDE; TYPE LENGTH MOD EL SiZE VOLTAGE OVERLOAD ~ UNDERCURRENT S.D. ~, RECORDING AMMETER AUTO RESTART '_" LIGHTING ARRESTE~ 1'2. OTHER VARtABLE FREQUENCY CONTROLLER: 200 TRANSFORMERS SIZE KVA ICS · TYPE PRIMARY TAPS SECONDARY TAPS _ KVA ,,, VARIABLE FREQUENCY TRANSFORMER 200 JUNCTION BOX fVENTED-SAFETY~ 5 KV TUBING HEAD PR/) Downho Package PHD Inductor Package CONOCO Mods 75 ' ' 263 CABLE GUIDE CABLE REEL NO. REEL SUPPORT SHIPPING CASE QTY. SIZE Si'iiFRiNG CA$t~ QT'(, SiY. E SHIPPING CASE QTY. SIZE SHIPPING CASE QTY. SIZE ,NOTE: SERVICING EQUIPMENT MAY aa RETURNED FOR 100% CREDIT WITHIN 6 MO. SUBJECT TO A t~EPAIR EQUAL TO 25% OF THE LIST PRICE. ;~,,',~.1~,.' T ~ ~ ('-"-'FI'rRL')-'~ ~' F_ .'-.'. .=_ ~'¢¢ ~., T~E ~ ~'~1'~? TO tJ'~l~ FAC..T.'),4',' ¢~E,"ON[,IT,0%c_t', CART'.-; % ',~.F ~,%.%:~,h415L'¢ .~)1- . ,,3 ¢-,~%,.:",Dj~.; r 5 ~1 TEI4MS-t~F T '-, Ev,*,~'f · ft 8000 CONOCO MILNE POINT VSC System Performance j '~ ~" L-2 ?000 6000 ~000 1000 100 200 300 400. . 500 . 600 700 800 900 1000 t !00 1200 1300 BPD I .... PUMP ..... i ' ~ ! % (60 4 -] PREPARED FOR: Conoco Inc. ~ON OF: Mr. Van Lineberger FIELD NAME: Milne Point WEI~. NAME: L Pad "ESP" Completions CASING: 7" ~9~LB L-80 5TC TUBING: 2-7/8" 6.4 LB EU 8RD x 2-3/8" 4.6 LB EU 8RD ~: 432/1001/01/90 IIRTE: September 17, 1990 PREPARED BY: Ray Chavers - Anchorage, Alaska (907) 261-7780 2-7/8" 6.4 lb EUE Tubing Conoco Supplied Electric Cable - Size #2 1/4" Stainless Steel Control Line. 0.049" Wall ~lickness x 600' Length 316Material (P/N 22 SXX 31060) 2-7/8" 2.313" Otis "FMX" Series 10 Tubing Retrievable "Non-Equalizing" SCSSV, Flapper Closure. H2S Service. Meets NACEMR-01-75, 2-7/8" 6.4 lb EU 8Rd BxP. Max. Setting Depths 1000' (P/N778 FMX23111-E) 2-7/8" 6.4 LB ~J 8Rd Pup Joint W/Couplir~ L-80 Ommbination Coupling 2-7/8" EU 8 Rd x 2-3/8" EU 8 Rd BxB P-105 IoD. 2.44" 2.313" 2.44" 2.44" B1-W Power Cable Feed ~nru For No. 2 Round Cable. 100 AMP, 2400 Volts, 4 KV Rated. Field Attachable Male Connector and Power Feed Thru with a 20' Electric Cable Pig-Tail. (P/N 12 OD 1225) Tubing Seal ~ Adaptor 1.97" 2-7/32"-14 UNS-2 x 2-3/8" EU 8Rd BxP (P/N 12 O 6722) Otis Annular Vent Valve 1.83" 3,000 psi W.P. Setting Depth 540 ', 2-3/8" EU 8Rd BxP (P/N 78 AVS 2001) 2-3/8" 4.6 lb El3 8 Rd 1.99" Pup Joint P-105 OoDo 3. 668" .25" 4.76" 3. 668" 3.668" 2.25" 2.62" 3.09" ECC. 3.69" 3.06" 600' 7.0' 6.0' .6' 23' 1.8' 2.61' 8.0' ~-~qATE: September 17, 1990 11. Otis "RDH" Dual Hydraulic Retrievable Pr~d. Packer 7" 26-32 lb 2-3/8" EU 8Rd Box x Pin - Primary and Secondary. Long string Set. Hanger Type. Std. Service (P/N 12 RDH 7003) 12. 2-3/8" 4.6 lb EU 8R~ 1.99" Pup Joint W/Coupling P-105 13. Otis "X" Selective Landing Nipple W/Coupling P-ll0 (Nipple P/N 11 X 18700-A "Blank" 5b_read Connections for 2-3/8" EU 8 P~ PxP)* a. 2-3/8" 4.6 lb EU 8Rd Coupling P-105 14. 2-3/8" 4.6 lb EU 8 R~ 1.99" Pup Joint W/Coupling P-105 15. Adaptor 2-3/8" EU x 2-7/8" 1.97 EUE BxP P-105 ** 1.94" 1.94" Sec. 1.875" 17A. 16. 2-7/8" 6.4 lb ~JE Tubing 2.44" Conoco Supplied 17. Otis circulating Ball 1.29" Catcher Shear Sub. Shears at 1,000 psi Diff. Pressure. "Blank" ~nread Connections for 2-7/8" ~JE BxB)* Option to It~ 17 2-3/8" Otis 'XA' Sliding 1.875" Side Door (Opens Up/Closes Down) Not Shown on Drawing 18. One (1) 2-7/8" 6.4 lb EUE 2.44" Joint of Tubing or Pup Joint-Conoco Supplied 19. Electric ~ible Pump o.no 5.95" 3.06" 3.06" 3.06" 3.06" 3.76" 3.668" 3.668" 3. 093" 3.668" PA~E2 7.1' 2.0' 1.0' 4.0' .6' .80' 3.0' } -I00.0 , ~P__< MV > SGR < G~PI ) 0,0 ~O.~C~ ~op,.oo 76 · (5000.0 0.0 ......................... ~P~ ........................ · 80000 2000.0 SFLU(DHMM) .80000 2000.0 IDPH<DHMM) .20000 ,, 2000,.0 I<---SFQ <---IMQ <---IDQ 77 Made By C_._ v"~ Checked By Page of Conoco Inc. Calculation Sheet Interoffice Communication TO: FROM: ~ ->~-> CVL DATE: October 11, 1990 SUBJECT: MPU L-2, L-l, L-5, L-6 Completion Procedures - Summary of Changes The procedures are basically the same as the L-3 procedure. The frac design has changed slightly. These designs go up to 12 ppg proppant. Also, the gel concentration has been increased from 40 to 50 # loading. I've attached a 40 # L-2 design so that you can see the benefits of going to 50. Apparent viscosity increases from approximately 200 to 300 cp at our temperatures with this revision. I am still working on Proposed and Blank Well Schematics. them Mondayish. I'll circulate If we see anything that calls for an adjustment from well to well as we progress, I'll propose addendums. As of now, our plan is to move EWS to L-5 and then L-6 upon completion of the L-3. Pool will rig up on L-2 and then move to the L-1. The Pool rig is better equipped (rotary table, etc...) to handle the L-1. The Pool rig will then go to H-Pad and EWS will kick off the workovers and possibly knock out G-Pad. Let me assist you should you have questions. C~~Va~ Lineberger Sr. Prod. Engr. o , CONFIDENTIAL FIGURE I EXPLOSIVES F~eld Sa~et~ Procedures Schlumberger P]t~X)]~PA~FrUR~ CH~C~ (~') Verify that Casing-to-Ril Voltage Monitor 1. Che~k to nee that perforetin~ less than 0,25V. equipment inlo~ded~ndofp~oper (h) Clear line of fire of all size nnd de~'r~ptlon, personnel. 2. Check to nee Omt pre~ure control {i) Attach CST or FT to c~ble equipment /s complete and of head and proceed ~n hole. proper ~ize. {j) Or attach Shar~hooter or 3. Check to ~ee if open hole 1o~ are BST to collar tocntor and &variable for proper depth contt~fl, cable heed. Proceed in ho/e. 5. Arming SC and SCE Gun~ ARB~AL AT LOCATION ia) Clear line of fire oi all I~r~onnel. 1. Hold spot sa/ety meeting. (b) Check contactor 2. Hold consultation with client if _po.~. able po~ible. (c) Trim contac~or prlmacord. 3. Check well are~ for hnzarda and (d) Insert blnnt~n~ cap in Bla~t- correct when necemary, in~ Cap Safety Loadtng Trim wire lead~. FY~f-l~ S~ A.ND (e) Connect binatm~ c~p' lead~ to OPERATIONAL ROUTINE ~n t~nd 1. No smoking except in permtm~b/e ( f ) ~emove bl~ttn~ iron Safety Load:mt areltl. ~mokmg mlterm~l to 50 cramp to pmmacord stored when teaVtn~ the~e areaa. ]~]nnttn~ Cap cr~nv~n~ 2. l~i~ up cnble, l~.emove ri~ wimnl (~) Pre,are ~un ~or water u~nt that m/Iht contact cable. .~at. 3. Check rig and Schlumberger umt (h) Proceed into for stray voltage. El/mmate if 6. Ope~ntwnaA Procedure ,n Hole pre~ent. [nata/l safety groundtng (a) At ~00' depth, turn on &aietv strap and recheck. Insta/J Casmg- sw,tch. ,t. art AC generator. to-Prig Voltage ~Vlonitor. Do not Watch casing coLlarw to proceed with operation d reeidu~tA tom. Tie ,n and re:om collar voltage is tn excess of 0.25V. 4. Prepare to attach explceive dev/ce. (h) Poettion ~un and shoot. (a) Turn olf safety swi'tch and (c) Come o~t of hole---~tol~ at g/ve key to r~g door o~rator. 100' and repeat ~atetv re,u- (b) Shut o~ AC generntor. Ia,on C-4 ia through (c) Turn off main circuit (d) Turn o/~ USP. PSP. GSP: D. COMPLETION OF ;OB etc. panel sw~tchen. I. Check to see that all equipment (e) Disconnect GNP papal and brought to the well ,s loaded on other panel- not used for truck to be returned to District. shootmg operation. (f) Turn o/f aLI radio trane- 2. Police the area for ~r,macord trotters, remnants, char~es, trnnh, etc. ~mmmmmmmmmmmmmmmmmmmmmmmmm~ SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2t 75 PLEASE REPLY TO SCHLUMBERGER WELL SERVICES J~'~'CV 1 ~. ]~g~ Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention' Van Lineber__ger Gentlemen' Enclosed ore 2 Bi. prints of the Compony CONOCO, Inc. GCT, Run 1, 11/8/90 Perforation Record,, Run 2, 11/8/90 on' Well Milne Point Unit L-2 Field Milne Point Additional prints are 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 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. _6 Desta Driye Midland, TX 79710 Attn: John Carrol *(915/685-5600) _l~tL_prints, 1RF Sepia Chevron U.S.A. =11111 South W~lcramt_ _Houston; T~wm~ 770qq Attn: ?ri scilla MacLeroy 7713/561-3652 /Alaska Oil & Gas Conse~'rv~tion / Commission ~3001 Porcupine Drive ~Anchorage, AK 99501 ~t~: John Boyle The film is returned to Conoco, Log Library. We oppreciote the privilege of serving you. _ prints prints RECE"' IVEL) NOV 1 4 !990 prints Alaska Oil & Gas Cons. Commission Anchorage Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M, Saalwaechter E)ISTR ICT MANAGER SWS-- 1327-F REPORT OF SUNDRY WELL ("--,.OERATION p, I r, IN l~)perations performed: Operati,,..,utdown __ Stimulate __ Plugging __ ' Perforate __ - "' ~ Pull tubing __ Alter casinc~ __ Repair well __ Other X' 6. Datum elevation (~'F'-~r KB) 2. Name of Operator Conoco, Inc. 3. Address PO Box 340045, Prudhoe Bay, AK 99734 5. Type of Well: Development ~ 56 ' KB MSL Exploratory __ Stratigraphic __ 7. Unit or Propedy name Service__ Milne Point Unit 8.Well number L-2 9. Permit number/approval number 90-6 10. APl number 50--029-21998 ,, 11. Field/Pool Kuparuk River Field 4. Location of well at surface 2072' FNL, 222' FWL, At top of productive interval Sec. 8, T13N, R10E, UM At effective depth Gyro Survey At total depth Not Presently Available feet 12. Present well condition summary Total depth: measured true vedical 7936 7335 * Effec~vedepth: measured 7808 truevedical 7244 * Casing Length Structural Conductor 8 0 ' Surface 5041 ' Intermediate Production 7 8 6 6 ' Liner Perforation depth: measured Size 13-3/8" 9-5/8" 7" N/A feet feet Plugs(measured) N/A Junk(measured) N/A Cemented Measured depth True vertical depth To Surface 301 bbls Class "E" 112 bbls Class "G" 54 bbls Class "G" 115' 115' 5076' 4949' 7901' 7321' trueve~cal * Note: TVD not Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) depths are based from Gyro. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure on MWD directional data, 0il & Gas Cons. Commiss[o[~ , AnchoraW 14. Prior to well operation Subsequent to operation N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run --To Follow Daily Report of Well Operations --% 16. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15188 Date 3/18/90 SUBMIT IN DUPLICATE Kuparuk River River Field - North Slope Borough, Alaska W.I. 100% Milne Point L No. 2 CONFIDENTIAL AFE 10-61-1191 API No. 50-029- Ak. Permit No. Elevation Location: 2,072' FNL, 222' FWL, Sec 8, T13N, R10E Umiat Meridian February 20, 1990 FINISHED MOVING IN RIG. NU & TEST DIVERTER SYSTEM. ACCEPT RIG @ 2200 HRS. UN-THAW STANDPIPE. JIM FOX PU BHA. Daily Mud Cost: $ Daily Cost: $ 3,038 Cumulative Mud Cost: $ 3,038 Cumulative Cost: $ FEBRUARY 22, 1990 CONTINUE DRLG F/1933' TO 3200'. TAKE MWD SURVEY, CIRC BOTTOMS UP, PUMP PILL. POOH. P/U NEW BHA. M/U MUDMOTOR, CHANGE AND ORIENT MWD RIH 450'--TEST RUN MWD/MOTOR. RIH. POOH 9 STDS TO RETRIEVE DP SCREEN. RIH. ORIENT TOOLFACE. DRLG F/3200' TO 3260'. CIRC AND COND HOLE. DRLG F/3260' TO 3432'. POOH L/D 5 SINGLES. REAM F/3274' TO 3316' TO REMOVE 5+ DEG DOGLEG. JIM FOX Daily Mud Cost: $ Daily Cost: $ 1,841 Cumulative Mud Cost: $ 6,831 36,827 Cumulative Cost: $ 222,157 FEBRUARY 23, 1990 CONTINUE TO REAM F/3316' TO 3432'. DRLG F/3432' TO 4192'. TAKE DIRECTIONAL SURVEY. PUMP PILL. SHORT TRIP 10 STDS. DRLG F/4192' TO 4509'. JIM FOX Daily Mud Cost: $ Daily Cost: $ 2,710 Cumulative Mud Cost: $ 9,755 56,782 Cumulative Cost: $ 278,939 FEBRUARY 24, 1990 CONTINUE DRLG F/4805' TO 5095'. CIRCULATE AND CONDITION THE HOLE. PUMP PILL. SHORT TRIP -SLM- TO THE DRILL COLLARS. JIM FOX Daily Mud Cost: $ 3929 Cumulative Mud ~[E ~ 13'6841 ..... Daily Cost: $ 51,369' Cumulative ~ ~'0,308 FEBRUARY 25, 1990 ~i~A¥ i l~ ]~gi.i1 · ~'~iasi(~ OJi & Ga~ Cons~ Commiss~ CONTINUE TO POOH FOR WIPER TRIP. ENCOUNTERED RESTRI~~a@ 1930'. STABILIZERS WERE SOMEWHAT BALLED UP. RIH. WORK TIGHT SPOT F/1900' TO 2000'. RIH TO 5095'. KELLY PU. CIRC AND CONDITION THE HOLE. PUMP PILL. POOH AND L/D BHA. NO HOLE RESTRICTIONS SEEN. R/U TO RUN CSG. RIH WITH 9.625", 36#/FT, J-55 ARCTIC GRADE, BTRS CSG. CIRC BOTTOMS UP @ JT #58. CONTINUE RIH WITH CSG. REPAIR PIPE LAYDOWN MACHINE. RUN THE LAST OF 117 (TOTAL) JTS OF CSG. CIRC AND CONDITION THE HOLE WHILE RECIPRICATING THE PIPE. JIM FOX Daily Mud Cost: Daily Cost: $ 2,814 Cumulative Mud Cost: $ 16,498 $ 134,378 Cumulative Cost: $ 464,686 FEBRUARY 26, 1990 CONTINUE TO CIRC AND COND THE HOLE WHILE RECIPRICATING CSG. PUMP PREFLUSH (40 BBL SEPIOLITE & 50 BBL WATER) FOLLOWED BY FIRST STAGE CMT (178.1 BBL PERMAFROST E AND 96.6 BBL CLASS G). DISPLACE WITH 381.7 BBL MUD. BUMP PLUG. FLOAT HOLDING. PRESS CSG TO 2750 PSI- OPEN STAGE COLLAR. CIRC AND COND HOLE PUMP 15 BBL WATER FOLLOWED BY SECOND CMT STAGE: 188.1 BBL PERMAFROST E AND 15.1 BBL CLASS G. DISPLACE WITH 132 BBLS MUD. BUMP PLUG-CLOSE STAGE COLLAR HELD. NOTE: FULL RETURNS BOTH STAGES-65 BBLS OF CMT. RETURNS ON SECOND STAGE CSG SHOE @ 5076'. STAGE COLLAR @ 1807'. DRAIN BOPE. BACK OUT LANDING JTR/D CSG AND CMT EQUIPMENT. N/D DIVERTER ASSEMBLY. N/U WELLHEAD AND BOPE. TEST BOPE. REPAIR LEAKING KILL LINE HCR VALVE. JIM FOX Daily Mud Cost: Daily Cost-. $ 1,308 Cumulative Mud Cost: $ 17,806 $ 130,619 Cumulative Cost: $ 595,305 FEBRUARY 27, 1990 REPLACE HCR VALVE ON KILL LINE W/MANUAL VALVE. COMPLETE TEST OF BOPE. WITNESSING BY AOGCC WAIVED BY L. SMITH. REPLACE AIR BOOTS ON FLOWNPL/FLOWLINE. INSTALL WEAR BUSHING. P/U AND TEST NEYRFOR TURBODRILL. M/U BHA. TIH TO 1700'. CIRC. BTMS. UP. SLIP AND CUT DRLG. LINE. TIH TO T/ CMT.@ 1799'. DRLG. CMT.F/1799' TO 1803'. DRILL OUT STAGE COLLAR F/ 1803' TO 1807'. TIH. TAG CMT.@ 4984'. CIRC.BOTTOMS UP. PRESSURE TEST CSG TO 1500 PSIG FOR 30 MIN. OK. DRILL OUT FLOAT EQUIP. DRILL 10' OF NEW HOLE. PERFORM EMWTEST TO 13.2 PPG @ 1100 PSI. DRLG. F/ 5105' TO 5184'. Daily Mud Cost: $ Daily Cost: $ 1,988 Cumulative Mud Cost: $ 19,794 39,736 Cumulative Cost: $ 635,041 FEBRUARY 28. 1990 DRLG F/5184'-5868'. SURVEY. SHORT TRIP 12 STDS. (HOLE IN GOOD SHAPE--NO PROBLEMS. ) DRLG F/5868 '-6597'. SHORT TRIP 8 STDS. (HOLE IN GOOD SHAPE --NO PROBLEMS. ) Daily Mud Cost: $ 5,756 Cumulative Mud Cost: $ 2.5,550 Daily Cost: $ 48,828 Cumulative Cost: $ 686,011 MARCH 1, 1990 DRLG F/6597'-7162' WHILE INC. MW F/9.5 TO 10.0 PPG. BOB DRIL -- ALL MEN AT STATIONS IN I MINUTE. SHORT TRIP 7 STDS. HOLE IN GOOD SHAPE. INDICATIONS THAT WE P/U A BALL ACROSS STAB IN BHA WHEN BACK ON BOTTOM W/PUMPS ON TRYING TO PACK OFF. DRLG F/7162-7344' WHILE INC. MW TO 10.1+ Daily Mud Cost: $ 5,161 Daily Cost: $ 52,345 Cumulative Mud Cost: $ 30,711 Cumulative Cost: $ 738,356 MARCH 2, 1990 DRLG F/7344-7354' SERVICE RIG AND MWD 'SURVEY DRLG F/7354'-7480' WHILEINC.MW F/10.i+ TO 10.2+, (NOTE: STARTED LOSING MUD TO HOLE.) CBU AND MWD SURVEY (HOLE IS TAKING 10 BPH) SHORT TRIP TO SHOE (CALC HOLE FILL = 17.5 BBLS, ACTUAL = 30 BBLS) RIHTO 7435', WASH AND REAM LAST 45'. OVERALL, NO HOLE PROBLEMS DRLG F/7480'-7766' SHORT TRIP 10 STDS (HOLE IN GOOD SHAPE -- NO PROBLEMS. CALC HOLE FILL = 7 BBLS ACTUAL = 10.5 BBLS. Daily Mud Cost: Daily Cost'. $ 4,401 Cumulative Mud Cost: $ 35,112 $ 48,933 Cumulative Cost: $ 787,289 MARCH 3,. 1990 DRLG F/7766'-7812' TOOK 2 BBL GAIN, STOP PUMP, MONITOR WELL, WELL FLOWING, CLOSE IN ONE PIPE RAMS, DP AND CP = 0 PSIG OPEN RAMS AND CIRC OUT TRIP GAS -- TOTAL CIRC=4200 STKS, STOP PUMPS AND MONITOR WELL -- STATIC. DRLG F/7812' - 7896' (PROPOSED TO). CIRC AND COND. HOLE (5500 STKS). SHORT TRIP TO SHOE (HOLE IN GOOD SHAPE -- NO TIGHT SPOTS). CALCULATED HOLE FILL - 21 BBLS, ACTUAL = 24 BBLS. RIG SERVICE. RIH 30 STDS ( NO BRIDGES -- 17' OF FILL ON BOTTOM), CBU AND CHECK TO ENSURE SHAKERS CLEAN. POOH F/LOGS, SLM IS GOOD, L/D TURBINE & MWD, MONITOR HOLE -- STATIC. R/U SCHLUMBERGER TO LOG WELL. RUN IN HOLE W/NGT-CNL-LBT-DIL TOOL TO 7900' LOGGERS DEPTH -- LOGGERS WERE ONLY ABLE TO GET DOWN TO 7860' ON 2ND PASS. Daily Mud Cost: $ 3,418 Daily Cost: $ 43,146 Cumulative Mud Cost: $ 38,530 Cumulative Cost: $ 830,405 MARCH 4, 1990 R/D LOGGING EQUIP. -- CLEAR FLOOR AND SERVICE RIG. M/U NEW BHA AND RIH TO 7883' -- 13' OF FILL. WASH AND REAM 7838 '-7896' DRLG F/7896' - 7936' SHORT TRIP 6 STDS (P/U WT. = 40K OVER, S/O WT. IS OK, 2' FILL). CIRC. AND CONDITION MUD POOH L/D DRILL PIPE CHANGE PIPE RAMS F/5" TO 7" LAY DOWN BHA PULL WEAR BUSHING, R/U CSG CREW, ANKD HOLD 15 MIN PREJOB SAFETY MEETING. RUN 14 JTS OF CSG, CHANGES CREWS, AND HELD 15 MIN PREJOB SAFETY MEETING. Daily Mud Cost: $ 3,285 Daily CoSt: $ 76,958 Cumulative Mud Cost: Cumulative Cost: $ 41,815 $ 907,363 MARCH 5, 1990 RUN 182 JTS OF 7", 26#,L-80,BUTT CSTG., CIRC LAST TWO JTS. IN HOLE, AND M/U HANGER AND LANDING JT. CIRC. 1.25 TIMES HOLE VOLUME AT 5.5 BPM WHILE RECIPROCATING CASING STRING 15' -- P/U 230,000 LBS. (26000 LBS DRAG) AND S/O 160,000 LBS. PUMP 670 BBL SEPIOLITE SPACER AT 6 BPM (10 MIN. CONTACT TIME). & PRESSURE TEST SURFACE LINES TO 3500 PSIG -- OK. CEMENT 7" CSG (51,5 BBLS CLASS G), BUMP PLUG W/3000 PSIG & HELD PRESS. FOR 10 MIN. -- OK. RELEASE PRESS. -- FLOATS HELD. B/O LANDING JT. AND &/D CSG CREW CHANGE ELEMENTS IN PIPE RAMSD F/7" TO 5" INSTALL PACK OFF, N/D BOP'S, INSTALL TBG HANGER & N/D TREE. START INJECTING MUD INTO 7" X 9 5/8" ANNULUS AND RIGGING DOWN RIG. Daily Mud Cost: $ 3,756 Daily Cost: $ 97,557 Cumulative Mud Cost: Cumulative Cost: $ 45,512 $1,004,520 MARCH 6, 1990 FINISH PUMPING MUD INTO 7 5/8" X 9" ANNULUS. CLEAN RIG AND DISPLACE ANNULUS WITH 60 BBLS DIESEL FREEZE PROTECTION. FINISH CLEANING MUD TANKS AND RELEASE RIG @ 0800 HRS. BEGIN MOVE TO L-6. Daily Mud Cost: $ 0 Daily Cost: $222,401 Cumulative Mud Cost: $ 45,512 Cumulative Cost: $1,234,212 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 April 5, 1990 Mr. Mike Minder Alaska Oil & Gas Conservation Commission 301 Porcupine Drive Anchorage, AK 99501 Re: Letter of Application Dear Mr. Minder: I am requesting shutdown of well operations for the L-2 well until we can compact the new pad enough to get a workover rig on location and begin completion operations. This will happen later in the summer. Included is the Form 10-403 and a Form 10-404 with a copy of the Daily Reports of Well Operations will follow the approval of the 403. The cement plug was bumped, casing pressure tested, tree flanged up and tested, and the well was shutin. Sincerely, D. L. Mount joy Sr. Drilling Foreman RECEIVE[? 1 1 ]990 ,?~Iaska Oil & Gas Cons. C0mmiss~0n Anch0rag~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon __ Suspend __ Operation shutdown _.~ Re-enter suspended well __ Alter Casing __ Repair well __ Plugging __ Time extension __ Stimulate ~ Change approved program __ Pull tubing ~ Variance ~ Perforate ~ Other 2. Name of Operator Conoco, -mc. 3. Address PO Box 340045, Prudhoe Bay, AK 9973z 4. Location of well at surface 2072' FNL, 222' At top of productive interval At effective depth Gyro Survey At total depth Not FWL, Sec. 8, T13N, Presently Available 5. Type of Well: Development __X Exploratory __ Stratigraphic ~ Service __ R10E, UM 6. Datum elevation (DF or KB) 56' KB MSL 7. Unit or Property name Milne Point Unit 8. Well number L-2 9. Permit number 90-6 10. APl number 50-- 029-21998 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical 7936 7335 * Effective depth: measured 7808 true vertical 7244 * Casing Length Structural 80 ' Conductor 5041 ' Surface Intermediate 7866 ' Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) * Packers and SSSV (type and measured depth) feet Plugs(measured) N/A feet feet Junk (measured) N/A feet Size Cemented Measured depth 13-3/8" To Surface 115' 9-5/8" 301 bbls Class "E" 5076' 112 bbls Class "G" 7" 54 bbls Class "G" 7901' Note: TVD not RECEIVEP ~ueverticaldepth 115' 4949' 7321' i AY 1 ]99[) .~[Jaska.0il & Gas Cons. Commission ~ Anchorag~ depths are based on MWD Directional Data, from Gyro. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation July 5, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ..~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Senior Production Foreman Cc Date 3/18/90 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent for_m, ~quired 10- Approveo copy Returned Approved by order of the Commission [Approval No.~ ~ 'c~ ~ LONNIF C. gl~,flTI4 Commissioner Date ~'--I q _C~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE CONOCO, Inc. 3201 "C" Street, Suite 200 Anchora~e,.....AK 99503. A~ention: M,ar~ Shannon ~entlemen: Enclosed are 2 BLprints of the Compony CONOCO, Inc. Well Milne Point Unit L-2 Phasor DIL/Porosity/Raw Data/NGT, Cyberlook, Run 1, 3/3/90 Field Milne Point Aclditionol prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: GeorKe Lamb - OF 2018 I BL prints , 1RF Sepia OXY.U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol * (915/685-5600) County North Slope Stote. Alaska 1 BLprints, 1 RF Sepia CONOCO. Inc. 1000 South Pine Ponca City, O~ 74603 Attn: I,ng Library prints 1 BL prints , 1 RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy * (415-_ASA,Z~l-O00.~ ...A~..-ask~ Oil & Gas Conservation ': Co m io. 3-001 Porcupine Drive Attn: John Boyle The film is returned to Conoco, Log Library. We oppreciote the privilege of serving you. prints prints ~ ,..n '1t q !qqN Date: tvl~ ~ -~ Alaska 0ii & Gas Cons. Anch0mge Ve~ truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DIS;TR ICT MANAOIER 5WS-- 1327-F RECEIVED f':.!~,~ C,'i.t & ~:~.~ Cc:ns. ~u.~mission Anchma,ge STATE OF ALASKA ALASKA OIL AI~ Ga3 CONSERVATION BOPE Inspact:lon Repert HUD SYST...E745: Visual Audio Trip tank .............. Pit gauge Flo~ monitor .._ - J ......... Oas detectors ....... BOPE STACK; ,, ^nnular preventer r~aJce-~e~ve 1 vas AH-i I i f.e ve lyes Test Pressure DATE , Choke menffold Full oharge p,eeeure Pres~ after elo~ure Pump t~r ctoa press 2~ pslg , Full oharge press e~e1~a .... N~ ..... ~ p~lg Con~rols~ Re~te Blind ~LLY AND FLO~ aAF~Y VALV~: Upper Kelly ~ Teat preaeure L~er Kelly Te~ pressure ~11 type ~ Tell pres~uee Teat pressure ...... Number ~alvea pslg p$1g ...... , .... SeC ........... i I ____: .e., _.';_..-;, :- _ Number flanges Adjustable chokes ..... r --~ :~: .... · Hydraulically operated choke TEST RESULTS~ Failures ~ TeB~ ~tme bra Repa{e or replacement of felled equipment :o be mede wtthtn end Inapector/C~ss~on office nctlf{~. ,. days orig - AOOCC c - Operator · - Supervisor C.OOq (rev 05/17/89) i~$pector: ~. , ~ January 4, 1990 Telecopy No. (907) 276-7542 D F Rainwater Sr Production Foreman Conoco Inc Pouch 340045 Prudhoe Bay, AK 99734 Milne Pt Unit L-2 Conoco Inc Permit # 90-6 Surf Loc 2072'FNL, 222'FWL, Sec 8,.T13N, R10E, UM Btn~hole Loc 1277'FNL, 1728'FEL, Sec 7, T13N, R10E, UM Dear Mr Rainwater~ 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. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing betore drilling below the shoe of the conductor pipe. ~ V ~hatterton Chairman Alaska Oil and Gas ~onservation ~o~tssion BY O~ER OF THE COMMISSION jo Enclosure Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALAS: OIL AND GAS CONSERVATION ')MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill lb. Type of well. Exploratory Iq Stratigraphic Test [] Development Oil Re-Entry © Deepen~JI Service [] Developement Gas [] Single Zone~ Multiple Zone 2. Name of Operator 5. Datum ElevatiOn (DF or KB) 10. Field and Pool CONOCO INC. KB 35 feet Kuparuk River Field 3. Address 6. Property Designation Pouch 340045, Prudhoe Bay, AK 99734 ADL 25509 4. Location of well at surface 7. Uni't or property Name 11. Type Bond(see 20 ^^c 25.025) - 2072'FNL,222'FWL,SEC 8,T13N,RIOE,UM Milne Point Unit Blanket AttOP of productive interval 8. Well number Number 1350' FNL, 1550' FEL, SEC 7,T13N,RlOE,UM L-2 8086-15-54 At total depth 9. Approximate spud date Amount ]277'FNL,1728'FEL,SEC 7,T]3N,RIOE,UM January 20, 1990 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed 'depth(MD and TVD) property line at TD 912' feet 60' ~ 500'to L-3 feet 2533 7896'MD/7325'TVDfeet, 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)42)) Kickoff depth 3200 feet Maximum hole angle 33 0 Maximum surface 3200 ps~. At total depth C'VD) 3800 psig ................... 18. Casing program Sett. incj Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD' (include stage data) 30" 13 3?8" 48 H-40 Weld 80' '35 35 ]15 115 _+485 sks Permafrost C i2 i/4" 9 5/8" 36 J-55 BIRS 5111' 35 35 5145 5001~ +_601 sks Permafrost'E +l~b sks Ciass'G" 2nd St~ge_+472 sks Permafrost E +73 sks Class G o ~/~ ~ 26 L-80 BTRS 7868' co Jo io~o i~o ±3u~ sks Class G i9. To be completed for Redrill, Re-entry, and D a ~l~l~/~s. +180 ~k~ Pu~-,,,~ r'ost C Present well condition summary +60 bbl s Dead Crude Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured · feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ISn~ reframC;d, at e RECEIVED DE, 2 01989 Liner Perforation depth: measured A:iaska 0il & Gas Cons. true vertical Anchorage Pit Sketch X 20. Attachments Fili,n,g fee ~" Property"Pla,.t ~ 'BOP Sketch I~ Diverter Sketch'~ Drilling pr;:)gr'am '~, '" Drilling fluid program ~; Time vs depth plot ~ Refraction analysis ID Seabed report ID 20 AAC 25.050 requirements 21. I hereby certify tha-t~he foregoing is true and correct to '{he best of my knowledge Signed ~ zCC.¢A.--.j~ ' Title Senior Production Foreman., Dat~2/14/89,. Commission Use Only Perm~it Numb~ I APl number _ ! Approval date See cover letter .?¢__) .- - I 50-o2._~, - .~_//~;;~ {~ J O] / {')4 / q ~ for other requirements co[~"~l]tion'~-o-~-~ppro~,a'l Samples required '~ Yes ~ No Mud Icg requi[e,d' -C Yes .~No- Hydrogen sulfide measures ~ Yes ~ No DirectFona. I survey required ..~ Yes E3 No Required working~...L~,ssure_~or ~ .,~?.M~ ~ 3M; ~ 5M; [] 10M; ~E315M Other: Y 207/~~ ~.~.//~~ by order of Approvedb, ~,..~ ,~' ,L -.J~.~.~ Commissioner the commission Date.. .. Form 10-401 Rev. 12-1-85 t Sub~ . triplicate ,, , N O R T H VICINITY MAP I AS BUILT PAD L SECTION 8, TISN, RIOE, UtVlAT MERIDIAN LOCATION IN SECTION WELL : FROM NORTH LINE : FROM WEST LINE I : 1970' i 158' STATE PLANE GOORDINATES WELL. : NORTHINGS : EASTINGS . .. ......... ~.. ......... , ........... . .... ..... .~. · ....... ......... ... I ~ 6,O51, 499.2 ~ 544,758.7 : : ZONE 4 WELL ~ LATITUDE ~ LONGITUDE t9 9 ............ ; ................................ ' ................................ : 149° 58' 02" D~C ~ 0 , Gas Cons. ~o 'Anchorage THAT /$,LL DIMENSIONS AND OTHER DETAILS F. ,. gj.-'~.-., ARE CORRECT. '"-~ , FR' C ll~.,...[~ ~;,~ SURVEYED 0 · CONO 0 ~ ~,N · FIELD B~K CERTIFICATE OF SU R VF'¥OI:~: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ~O THAT .-- - THIS PLAT REPRESENTS A LOCATION SURVEY '.~ ~2 '... T 13 N R 9 E T 13 N R 10 E 1' 13 N R 11 E MILNE POIN' UNIT :, ~,, , u~ ~ ""~ "' ~ ' "' ...................... - ~" ' ~'~ .... ~ '~'-' ('~l:)®notee tl'lc, t ~umbe~l C,I-~VRO. ~.~ CONOCO ET AL. (3~ ~/~,,O~) ~AL (~ CONOCO ET &L, q.~ ~ Unit Bound.fy ,AOL,-3~97,17 12(~5,,AC, _ LDL CoNoCo. ET ^L 6/64 _ ADL-255Og 2533 JI.C ADL-47434 2560 AC ADL-47433 2~60 AC "ADL.~7432//~/68 AC~ ~'~ · , I IIIII I~ ..... ~ , . ,, , ,... ., C.I'Lc'vRoN C 0 ~/,OC.O, ,e'T/~/'h"'~ ~"~ / '"'"~ '~-'"" ~ CONOCO E:r A~," ~) CONOCO E'r + + -- . 23 24 19 2.0 .21 22 23 ~ 24 19 20(' 21 22 !ADL-25516 h'~ ADL-47439 ADL-3 158~ Jot.-:~Ise4e 1280 AC ADL-47437 2560 AC &DL-47436 2544~C 1280 AC .1260 ACI 6 A.DL-25514 2560 AC ADL-25515 2544 AC 12eo Ac ......... ~:'~:* 30 29j 28 27 26 · 25 30 29 ', ........ EX! ;IBIT A A~ : ~16 36 31 32 Mlle8 O ~ ~ ~ 2235AC 20 ~A~L-25~ 25eOAC ' ADL-25518 2560 AC ADL-28231 2555 AC - ' / iOHIO Merldlen,Alaike I 2 ~cele ii FRCM SALAM&NC(q$ MI,lO TROUGH HOLE I'ILL TANK I MUD CLEANER w~TER ~ HC-LE FILL V& .;UL'J C[NTRIFUG.r L"~G~' S~ER r4~x/la ;LL i .~.4fX CHAaGE CH^RGE AGI?ATO~ "-I/1"-- eUZT£RFLY V~-LV£ ~ GATE VALVE ,,~.(:~MUD GU~ ~..~..,Nv. PSv ~ - C~q A IN AlaC TI~ ~ ~CT~N V~VE ~C~CN Cg ( ~ V~L~ I~ drcf FLOW SHEET ._= AXELSEN INOUSTIMES LTD. EDMON TO~, ALBERTA :. PHONE (4~3.3) 465- fi,42 ...... ~,~i""'~- 1477-02 . MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING · FILL'UP FLOW LIN[ RECEIVED D~c 2 o t989 ?~,.~aska 0il & 6as Cons. Commissic: APl 50004 RAM lOP I$~J/1 · APl ~,OOOd I° lJJl 5000 TIG liD[ OUTL[TS U~ ~ SPOOL · / I$~/i" APl $0004 · '11' APl 5000 II · /,PI 5000e 3' .~Pi 50004 CSG :''' o . . Threaded .' · ' ' '' Connection ~ . · . I!.." -..' ii" "'; · ~.[,.~",,.', , · · .".~'; . ; .- , ,., '. ,. . · '''o'"i.;~' (2) (3) (~,) (5) R.O.P. stack size rating meets AP1 RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. BOP£ to be operated on each trip & pressure tested weekly. Hydraulic control system for BOP£ to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. Choke and kill manifolds shown separately to ~eet APl RP 53 class 5M requirements. KILL MANIFOLD ~ FROW MUD Pbmr FROM REMOTE HIGH PRESSURE -PUMP NOTE: I. RmRAULIC Ce~TROL STSTEU FOR 80~ ~ACK & g~NIFOLD TO INCLUDE (5~ STATI~ CCNTROL MANIFO~ L~ATED REMOTELY ~ITH ~0 PSI ACCUqULATOR 160 G~. RESE~IR ~ AUX. ENERGY SOURCE. SrA. ~NTROL ~A~IF~ PLUS ~RIAB~ CHOKE ~NT~L TO BE mCATED ON R~G FLOOR. Z K~LL a CHG~ ~ANIFOLDS ~ MEET A~ RPS~ 5~ S~S. --... REMOTE PRESSURE GAGE SENSOR HYDR~UMC CONTROLLED REMOTE OPERATED IR DRILLING SPOOL HYDRAULIC CONTROLLED D,{OTF OPERATED ]~ REMOTE PRESSURE · GAGE SENSOR · ADJUSTABLE CHOKE ADJUSTABLE CHOKE CHOKE MANIFOLD __ VARIABLE CHOKE CONTROL 19. 1 TO ATMOSPHERIC MUD/GAS SEPARATOR TO SHALE SHAKER RE¢£'I"./EO DE e 2 0 iriS9 G~s Cons. Anchorage CHOKE 8~ KILL UANIFOLDS FOR ClS/8'~ 8~ 7" OD CASING BOP STACK SOP ~ANIFOLD LAYOUT- CONOCO, INC. : CONOCO, INC. IdlLNE POINT UNIT DIVERTER STACK FOR 13 318' -CONDUCTOR §IV[RTCR OglCK CO~IN[C! ASS[lilLY SI, V[R '$U! A$$[MBLY STARTI~O H[&O RECEIVED Oil & ~.s Cons. Anchorage 1. The hydraulic control syste~ will be in accordance with APl specifications and A~ requirements. ~. The HCR valve will open ~hen the preventer closes. A single 10" relief line will pun off of the drilling spool HCR valve and will have a targeted downstream tee for downwind diversion. Valves on both sides of the tee will be full opening and linked together to enable one to always be open and the other to be closed. SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-2 Conoco Inc. 3201C Street, Suite 200 Anchorage, AK 99503 I · A· B· Ce II. Ae B· De III. Casing and Cementing Program The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with +480 sacks Permafrost type "C". The 9-5/8" surface casing will be cemented in 2 stages with the first stage using +_601 sacks of Permafrost "E" cement followed by +_195 sacks of Class "G" cement. A DV tool will be placed at +1800' MD. The second stage will contain +472 sacks of Permafrost "E" cement followed by +73 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. The 7" production casing will be cemented in two stages. The first stage will consist of +-302 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of +180 sacks of permafrost type "C" cement followed by _+60 barrels of Dead Crude pumped down the 7" x 9-5/8" annulus. Drilling Fluid Program 0-500' 9.0 ppg freshwater spud mud. 500'-5145' g.O ppg-9.8 ppg freshwater spud mud. 5145'-7000' g.o ppg-g.5 ppg dispersed. 7000'-TD 10.4 ppg dispersed. RECEIVED Oil & n~. · Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field. The mud system will be low solids, non- dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at TD will be 10.4 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 test will be performed as per State Regulations. 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 L-1 with 27' of closure at a depth of 3540'. Dead crude will be placed in the 7" x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed after releasing the drilling rig. A. Drill a 30" conductor hole to +80' and set 13-3/8" conductor. B. Drill a 12-1/4" surface hole to +4563' TVD (5730' MD) and set g- 5/8" casing. C. Drill an 8-1/2" production hole to 9908' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL O' O' Gravel 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3597' 3600' "K" Sands 1-1-4 9.2 25 15 65 14 3686' 3690' "M" Sands 1-1-4 9.4 25 15 65 13 3942' 3958' "N" Sands 1-1-4 9.4 25 15 65 12 4114' 4130' "0" Sands 1-1-4 9.4 25 15 65 12 6579' 7009' Sea Bee 1-1-4 10.2 8 12 40 10 6801' 7310' Kup Top 1-1-6 10.2 8 12 35 5 7025' 7539' L K (1) 1-1-6 10.2 8 12 35 5 7044' 7559' L K (2) 1-1-6 10.2 8 12 35 5 7225' 7796' B L K 1-1-6 10.4 6 12 35 5 7325' 7896' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. RECEIVED DEC2 e, i9B9 ~>ias~ BiI.& G~.s Cons. ~nchora[Io A. B. C. D. E. F. G. H. I. J. TOTALS TIME ESTIMATE Rig Up Drill Surface Hole Run Surface Casing and Cement Drill Out and Test Drill Production Hole Log Open Hole Condition, POOH, L.D. Run Production Casing Cement Production Casing Move Rig Hours Days Cum. Days 10 0.42 100 4.16 4.58 36 1.50 6.08 8 0.33 6.41 120 5.00 11.42 36 1.50 12.91 20 0.83 13.74 10 0.42 14.16 10 0.42 14.58 10 0.42 15 360 15 15 RECEIVED WP/PERMSUPP MILNE POINT~)NIT WELL -1 -2 -4 -5 -6 -7 -8 -9 10 11 Rate vs. Depth 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 18.00 RIG DAYS HORIZONTAL PRO 'CTION SCALE 1 .IN. - lO00 FEET CONOCO, Pad L, Wel ! No' 2 Revleed Pr'opoes MI Ine Polni: Unli:, Nor'i:h Slope, TD LOCATI:ON ~ 1277" FNL, 17'28' FEL SEC. 7,, T13No R IOE T ARG'ET LOCATI:ON' 1,350' FNL. 15,5~)' F'i~L SEC:. 7'. T13N. R10E 2000 _ Z CD , 1000 _ ~ 1000 .. WEST-EAST 2000 1 000 i 1000 ! TARGET TVD-7,025 Tt'ID-7,$4.0 DEP- I gl NORTH 722 WEST 1772 SURFACE N 67 DE(; 50 MI N W 191:3' (TO TARGET) SURFACE LOCATION ' 207'2' FNL. 222' FWL SEC. 8. T13N. RIOE . - CONOCO. Ino. Ped L. Wel I No' ,f~ Revised Proposel HI Ine Point Unl< North Slope, Aleske 0 . RKB ELEVATION~ 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ 8000 KOP 2 Io 14 18 22 TVD=3200 TMD=3200 DEP=O BUILD 2 DEO PER 100 FT 30 32 EOB TVD=4746 TMD=4833 DEP=453 ; 9 5/8" CSO PT TVD-5000 TMD-5145 DEP=62 AVERAGE ANGLE 32 DEG 39 HI N TARGET / TOP KUP SNDS TVD=7025 TMD=7540 DEP=1913 TB / 7" LINER TVD=?325 TMD=7896 DEP=2106 I 1000 VERTICAL I 2000 SECTION I 3000 5O lO0 150 2OO i I I , i 250 I ~00 350 I 400 1850 -- . _. 1900 - J ! 1 950 ~~. -. 2000 ~~ '~4~o0 2050 - 2100 2150 _ 1 I ! i I I ~- 0 '" ~900 ~ 5500 ~ "'~57'00 "'-~r..oo % ' sgoo /ssoo , , _ i I i 50 1 O0 1 50 200 250 I 300 /°"~ 1 O0 /'/900 · 500 j I 35O i 400 _ 1 85O _ 1 900 _ 1 950 2000 2O50 _ 2100 _ 2150 ..**-***.;.**~..: ~>.--':~'** (..?. _~ol'~C0 · '*":°* NOCO, IHC ,, ~ATTH: LUCY FEL.I..~R3' · . '..~..-.. t' op 0 BOX HOUSTOH, TX 772i 'p O BOX PUEBLO, ' COt,O, 8 P~RT: SATISFACTORY TO FURNZSH GRADE K-55 COUPLINGS ON ENT~R~ OROSR INSP ELECT'ROMAGN~T~C SPECIAL EHD AREA tOOl: THREAD GAUGIHG NO 0VERRGE DEgZRED,.~'HIP ~UnNT~¥Y ORDERED ONLY. ,TE:E SPECIAL iNSTRUCTZOH$ CONOCO MPU OPS CTR 907-659-6390 ~CONOCO INC.~CI}N$II;NED: BN 'r AGENT , SEATTLE ~ WA.RULE 11 ~ QFOR FURTHERANCE TO ALAgKR AN(;HORAGE,AK TO {tNt. OADA DEL ~ PREF'A 4637, STEEL CORPORATION P.O. Box 3 ! 6 Puoblo, Colorado 81002 Customer order~ 907-1£07~9 · - --T : ..... =: '-- 33899 47330 0.24 0.93 .009 .006 .19 .19 .07 0.05 .013 .01S .000 .0o04..0o4 .00[~. 0.23 0.99 .014 .004 ,22 .24 .07 0.0~ .012 .0l$ .000 .0005 .004 .0014 0.26 0.97 .013 ,003 .23 ,24 .07 0.08 ,01l .015 .000 .00C'4 .004 .00IE 0.25 0,94 .011 ,004 .~0 .13 .07 0,08 .010 .0i8 .000 .0004 .004 .001~. Heal Number Number 33899 33900 47330 4~7331 I I Sample Original iNumber Dimensions I ¢V2 'X 1 1.493 X .373 1 1.490 X .~86 ~.493 X ,365 , 56,000 Y1e~ Ultimate -~lon~a~ 1 on- ~ PSI PSI In.lin, Pct. BHN~ s' - soo z 4.o o 55,700 82,400 2 32.0 0 55,800 81,600 '2 ~4.0 0 80,600 Z 38.0 0 ALL MELTING AND Mu%NUFACl'URING ;PR0',.iE3SES OF THE MATF, R IA5 SUDJCCT T~.~ THIS TEST C~RTIFICAT~ 0CCUaaED IN THE UNITED STATES OF AMERICA. This is to certify tha~ the maCerial subject to bhis certificate of inspection and Notice of Limited Warranty was la.~n~Jfactured in accordance with an~ conforms to the specifications designated hereon. NO ~RANTY I$ ~PRESSED 0R IMPLIED other than those set forth above. In ~rticular. CF&I Steel Co,potation specifically disclaims any implied warranty of me~chantabiilt? or' fitness, for ~ntende~purpose. t '--Oua 11 t 12/28/89 CONOCO MPU OPS CTP~?-659-6~90 00? CCRT1FIC, ATg OF CF&I ~TEEL CX)i~PORATION P 0 ~OX ~16 [CONOCO, INC. . ..... , i i , T~X EXEMPT T~G FOR:CONOCO INC, $&T WHSE-RLRSKR P.0. SEAMLESS STEEL PIPE CASING (O~C.T.G,) H & k GRADE J-55 FOR ARCTIC SERVICE ?-5/8 IN "".352 WALL 36,Ge LB/Fl' R-3 9UTTRESE T/C ' 62t~-0723-2-t HEAT ~T¥ UOM THRD CENGTH 3'-~897 16 JNT 3-~?00 26 JNT 20.7 4-7530 26 JNT 20.7 ~-75~! ~2 JNT 20,7 TOTAL TOTAL NET WT. 679,1 ~212.5 2444~ 47909 1'5165e 12/28x89 16:40 , CONOCO MPU OPS CTR ~07-659-~390 003 /,, / """' ~0, /NC. $6~T WHSF_-RLASK~q CONOCO ITEM NO. e~ ~E~MLEEE ETEEL PIPE CAEING (O,C,T.G.) H ~ K G~DE 9-~/B IN ,~52 WALL ~6.ee LB/FT R-3 BUTTRESS -T/C HERT ~TY UO~ THRD LENGTH 3-~89~ le JNT 2e,7 3-3~ee t4 JNT 2e.7 4-733e 12 JNT 2e.7 4-7331 ~ 9 JNT 2e. 7 BAL. TO SHIP FEET 576 · 7 2076 .2" ti CONOCO MPU OPS CTR 907-659-E~90 Conoco inc. Requ~t For Facsimile Trammi.ion Fax Keply Number: (907) 659-6390 ET~ 481-6390 notify (907) 659-63a'0 if complata tranemiss~o~ is not recaiv~d. 07:41 CONOCO MPU OPS CT 07-659-6J90 001 · ~, I:2.29. P. i DATE; December ~9, 1989 PAGC 1 of I TO: Dave Mount Joy Conoco Alaska FAX NO: g0~-659-6390 FROM: J. E. Otont$to Manager-Tubular Products Please find be]ow the impact values ?or the ?lye heats conducted on 3/4 s4ze specimens 19. Heat 3-3899 Heal 3-:~900 Heat 4-7330 Heat 4-7331 Heat 8-9110 Indtyid_~pl Tests (F=[/Lbs) 3 Tes~ Avq~ 10, lZ, 17 13.0 20, 14, 9 14.3 33, 4~, 32' 3S, 7 IS, ~1, ~4 20.0 Mtnlmum allowable average ?or 3/4 stze specimen - 12 ?t/lbs Hlnlmum Individual lest fo~ 3/4 s~ze specimen * 9 If you requl~e ~urther ~n?or~natton, don'~ hesitate to call. 14anage?-Tubul a~ P~oducts dEO/$p cc: j, O, Hotttn.qe~ 01/02./90 CONOCO MPU OPS CTR o=~9-659-6390 · 2.1990 14:40 DAVE: 0&nuary 2, 1990 PAGE .3_ ot' .i_ TO: Dave Hountjoy Conoco A1 aska FAX NO: 901-659-6390 FROM: J. E. Olontsto Hanager-Tubul ar Products Below are llsted some impact values for APl K-i)$ product as requested. All were ~vnducted at room temperature. Hoat~ lm~. ac~;,,, Value (Ayg_)_ Ft/Lb.s 2-7337 35.8 4-0607 ~1.0 4-0608 35.0 3-735~ 34.5 t-7328 35.5 4-0581 30,3 3.7313 27.0 3-7314 27.5 4-O580 36.8 'These impacts are above most; manufacturers K-SS product as CF&I designs their steel for tou.~hness. As previously stated, the Arctic service 0-55 meet API J-SS in every sense but is designed for better tmpmct proper'ties at low temperatures, If furthe, information is required, let me know. J. E, Otonls(o Hanaget'-Tubul ar Products JEO/sp Company Lease & Well No. YES NO CHECK LIST FOR NEW WELL PER}fITS ITEM APPROVE DATE ~-~ Fee . ~7~---./~7~7~..~. ~ 1. Is the permit fee attached (1) (2) Loc (8) (3) mdmin .~_~__ ~)~)/~ 9. (9 thru ' 10. ~,~.~ ~z-,~-~9 ~. (10 and 13) 12. 13 (4) Casg ~(14 thru 22) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 2. Is well to' be located in a defined pool ............................. ~__ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ....... ..... 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... (23 thru 28) ls conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve 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 wellbore 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 diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~D psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ' (29 thi-u' 3]~' (6) Add: Geology. Eng,. eering: DWJ ~.CS rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE / Additional Remarks: ~1-- ~ ~ .~ c~. ?~ CO ~ t733 ~ ;~ ~;~ b~-~,'~. 1
