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Home My WebLink About192-099 Davies, Stephen F (DOA) From: Lastufka, Joseph N [Joseph.Lastufka ©bp.com] Sent: Tuesday, February 12, 2013 4:54 PM To: Davies, Stephen F (DOA) Subject: RE: PBU S -37 and S -37A Surface Location Question Attachments: PBU S -37, 10- 05- 92.pdf Steve, The recent completion report(s) used the As -Built for the surface locations (and x -y coordinates) which I have attached for you, the N /S, E/W offsets match with our converter as well... I am under the impression that the recently submitted location is the correct one. Please let me know if you would like for me to alert you in the future when I submit a corrected surface location (depending on how different from the original). Hope that I've explained it well, if you have any questions please don't hesitate to let me know. Thanks! Joe Lastufka Alaska Wells Technologist SCANNED MAR 2013 Cell: (907) 227 -84961 Office: (907) 564 -4091 a BP Exploration Alaskaj900 E. Benson Blvd.JRoom: 788D1Anchorage, AK From: Davies, Stephen F (DOA) [mailto:steve.daviesc alaska.gov] Sent: Tuesday, February 12, 2013 4:37 PM To: Lastufka, Joseph N Subject: PBU S -37 and S -37A Surface Location Question Joe, The original completion report for PBU S -37 (Permit 192 -099) gives the surface location of the well at 1684 FNL, 1929 FWL, Sec, 35, T12N, R12E, UM BP's Well Completion Reports for PBU S -37 and S -37A submitted on 11/9/2012 list the surface location at 1647 FNL, 1922 FWL, Sec, 35, T12N, R12E, UM Could you check this and let me know which is correct? Thanks, 1 • ( /z- - ` f 27 26 25 I E 1 r. r {3 saw 1 ;-4 S PAD 1 G_ : z i ` ;U„r _ ! 7., 36 JY / / __ _. -._.. .._ _.- _._ ..__ / _ 4 /_ T.12N. S PAD r' T.1 1 N. 3 2 - ----- -* - -- ---- ----- r VICINITY MAP ,., 4000' 1 22 If 22023 321 24 425 2i 5 V 28 9 10 1 29 9 3632 m 34,Yi 1139 3112A 13 14 I, F l r---1 __ . LEGEND • ' + AS -BUILT WELLS 4-11 1 i 1 -'4- EXISTING WELLS 4∎1 OF ,4 111 °° ,� �� ' • ° °' °'••.; I II J = �- 0. �� r I • / .f 1 F. ROBERT BELL / 3252 -S : • NOTES / '� ° • q � . • 4`° 2. REFERENCE FIELD BOOK ?WOA992 -10 t t��1l.11� »��` (PGS. 25 THRU 29). 3. ALASKA STATE PLANE COORDINATES SURVEYOR'S CERTIFICATE ARE ZONE 4, ALASKA, NAD27. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LOCATED WITHIN PROTRACTED SECTION 35 T. 12 N , R. 12 E., U.M , AK. LAND SURVEYING IN THE STATE OF WELL A.S.P. PLANT GEODETIC CELLAR BOX SECTION ALASKA AND THAT THIS PLAT REPRESENTS NO. COORDINATES COORDINATES POSITION ELEV. OFFSETS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL Y =5979855.20 N.1729.40 d 70'2112.905' FNL 1640' DIMENSIONS AND OTHER DETAILS ARE 33 x= 619649.56 E.1000.09 149'01'42.249' 35.60' FWL 1487' CORRECT AS OF OCT. 2, 1992. Y=5979854.96 619944.03 E.1000.45 149'01'33.643" 36 FWL 1782' 341 X. 82' F . R. BELL & ASSOCIATES Y =5979855.10 N.2060.40 70'21'12.852 . FNL 1645' 351 X= 619980.53 E.1000.31 149'01'32.576' 35.74 FWL 1818' 36 P Y=552nn504 2130.56 14 3 .840' 35.84' FNL 1646' BP EXPLORATION !y, FNL ? X- 5620084.30 V E.1000.89 149'01'29.5 35 I FWL 1 ✓ S PAD • Y= 5979855.01 N.1911.91 70'21'12.874' FNL 1643' CONDUCTOR AS -BUILT = - X. 619832.05 E.1000.35 149'01'36.915" 36.84' FWL 1670' WELLS 33, 341, 35i, 361. 37 de 38i DATE: DRAW 1kRLK: 20/5/92 MINISH FENTIE `- � �atk a�tx �aE R 0 10/5/92 ISSUED FOR INFORMATION ADM JMF 1" - 400' �v� •.A. SUIJ 4:40, 010~111". 14 wet REV N0. DATE REVISIONS DRAWN CHECK SK- SPADAB 1 of 1 0 F • I. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other 1b. Well Class ® Abandoned 0 Suspended 20AAC 25.105 20AAC 25.110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ® Development ❑ Service l 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Num' M 1 � �" BP Exploration (Alaska) Inc. i( , ' / y 192 -099 • 312 -248 I / � 3. Address: 6. Date Spudded: ,T ?, 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 10/22/1992 50 029 - 22291 - 00 - 00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/2/1992 PBU S -37 1647' FNL, 1922' FWL, Sec. 35, T12N, R12E, UM 8. KB (ft above MSL): 69 . 3 , 15. Field / Pool(s) Top of Productive Horizon: GL (ft above MSL): Prudhoe Bay / Prudhoe Bay 1974' FNL, 3665' FWL, Sec. 35, T12N, R12E, UM ( ) 35.64'° Y - Total Depth: 9. Plug Back Depth (MD +TVD) 2092' FNL, 3961' FWL, Sec. 35, T12N, R12E, UM 9145' 8675' 4b. Location of Well (State Base Plane Coordinates, NAD : 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x - 620084 • y - 5979855 • Zone ASP4 • 9770' 9224' ' ADL 028257 - TPI: x- 621833 y - 5979556 Zone ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 622131 Y 5979443 Zone- ASP4 None 18. Directional Surve : 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): y ❑Yes ®No (Approx.) A (Submit electronic and printed information per 20 AAC 25.050) N ft MSL 1900' ( PP ) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIL / BHC / GR /RD N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H -40 Surface 76' Surface 76' 30" 11 yds Arctic Set 10 -3/4" 45.5# NT -80 36' 2923' 36' 2915' 13 -1/2" 1756 cu ft AS III, 500 cu ft AS 1 RECEIVED 7 -5/8" 29.9# NT -95HS 32' 9106' 32' 8642' 9 -7/8" 1305 cu ft Class 'G' 5 -1/2" 17# 13Cr80 8894' 9770' 8460' 9224' 6 -3/4" 157 cu ft Class 'G' NOV 0 9 2012 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD AOGCC If Yes, list each interval open S DEPTH SET (MD +TVD of Top & Bottom; Perforation Size and Number): S IZE (MD) PACKER SET ( MD / TVD) 4 - 1/2 ", 12.6#, 13Cr80 8902' 8837' / 8412' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ® No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9145' Set Whipstock 20 Bbls Class 'G', 22 Bbls Class 'G' 8863' 4 -1/2" Baker Liner Top Packer 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested. Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No 4 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 RP&MS NOV 14 2011 Form 10-407 Revised 10/2012 CONTINUED ON REVERS /2/2.Z.714.- /2.Z.714.- Submit Original Qnly / / -v 4P 29. GEOLOGIC MARKERS (List all formations allarkers encounter 30. FORMATION TESTS NAME MD TVD Well Tested Yes ® No • Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9106' 8642' None Shublik 9150' 8679' Sadlerochit 9255' 8770' Formation at Total Depth: 31. List of Attachment: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Summary of Post -Rig Work, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Matt Ross, 564 -578 • ossmo ©bp.com Email: lastuf @bp.com Title: Drilling Te Printed Name: Joe - i a " (p� 'n G1 Signature: Phone 564 4091 Da �4 / /) 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 10/2012 Submit Original Only • • S -37, Well History (Pre Rig Sidetrack) Date Summary 07/28/12 RAN 3.80" CENT AND TAGGED XN NIPPLE AT 8872' SLM. RAN A 3.70" CENT, 4 -1/2" TEL, 2 -1/2" SAMPLE BAILER & LOCATED TT AT 8883' SLM ( +15' correction = 8898 ELMD). TAGGED TOP OF CEMENT CAP @ 9380' SLM (9395' ELMD - 35' OF RATHOLE) (recovered a sample of cement) RAN A 3.70" x 20' DUMMY WHIPSTOCK & TAGGED TOP OF CEMENT CAP AT 9380' SLM (9395' ELMD). 07/28/12 INITIAL T /I /O = 1500/350/200 PSI. RIH W/ HEAD(6X3)/WELLTEC MILLING TOOL AND CCL OAL = 34.7' OAW = 514LBS MAX OD = 3.801" FISHING NECK = 1.38" CCL TO BOTTOM OF BIT = 26.1' CCL TO MID ANCHORS = 11.5', MILL OD BEFORE MILLING = 3.801 ". MILLED SWN NIPPLE AT 8890' TO 3.80" ID. L 07/29/12 RIH. HEAD /ERS /SWIVEL/WPPT -CCL, GR, TEMP, PRESS/WHIPSTOCK. LENGTH: 56'; WEIGHT: 600 5 LBS; OD: 3.625 "; FN: 1.38 ". CCL -TOP OF WHIPSTOCK: 18.5 FT. TOP OF WHIPSTOCK SET AT: 9145 FT. 9.14* ROHS. BAKER GEN II WHIPSTOCK. 4.5" x 5.5" 17 #. FINAL T /I /O = 1500 /300 /200. WELL LEFT SI ON DEPARTURE. VALVES OTG. 07/30/12 SV, WV, SSV, MV = Closed & LOTO. IA, OA = OTG. NOVP. 08:45 hrs. 08/02/12 T /I /O = SSV /250/200. Temp = SI. Bleed IAP and OAP to 0 psi (Pre CTD). IA FL @ surface. Bled IAP to 0 psi in 35 min ( -1 bbl liquid). Bled OAP to 0 psi in 20 min. Left open bleed for additional 30 min. SI, monitored for 30 min. No change in IAP. OAP increased to 10 psi. Job complete. Final WHPs = SSV /0/10. SV, WV, SSV =C MV =O. IA, OA =OTG. NOVP. 02:25. 08/03/12 T /I /O = SSV /5/85. Temp = SI. WHP's (Post Bleed). AL, flowline, and wellhouse have been removed. IAP increased 5 psi and OAP increased 75 psi overnight. SV, WV, SSV, MV = Closed and LOTO. IA, OA = OTG. 10:00 hrs. 08/06/12 T /I /O 1470/7/155 Temp= SI Load and Kill (pre rig) Load tubing with 2 bbls meth, 217 bbls 120*f 1% KCL. Freeze protect tubing with 2 bbls meth, 40 bbls diesel. FWHP vac /0/680 SV,WV,SSV= closed, MV =open, IA and OA =OTG. 08/07/12 T /I /O= VacNac /540. Temp= SI. Bleed IA & OA to 0 psi (Pre CTD). No AL, flowline, or wellhouse. OA FL @ surface. Bled OA from 540 psi to 0 psi ( -10 gals fluid) to slop tank in 10 mins. Monitored for 30 mins. OAP went on vac. Job complete. Final WHPs= VacNacNac. SV, WV, SSV & MV =C. IA & OA =OTG. NOVP. 08/07/12 T /I /O= Vac /0/0 Conducted PJSM. SSV would not cycle to fully closed. PT'd thru tree cap against Swab & Master valves (w/ WSL approval)) 3500/ 5 min. pass. Removed tree cap, attached lubricator w/ TWC #279, PT'd 250 /Iow..3500 /high..pass. SET 4" CIW "H" TWC #279 thru tree using 1 -1' Tagged @ 111 ". Shut SN & MN, removed lubricator, attached tree cap. PT'd TWC & Master valves independently 250 /Iow..3500 /high..pass for barriers to C/O SSV. Removed upper tree from SSV. Removed bad SSV, replaced w/ new SSV w/ Baker act., re- installed upper tree. Made C/O w/ night crew. 08/07/12 T /I /O = 0/100/0. Made change out with day crew. Conduct PJSM. Torqued flanges (MV to SSV and SSV to Flow cross) to API specs. (1 -1/4" L7M 726 ft. Ibs.). PT'd tree to 200 -300 psi. low for 5 min. (passed) and 5000 psi. high for 5 min. (passed) using TWC as barrier. Charted and documented. Rigged down. Page 1 of 1 • • a :. s Common Well Name: S -37 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/8/2012 End Date: 8/30/2012 X3 -0011 WF (3,050,122.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 63 : 37 10/22/1992 00:00 @69.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/8/2012 18:00 - 00:00 6.00 MOB N WAIT PRE BEGIN RON EVENT WITH NORDIC 2 CTD RIG AT 18:00. STAGE RIG ON CC2A WHILE WAITING FOR DOYON 25 RIG TO CLEAR SPINE ROAD. CONTINUE MAINTENANCE -TYPE ACTIVITIES. PREP AND PAINT EXTERIOR OF RIG. INSTALL BOP RAMS. PERFORM GENERAL CLEANUP AROUND RIG. CONFIRM CLOSURE OF RIG CONDITION/ENVIRONMENTAL ACCEPTANCE AUDIT ACTION ITEMS. 8/9/2012 00:00 - 04:30 4.50 MOB N WAIT PRE STAGE RIG ON CC2A WHILE WAITING ON DOYON 25 RIG TO CLEAR SPINE ROAD. CONTINUE TO PREP AND PAINT EXTERIOR OF RIG. COMPLETE INSTALLATION OF RAMS INTO BOP STACK. PERFORM GENERAL CLEANUP OF RIG FOLLOWING MAINTENANCE PERIOD. PREPARE RIG TO MOVE. 04:30 - 05:00 0.50 MOB _ P PRE HOLD PREJOB SAFETY MEETING AND MOVE RIG OFF HERCULITE. STAGE RIG ON EDGE OF PAD. CLEANUP MAINTENANCE LOCATION. 05:00 - 07:00 2.00 MOB N WAIT PRE STAGE RIG ON PAD. WAIT ON SECURITY AND CREW CHANGE FOR RIG MOVE. TP AND DRILLER MAKE ACTUAL ROUTE DRIVE TOGETHER TO S PAD. 07:00 - 08:00 1.00 MOB P PRE HOLD PJSM FOR MOVE TO S PAD. REVIEW ROUTE DRIVE HAZARDS. DISCUSS COMMS AND POSTIONS FOR EACH HAND. JACK UP RIG. MAKE LAST MINUTE WALK AROUND AND CHECKS. 08:00 - 12:30 4.50 MOB P PRE MOVE RIG FROM CC2 -A PAD. FOLLOW SPINE ROAD OVER KUPARUK RIVER BRIDGES. 12:30 - 14:00 1.50 MOB P PRE RIG AT ACCESS ROAD TO S PAD. RIG ON S -PAD AT 1400 HRS (TOTAL MOVE TIME = 6 HOURS) 14:00 - 17:00 3.00 MOB P PRE SET RIG MATS AROUND S-37 WELLHEAD AND PREPARE LOCATION. 17:00 - 18:00 1.00 MOB P PRE SPOT AND CENTER RIG OF WELL. - WELLWORK TRANSFER PERMIT OPEN WITH PAD OPERATOR. - ALL VALVES ON TREE AND WELLHEAD CLOSED FOR PULLING OVER WELL. - INITIAL T /I /0= TWC /0 /0 PSI - ALL PRE -RIG WORK VERIFIED COMPLETE. DOUGLE GATE VALVES INSTALLED ON OA FOR FAILED MIT -OA. - S -11 AND S-05 WING VALVE LOCKED OUT BY WSL AND PAD OPERATOR FOR ANTI - COLLISION - PRE -SPUD MEETINGS HELD WITH BOTH CREWS 18:00 - 20:00 2.00 RIGU P PRE BERM UP AROUND RIG, GENERAL RIG UP OPERATIONS. Printed 8/27/2012 11:13:55AM 4Y'rth Arne' to • eration Summary Re • • Common Well Name: S -37 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/8/2012 End Date: 8/30/2012 X3 -0011 WF (3,050,122.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 63 : 37 10/22/1992 00:00 @69.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 21:00 1.00 BOPSUR P PRE ACCEPT NORDIC 2 CTD RIG AT 20:00 ON 8/9/2012. PRESSURE UP DOWN WING VALVE AGAINST CLOSED SSV AND CLOSED SWAB VALVE TO 3000 PSI AND CONFIRM LEAK TIGHT (PROPER STEM EXPOSED ON SSV AND CORRECT # TURNS ON SWAB) TO ESTABLISH BARRIERS FOR BREAKING CONTAINMENT (PASSING TEST). NIPPLE DOWN TREE CAP FLANGE. SPOT SATELLITE CAMP AND OTHER SECONDARY EQUIPMENT. 21:00 - 23:00 2.00 BOPSUR P PRE NIPPLE UP 7- 1/16" 5K BOP STACK TO 4-1/16" SWAB FLANGE WITH FOLLOWING CONFIGURATION FROM TOP DOWN: - HYDRIL GK ANNULAR - TOT BLIND -SHEAR RAMS WITH BOOSTERS TOT 2 -3/8" COMBI PIPE RAM/SLIPS - FLOW CROSS WITH 2- 3/16" INNER HCR VALVE AND 2- 1/16" OUTER GATE VALVE ON BOTH KILL AND CHOKE LINE TOT 2 -3/8" X 3-1/2" VB RAMS TOT 2 -3/8" COMBI PIPE RAM/SLIPS LIFT 2 -3/8" COILED TUBING REEL INTO REEL HOUSE 23:00 - 00:00 1.00 BOPSUR P PRE INSTALL LUBRICATOR AND PACKOFF ON TOP OF BOP STACK TO EXTEND PRESSURE CONTROL EQUIPMENT UP TO RIG FLOOR. 8/10/2012 00:00 - 01:30 1.50 BOPSUR P PRE COMPLETE RIGGING UP LUBRICATOR, PACKOFF AND INJECTOR. HARDLINE CREW ON LOCATION TO RIG UP FLOWBACK TANK AND HARDLINE. 01:30 - 02:30 1.00 RIGU P PRE HOLD RIG EVACUATION DRILL AND AAR WITH ALL ON LOCATION. 02:30 - 04:00 1.50 BOPSUR P PRE RIG UP TO PRESSURE TEST BOPE. RECORD RIG FLOOR TO BOP ELEMENT MEASUREMENTS. FILL ALL LINES AND FLOW THROUGH MUD GAS SEPARATOR. RIG UP REEL HARDLINE. 04:00 - 12:30 8.50 BOPSUR P PRE PRESSURE TEST BOPE PER ADWOP AND AOGCC REGULATIONS TO 250 PSI LOW AND 0 3500 PSI HIGH FOR FIVE MIN EACH. STATE'S p1 RIGHT TO WITNESS WAIVED BY AOGCC ►►✓✓ REPRESENTATIVE BOB NOBLE. - PRESSURE TEST ANNULAR PREVENTER WITH 2 -3/8" TEST JOINT - PRESSURE TEST VBRS WITH 2 -3/8" & 3 -1/2" TEST JOINT. - TEST AND CALIBRATE GAS ALARMS. - FUNCTION ALL COMPONENTS FROM ALL CONTROL STATIONS - NO FAILURES DURING TESTING. - SEE ATTACHED DOCUMENTATION REPORT AND CHARTS. Printed 8/27/2012 11:13:55AM , o Common Well Name: S -37 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/8/2012 End Date: 8/30/2012 X3 -0011 WF (3,050,122.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 63 : 37 10/22/1992 00:00 @69.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 15:00 2.50 MOB P PRE HOLD PJSM TO PULL COIL ACROSS TO INJECTOR. RU TUGGER CABLE. TEST SAME. PULL COIL ACROSS PIPE SHED ROOF. ENGAGE AND FULLY STAB IN TO INJECTOR. 15:00 - 16:30 1.50 MOB P PRE FILL COIL WITH KCL. VERIFY SLB PUMP GAUGES IN AGREEMENT WITH NORDIC GAUGES. 16:30 - 17:30 1.00 BOPSUR P PRE PRESSURE TEST INNER REEL VALVE AND PACKOFFS 250 PSI AND 3500 PSI. PASSED. CHART SAME. 17:30 - 20:00 2.50 MOB P PRE RIG UP AND PUMP E -LINE SLACK BACK IN COIL. 20:00 - 21:45 1.75 MOB P PRE CUT 256' OF 2 -3/8" COILED TUBING WITH HYDRAULIC CUTTER. 21:45 - 22:15 0.50 MOB P PRE INSTALL SLB COILED TUBING CONNECTOR AND PULL TEST TO 35 KLBS. 22:15 - 00:00 1.75 MOB P PRE SLB TECHNICIANS ON LOCATION TO ADJUST GOOSENECK AND CALIBRATE INJECTOR WEIGHT CELL FOR NEW INJECTOR INSTALLED DURING SUMMER MAINTENANCE). 8/11/2012 00:00 - 01:00 1.00 MOB N SFAL PRE TROUBLESHOOT E -LINE JUNCTION BOX AT REEL DUE TO CONNECTIVITY ISSUE WHILE TESTING WIRE. 01:00 - 03:30 2.50 MOB P PRE MAKEUP BHI E -LINE HEAD AND TEST (PASS). PUMP E -LINE SLACK FORWARD. 03:30 - 04:30 1.00 BOPSUR P PRE PRESSURE TEST INJECTOR LUBRICATOR AND DFCVS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS, SEE ATTACHED CHART). PERFORM LEAK TIGHT TEST ON COILED TUBING CONNECTOR. 04:30 - 08:00 3.50 RIGU P PRE HOLD PJSM. RIG UP VALVE SHOP LUBRICATOR AND PRESSURE TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). OPEN SWAB, SURFACE SAFETY AND MASTER VALVES. PULL TWC. PRESSURE ON WELL = VAC. CLOSE MASTER, SSV AND SWAB VALVES. BLEED OFF PRESSURE ON LUBRICATOR AND MONITOR FOR LEAK TIGHT (PASS). RDMO VALVE SHOP LUBRICATOR. 08:00 - 08:30 0.50 RIGU P PRE HOLD PJSM TO DISCUSS KILLING WELL. REVIEW VOLUMES, FLUIDS, MAX PRESS & RATE, VALVE ALIGNMENT. 08:30 - 09:30 1.00 RIGU P PRE HOLD RIG EVACUATION DRILL. RIG EVACUATED IN LESS THAN 2 MIN, INCLUDING VAC TRUCK DRIVERS. ALL HANDS COULD HEAR THE SIREN. SCS HEAD COUNT CORRECT. HOLD AAR IN SAT CAMP AFTER DRILL. DISCUSS WIND DIRECTION IN NEAR CALM CONDITIONS. Printed 8/27/2012 11:13:55AM North America - ALASKA B ` y Operation Summa F ry Common Well Name: S -37 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/8/2012 End Date: 8/30/2012 X3 -0011 WF (3,050,122.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 63 : 37 10/22/1992 00:00 @69.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 13:00 3.50 RIGU P PRE OPEN WELL. PUMP 5 BBLS MEOH. PUMP 250 BBLS KCL. 500 -600 PSI WHP AT 5 BPM. CHECK ALL SURFACE EQUIPMENT FREQUENTLY AFTER MAINTENANCE. PUMP 150 BBLS USED FLO PRO MUD. MAX PRESSURE: 1025 PSI WITH 10 BBLS INTO PERFS. SHUT DN. BLEED WHP. CIRC ACROSS THE TOP AND MONITOR WELL FOR 30 MIN. ESTIMATE LOSSES AT 25 -30 BPM. CALL FOR ADDITIONAL USED MUD FROM NORDIC 1 RIG. 13:00 - 14:00 1.00 STWHIP P WEXIT HOLD PJSM. MU INTEQ / BAKER TT MILLING BHA AS PER WELL PLAN. BHA OAL = 121'. STAB COIL. TEST TOOLS. GET ON WELL. PRESS TEST QTS TO 250 AND 3500 PSI. CHART TEST. PASSES. 14:00 - 18:30 4.50 STWHIP ' P WEXIT DISPLACE KCL FROM COIL THROUGH EDC. RUN IN HOLE. STOP AND MAKE ADJUSMENTS TO NEW CT INJECTOR. CONTINUE TO RIH TO TIE -IN LOGGING DEPTH AT 8900' MD. LOG KINGAK JB MARKER GR SIGNATURE AT 8930' MD TO TIE -IN TO PDC LOG (APPLY -9' CORRECTION). 18:30 - 19:30 1.00 STWHIP P WEXIT LOG CCL FROM 9000' MD TO 8700' MD IN PREPARATION FOR PLANNING INTERMEDIATE DRILLING LINER TOP. RUN BACK IN HOLE TO 9100' MD. SLOW PUMP RATES, 8.7 PPG, 9141' MD: MP #1: 0.5 BPM = 1490 PSI, 1 BPM = 1553 PSI 4 MP #2: 0.5 BPM = 1509 PSI, 1 BPM = 1750 PSI. 19:30 - 20:15 0.75 STWHIP P WEXIT RUN IN HOLE FROM 9100' TO DRY TAG TOP OF WHIPSTOCK AT 9141.4. PICKUP 10', ESTABLISH PUMP RATE AT 2.6 BPM, 2800 PSI AND RUN BACK IN HOLE TO TAG WHIPSTOCK AT 9141.0' MD. 20:15 - 00:00 3.75 STWHIP P WEXIT KICKOFF NEW SIDETRACK AND MILL WINDOW IN 5 -1/2" LINER FROM 9141.0' MD to —1P‹ 9144.2' MD AT MIDNIGHT; 2.6 BPM IN, 2.25 -2.5 BPM OUT, 2800 PSI FREESPIN, 2950 -3050 PSI o"" PUMP PRESSURE, IA/OA = 25/250 PSI. MW IN/OUT = 8.7 PPG, ECD = 10 PPG. NO STALLS e DURING START OF WINDOW. LOSSES TO FORMATION APPEAR TO BE HEALING WHILE MILLING. AVERAGE DURING TIME PERIOD = 10 -15 BPH. BLEED OA FROM 735 PSI TO 200 PSI IN <3 MIN, <20 GAL FLUID. Printed 8/27/2012 11:13:55AM y ¢ "`` f° " • North America - ALAS ®/Z Operation Summary R r "� Common Well Name: S -37 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/8/2012 End Date: 8/30/2012 X3 -0011 WF (3,050,122.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 63 : 37 10/22/1992 00:00 @69.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/12/2012 00:00 - 06:00 6.00 STWHIP P WEXIT MILL WINDOW IN 5 -1/2" CHROME LINER FROM 9144.2' MD AT MIDNIGHT TO 9152' MD AT 6 AM; 2.6 BPM, 2800 PSI FREESPIN, 2900 -3100 PSI PUMP PRESSURE, 1 -3 KLBS DHWOB. MW IN/OUT = 8.7, ECD = 10.1 PPG. IA/OA = 250/500 PSI. NO STALLS OR SIGNS OF EXTRA LOSSES TO FORMATION WHEN EXITING LINER WITH MILLS. LOSSES TO FORMATION HAVE DROPPED TO < 5 BPH. 06:00 - 06:30 0.50 STWHIP P WEXIT CREW CHANGE. DISCUSS OPERATIONS AND RIG EQUIPMENT STATUS. MAKE ROUNDS AND CHECKS. CONTINUE TO MILL WINDOW. 06:30 - 09:30 3.00 STWHIP P WEXIT CONTINUE TO MILL WINDOW FROM 9151.4'. 2725 PSI FS AT 2.56 BPM IN/2.49 BPM OUT. 200 PSI MTR WORK. 0.49K# DHWOB. IA/OA/PVT: 320 PSI / 576 PSI / 310 BBLS. BHP /ECD / TVD: 4472 PSI / 10.09 PPG / 309 _ BBLS. MILL WINDOW TO 9153.5'. NO STALLS. NO INDICATION OF EXITING CASING BASED ON MILLING PARAMETERS. SAG CUTTINGS NOTED IN SAMPLES. 09:30 - 11:30 2.00 STWHIP P WEXIT DRILL NEW FORMATION TO 9161.6'. 11:30 - 13:45 2.25 STWHIP P WEXIT DRESS WINDOW WITH THREE SLOW UP /DOWN PASSES. 2908 PSI FS AT 2.57 BPM IN/2.54 BPM OUT. DRY DRIFT AT 10 FPM. WINDOW SMOOTH. 13:45 - 16:30 2.75 STWHIP P WEXIT FLOW CHECK WELL FOR 10 MINUTES. WELL STABLE. OPEN EDC. CIRCULATE OUT OF HOLE. 2505 PSI AT 3.12 BPM. 16:30 - 17:00 0.50 STWHIP P WEXIT AT SURFACE. GET OFF WELL. UNSTAB COIL. LD BHA. MILL GAUGED 3.79" GO / 3.78" NO GO STRING REAMER: 3.80" GO / 3.79" NO -GO. 17:00 - 18:45 1.75 DRILL P INT1 MU INTERMEDIATE SECTION BUILD DRILLING BHA. STAB ON WELL WITH INJECTOR AND PRESSURE TEST QTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS) - 4 -1/8" HUGHES BI- CENTER PDC, RWD 2ST3053.750QF, SLICK COATING - 2 -7/8" X -TREME HIGH SPEED MUD MOTOR, 2.6° BEND - 3" COILTRAK TOOLS WITH RESISTIVITY AND DFCVS - BHA OAL = 79' Printed 8/27/2012 11:13:55AM fi d North America - ALASKA - : ® / O peration Summary Report ' tt Common Well Name: S -37 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/8/2012 End Date: 8/30/2012 X3 -0011 WF (3,050,122.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 63 : 37 10/22/1992 00:00 @69.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:45 - 21:15 2.50 DRILL P INT1 TRIP IN HOLE WITH DRILLING ASSEBMLY FROM BHA AT 79' MD TO PREVIOUSLY DRILLED TO DEPTH AT 9162' MD. LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE -IN (APPLE -11' CORRECTION COMPARED TO PREVIOUS CORRECTION OF -9'). SLOW PUMP RATES, 8.7 PPG, 9162' MD: MP #1: 0.5 BPM = 1548 PSI, 1 BPM = 1838 PSI MP #2: 0.5 BPM = 1564 PSI, 1 BPM = 1828 PSI 21:15 - 00:00 2.75 DRILL P INT1 DIRECTIONAL DRILL 4 -1/8" INTERMEDIATE BUILD HOLE SECTION FROM 9162' MD TO 9204' MD AT MIDNIGHT (42' IN 2.75 HRS = 15 FPH); 2.5 BPM, 2875 PSI FREESPIN, 2950 -3200 PSI PUMP PRESSURE, 1 -3 KLBS DHWOB. MW IN/OUT = 8.7 PPG, ECD = 10.2 PPG. NO LOSSES TO FORMATION WHILE DRILLING AHEAD. PICKUP WEIGHT OFF BOTTOM = 30 KLBS. IA/OA = 350/250 PSI. DRILLING BUILD SECTION IN SHUBLIK. BUILD RATES ARE APPROXIMATELY 25 °/100' USING NEAR BIT INCLINATION. 8/13/2012 00:00 - 06:00 6.00 DRILL P IfTi DIRECTIONAL DRILL 4 -1/8" INTERMEDIATE BUILD HOLE SECTION FROM 9204' MD AT MIDNIGHT TO 9275' MD AT 6 AM (71' IN 6 HRS = 12 FPH); 2.5 BPM, 2875 PSI FREESPIN, 3000 -3250 PSI PUMP PRESSURE, 1 -4 KLBS DHWOB. MW IN/OUT = 8.7 PPG, ECD = 10.3 PPG. NO LOSSES TO FORMATION WHILE DRILLING AHEAD. DRILLING BUILD SECTION IN SHUBLIK. TARGETING 30 °/100' DLS. BUILD RATES ARE APPROXIMATELY 27 °/100' USING NEAR BIT INCLINATION. NO OFFICIAL SURVEYS YET DUE TO PROXIMITY TO OLD WELLBORE. 06:00 - 06:30 0.50 DRILL P INT1 CREW CHANGE. REVIEW CURRENT OPERATIONS AND RIG EQUIPMENT STATUS. MAKE RIG CHECKS AND OUTSDIE ROUNDS. CONTINUE TO DRILL BUILD SECTION. 06:30 - 10:00 3.50 DRILL P INT1 DRILL AHEAD FROM 9275'. 3010 FS AT 2.64 BPM IN/OUT. 200 -300 PSI MTR WORK. 2.2K# DHWOB. IA/OA/PVT: 355 PSI / 333 PSI / 414 BBLS. BHP / ECD / TVD: 4634 PSI / 10.28 PPG / 8660'. 10:00 - 10:30 0.50 DRILL P INT1 WIPER TRIP TO WINDOW. HOLE SMOOTH. 10:30 - 11:00 0.50 DRILL P INT1 DRILL AHEAD FROM 9300'. Printed 8/27/2012 11:13:55AM t i E S -37, Well History (Post Rig Sidetrack) Date Summary 09/07/12 T /I /O= Vac /0 /0 Conducted PJSM. Opened Master, SSV, and Swab valves. Confirmed 0 psi. at tree cap. Torqued all tree flanges to specs. 09/08/12 T /I /O = Vac/0 /0. Conduct PJSM. Used SV and SSV as barriers. PT'd tree cap to 500 psi. for 5 min. (passed) prior to removal of tree cap. Bled off pressure and performed LTT. (passed). RU lubricator w. 1- 1' ext. and CIW 4 " pulling tool. PT'd lubricator to 200 -300 psi. low for 5 min. (passed) and 3500 psi. high for 5 min. (passed). Pulled 4" CIW BPV # 131 tagging at 114 ". SI SSV and SV (23 1/2 turns) and bled off • pressure. Made C/O with night crew. Night crew rigged down lubricator and rigged up with 1 -1' ext., CIW setting tool, and 4" CIW TWC # 279. PT'd lubricator (same steps as above) passed. Set TWC tagging at 114 ". PT'd tree using TWC as barrier to 200 -300 psi. low for 5 min. (passed) and 5000 psi. high for 5 min. (passed). Tests charted and documented in QC reports, (field charted tests). SI. SSV and SV. Bled off pressure and Rigged down lubricator. Pt'd tree cap to 500 psi. (passed). 10/17/12 DRIFT W/ 2.53" CENT., 1 -3/4" S. BAILER TO DEVIATION @ 9375' SLM. DRIFT & TAG DEPLOYMENT SLEEVE W/ 10' x 3.70" DMY WHIPSTOCK DRIFT & 3.50" LIB @ 8874' SLM. LRS PUMPED 150 BBLS CRUDE DOWN TBG TO ASSIST W/ B &F. B &F W/ 3.805" GAUGE RING, 8'x1.5" STEM, 4 -1/2" BLB, AND 2.15" CENT. SD @ 8866' SLM AND SAW TRAVEL DOWN TO 8874' SLM. SET BAKER KB LTP W/ HES DPU IN DEPLOYMENT SLEEVE @ 8863" MD (MID ELEMENT). SET 4 1/2" CAT STANDING VALVE LTTP IN LTP @ 8878' SLM. LRS MIT -T TO 250 PSI FOR 5 MIN. (PASS). LRS MIT -T TO 2400 PSI PASSED. 10/18/12 PULL 4 -1/2" CAT STANDING VALVE LTTP FROM 8857' SLM. Page 1 of 1 lRlEE= " 41/16" 5M CIW • SA' NOTES: W ELL ANG(E 74 9325' * ** A_ WELL FAD 11" 5M FM PJC DRAFT 1/2" GFEROME TBG & 5 -112" LNR • :* ACTUATOR= BAKER a� IsIMAL KB. B EV = 693 BE ®,.>�r 32' .illi I KOP= 5000 20" CONDIJGTOR — 910` 2228' I - 112" OTIS HXO SSSV NP, 13 = 3.813' I Max Angle 110" @ 10098' 91.5 #, H 40, Datum MD = 13= 19.124" Datum TVD= 8800' SS GAS LET MANURE.S 10-3/4" CSG, 45.5 #, NT-80 OTC. Y? = 9.953" — 2923' ST M) " _ND DEV TYPE VLV LATCH PORT' DATE 6 3018 3009 1 CA DOME BK ' 16 10121112 5 5104 5095 4 CA SO BK r 20 10/18/12 4 6713 6624 29 CA DMY BK r 16 02103112 3 7885 7612 33 CA DMY BK r 16 02/03/12 2 8333 7987 33 CA DMY BK r 0 01124/10 Minimum ID = 1.91" t 10303' 1 8438 8075 33 CA DMY BK r 24 102/03112 2.70" DEPLOYMENT SLEEVE 8777' H 4- 112" PKR SWS NP, ID =3.813 I $837' -17 -518 X 4 -1/2" BKR S-3 F'KR, ID = 3.875" ►�� ► 1 4 -1/2" BKR BK LIP, D= 2.38" (10/17/12) I 8863' ■ ,_. 1.171 8869' —I3.70 DEPLOY SLV, D= 3.00" T C 8870' H4- 112" PKR SWS NP, 13 = 3.813' `S i1 8$76' -{ 3. BKR HGR SUB, D = 2.813" A 0 • 8890' — 4 -1/2" PKR SWN NIP, A 1# 04 MILLED TO 3.80" (07/29/12) 14 8894' 7 -5/8" X 5- 112" TIEBACK SLV, TOP OF 5 -1 /2" LNR —I 8894 I 4 w 1 ISOLATION PKR, 13= ? 1 4-1/2" TBG, 12.6 #, 13CR NSCT, —I 8902' F ## ‘4; - 8902' 4 -1 /2' WLEG, ID = 3.958" I 0152 bpf, D = 3.958" I• IP. a 8898' H MD TT LOGGED 02 /08/93 •• 1 8906' — I7 -5/8" X 5 -1/2" FLEX LOCK HOR, D = ? • j 7 - 5/8" CSG, 29.7 #, NT - 95 - HS NSCC, D = 6.875" H 9108' I • 1# tot . v., 9114' — [3 - 1/2" X 3 -3/16" XO, D= 2.786 3-1/2" LNR, 9.3 #, L STL, .0087 bpf, D = 2.992" I—H 9114' j #� 1.*0 1,# H 5 • - 1/2' BKR WHPSTOCK (07129/12) 9145' . : 5-1/2" LI'2, 17#, 13CR FL4S, . —9151 41 ►:41 0232 bpf, ID = 4:892' � +*# ►4 , MILLOUT WCJDOW (S -37A) 9141' - 9151' ll�+ t' 3-1/4" LNR, 6.6#, L -80 TCII, 0079 bpf, 13= 2.850" H 10354 I 10303' H2.70" BKR DEPLOY SLV, ID = 1.91 I iRFORATION SU1v1U111RY I 10354' 1— BKRALUMINtJM PORTED BULLNOSE LOG: GU DE SHOE, MILLED TO 2.74" REF ANGLE AT TOPPERF: ° @' Note: Refer to Production DB for historical perf data SIZE SPF I' fERVAL Opn/Sqz DATE 2 -3/8" SLOT 10305 - 11561 O 08/31/12 1 PBTD 1 11561' i 2 -3/8" LNR 4.70#, L -80 STL, .0039 bpf, D = 1.995 11583' E DATE REV BY I COMMENTS DATE REV BY I COMMENTS PRUDHOE BAY UNIT 11/06/92 N286 (INITIAL COMPLETION I 11/07/12 PJC LTP CORRECTION WELL: S-37A 09/02/12 NORDIC 2 CTD SIDETRACK (S -37A) I I PERMIT No: 't120920 09/06/12 PJC ,DRLG HO CORRECTION d 1 API No: 50-029-22291-01 09116/12 PJC _ ... 1DRLG DRAFT CORRECTORS I 1 SEC 35, T12N, T12E, 1648' FNL & 1922' FWL 1 10/29/12 SWC/JMDISET BKR KB LW (10/17/12) 10/29/12 SWC/A1 DI GLV C/O (10/18-21112) I BP Exploration (Alaska) • FA , ffi FE A ` Litti LC CHF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader f BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S -37 Sundry Number: 312 -248 '` ; ' JUL i 201 "L 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. 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 reconsideration. A request for reconsideration 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. Sincerely, / Daniel T. Seamount, Jr. Commissioner DATED this A day of July, 2012. Encl. - g� I b . t , ECEIVED STATE OF ALASKA 1 ALLKA OIL AND GAS CONSERVATION CO + ISSION JUL 0 6 2012 APPLICATION FOR SUNDRY APPROVAL AOGCC 20 MC 25.280 1. Type of Request: ❑ Abandon _4 Plug for Redrill ' ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 1 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 192 - 099 • 3. Address: 0 Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22291 -00 -00 . 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: PBU S - Spacing Exception Required? ❑ Yes 0 No 9. Property Designation: 10. Field / Pool(s): ADL 028257 ' Prudhoe Bay / Prudhoe Bay 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): 9770' ' 9224' - 9400' 8897' 9400' None Casing Length Size MD ND Burst Collapse Structural _ Conductor 76' 20" 76' 76' 1490 470 Surface 2887' 10 -3/4" 36' - 2923' 36' - 2915' 5210 2480 Intermediate 9074' 7 -5/8" 32' - 9106' 32' - 8642' 8180 5120 Production Liner 876' 5 - 1/2" 8894' - 9770' 8460' - 9224' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9115' - 9426' 8649' - 8919' 4 -1/2 ", 12.6# 13Cr80 8902' Packers and SSSV Type: 4 -1/2" Baker Permanent S -3 Packer Packers and SSSV 8837' / 8412' MD (ft) and ND (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 15, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended • 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Ross, 564 - 5782 Printed Name John c / . ,. , Title Engineering Team Leader Prepared By Name /Number: Signature Phone ' Phone 564 - 4711 Date 7(3 4 Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval Notify Commission so that a representative may witness Sundry Number r: ,/ ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 4- 35OO ,st ece -725 / � Other: Cffn `CCU mP_ 0. ior'o✓ -e•. / Z ��G zs . �� z�,�) Subsequent Form Required: • -ii 67 APPROVED BY 71ialt2 Approved ' .�,. - �, 1 COMMISSIONER THE COMMISSION Date / Form 10-403 - -, ' - - /2- — 1 202 �� Submit In Duplicate r (V ORIGINAL ,� *i---- "sly • • To: Alaska Oil & Gas Conservation Commission From: Matthew Ross bp CTD Engineer Date: June 28, 2012 Re: S-37 Sundry Approval Sundry approval is requested to plug the S -37 perforations as part of drilling the S -37A coiled tubing sidetrack. History of S -37. Well S -37 was a rotary sidetrack drilled in 1992 in zone 3 & 4. It is a slant well (max inclination of 34 degrees) and has 4 -1/2" chrome tubing and 5 -1/2" chrome liner. Water production remained high and oil rates slowly declined. Zone 3 was isolated with Sand /cement on 9/14/94 to isolate any water production from Zone 3 and to improve hydraulics of the well, but no major change in production was observed. Reason for sidetrack. S -37 is no longer a competitive well due to an uncompetitive water cut. The proposed sidetrack will access a target in the Sag River. Proposed plan for S -37A is to drill a through tubing sidetrack with a Coiled Tubing Drilling rig on or around September 15 2012. The existing perforations will be isolated by the primary 3 -1/4" protection string cement job. The sidetrack, S -37A, will exit the existing 5 -1/2" liner and kick off in the Sag River, invert and land in the Sag River. This sidetrack will be completed with a 3 -1/4" protection string & a 2 -3/8" slotted liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. CfriC0 we,/ po /1/ fou kv/4 q krertecAr P 4 14/ s '-c tl 1'r (e ji'.'l / 541,(ao 19‘ jp Ai �i�v �@ of P y f At/ t prod Oi i4 loo ��Z Pre -Ri g Work: (scheduled to begin August 15 2012) • 1. F MIT- IA to 3,000 psi, MIT -OA to 2,000 psi). 2. W Cycle LDS; PPPOT- T to 5,000 psi. 3. S Drift for 4W x 5W thru- tubing whipstock. 4. E Set 4W x 5W thru- tubing whipstock at 9,145' md. 5. E Mill XN profile at 8,890' and to 3.80 ". 6. V PT MV, SV, WV. Bleed wellhead pressures down to zero. 7. 0 Bleed production flow and GL lines down to zero and blind flange. 8. 0 Remove wellhouse, level pad. 9. V Set TVVC (4" 'H' profile) 24 hrs prior to rig arrival. Rig Work: (scheduled to begin September 1 2012) P 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" single string high side window in 5 -1/2" 17# 13Cr production liner from mechanical thru- tubing whipstock at 9,145' and and 10' of rathole. Swap the well to Power - Pro SF. 3. Drill build: 4.125" OH, 255' (30° /100 planned) with resistivity. 4. Drill lateral: 4.125" OH, 700' (12° /100 planned) with resistivity and land well in Sag River at 10,100' md. V 5. Run & cement 3 -1/4" TCII protection string leaving TOL at 8,880' md. 6. Drill lateral: 3.25" OH, 2,175' (30° /100 planned) with resistivity to a final TD at 12,275' md. 7. Run 2 -3/8" slotted liner and drop inside 3 -1/4" protection string. fr° 8. Freeze protect well to 2200' TVD. 9. Set BPV. ND BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. 10. RDMO Nordic Rig. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set 4 -1/2" KB liner top packer. 3. Generic GLV's. 4. RU well testers. Matthew Ross CTD Engineer 564 -5782 CC: Well File Sondra Stewman/Terrie Hubble TREE = 4-1/16" 5M CIW • $/•Y NOTES: CHROME TBG AND LNR I WELLHEAD = 11 "5MFMC S -37 ACTUATOR = OTIS KB. ELEV = 65' BF. ELEV = 32' KOP = 5654' I Max Angle = 34 @ 7177' 2228' I- -I4 -1/2" OTIS SSSV NIP, ID = 3.813" Datum MD = 9369' rW Datum TVD = 8800' SS 10 -3/4" CSG, 45.5 #, NT -80, ID = 9.953" H 2923' I A GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3018 3009 1 CAMCO DOME BK r 16 01/24/10 � 5 5104 5095 4 CAMCO DOME BK F 16 01/24/10 4 6712 6624 29 CAMCO DOME BK " 16 01/24/10 Minimum ID = 3.725" @ 8890' 3 7885 7612 33 CAMCO DOME BK ' 16 01/24/10 4 -1 /2" PARKER SWN NIPPLE 2 8333 7987 33 CAMCO DMY BK F 0 01/24/10 1 8438 8075 33 CAMCO SO BK 24 01/24/10 ' ' I 8777' H4-1/2" PKR SWS NIP, ID = 3.813" I g I 8837' H4-1/2" BKR PERM S -3 PKR, ID = 3.875" I ' I I 8870' 1-14-1 /2" PKR SWS NIP, ID = 3.813" I ' ' I 8890' 1-14-1/2" PKR SWN NIP, ID = 3.725" TOP OF 5 -1/2" LNR I 8$94' 4 -1/2" TBG, 12.6 #, NSCT 13CR, H 8902' I / \ I 8902' H4 -1/2" WLEG, ID = 3.958" .0152 bpf, ID = 3.958" I 8898' H ELMD TT LOGGED 02/08/93 I 17 -5/8" CSG, 29.7# NT- 95 -HS, ID = 6.875" H 9108' r I I PERFORATION SUMMARY REF LOG: SWS SONIC ON 11/03/92 I ANGLE AT TOP PERF: 31° @ 9115' Note: Refer to Roduction DB for historical perf data 9400' TOP OF CEMENTlSANDBACK SIZE SPF INTERVAL Opn /Sqz DATE A��•�■�•D�■^ I� 3 -3/8" 6 9115 - 9148 0 07/26/09 3 -3/8" 6 9255 - 9285 0 04/19/93 3 -3/8" 4 9255 - 9360 0 02/10/93 3 -3/8" 4 9418 - 9426 C 02/10/93 I PBTD I - I 9692' I �i'i'i'i�i ∎∎• I 5-1/2" LNR, 17 #, 13CR FL4S, .0232 bpf, ID = 4.892" I 9770' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/06/92 ORIGINAL COMPLETION 09/29/09 RRD /SV ADPERF (07/26/09) WELL: S -37 03/09/01 SIS -MH CONVERTED TO CANVAS 02/04/10 DAV /PJC GLV C!O (01/24/10) PERMIT No: 1920990 03/12/01 SIS -MD FINAL API No: 50- 029- 22291 -00 09/07/01 RN/TP CORRECTIONS SEC 35, T12N, T12E, 1684' FNL & 1929' FWL 06/03/03 MH/TLP GLV C/O (09/20/07) 07/09/09 HLS /SV TBG /LNR CORRECTIONS BP Exploration (Alaska) TREE _ /16" 5M CNV • WELLHEAD = 11" 5M FMC � • S w 7 J SOY NOTES: CHROME TBG AND LNR v{ ACTUATOR = OTIS KB. ELEV = N 65' proposed CTD sidetrack BF. ELEV = 32' KOP = 5654' Max Angle = 34 @ 7177' 2228' — 14 - 1/2" OTIS SSSV NIP, ID = 3.813" Datum MD = 9369' IIII Datum TVD = 8800' SS 10 -3/4" CSG, 45.5 #, NT-80. ID = 9.953" H 2923' , GAS LIFT MANDRELS STI MD I TVD DEV TYPE VLV LATCH PORT DATE ij 6 3018 3009 1 CAMCO DOME BK r 16 01/24/10 5 5104 5095 4 CAMCO DOME BK r 16 01/24/10 4 6712 6624 29 CAMCO DOME BK r 16 01/24/10 Minimum ID = 1.78" @ - 10000' 3 7885 7612 33 CAMCO DOME BK r 16 01/24/10 2 8333 7987 33 CAMCO DMY BK r 0 01/24/10 3" Deployment Sleeve 1 8438 8075 33 CAMCO SO BK r 24 01/24/10 TSGR = 9,106' MD 1 1 877T H4 - 1/2" PKR SWS NIP, ID = 3.813" IX X 8837' H4 BKR PERM S -3 PKR, ID = 3.875" ' ' I 8870' H4 PKR SWS NIP, ID = 3.813" I 3 -1/2" Liner Top Packer -- . — Top of 3 -1 liner at – 8,880' 32 ' / 1 8890' H4 - 1/2" PKR SWN NIP, ID = 3.80" 'milled out TOP OF 5-1/2" LNR —I 8894' • 4 -1/2" TBG, 12.6 #, NSCT 13CR, —I 8902' i 8902' H4 - 1/2" WLEG, ID = 3.958" .0152 bpf, ID = 3.958" 8898' — ELMD TT LOGGED 02/08/93 3 -1/2" x 3- 3/16" XO --A `-- 1 7 -5/8" CSG, 29.7# NT- 95 -HS, ID = 6.875" —I 9108' Top of 2 -3/8" slotted liner at –10,000' 4-1/2" x 5-1/2" TT whipstock at 9,145' 1* 31 1 2-3/8" slotted liner TD at 12,275' PERFORATION SUMMARY REF LOG: SVVS SONIC ON 11/03/92 ' 3- 3/16" shoe at 10,100' ANGLE AT TOP PERF: 31° @ 9115' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 9400' J TOP OFCENE]VT /SANDBACK 3 -3/8" 6 9115 - 9148 0 07/26/09 4 3 -3/8" 6 9255 - 9285 0 04/19/93 3 -3/8" 4 9255 - 9360 0 02/10/93 3 -3/8" 4 9418 - 9426 02/10/93 PBTD —I 9692' I '1fffff1 f 5 -1/2" LNR, 17 #, 13CR FL4S, .0232 bpf, ID = 4.892" l 9770' 1 ••• • ••• • •v v v � — DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/06/92 ORIGINAL COMPLETION 09/29/09 RRD /SV ADPERF (07/26/09) WELL: S -37A 03/09/01 SIS -MH CONVERTED TO CANVAS 02/04/10 DAV /PJC GLV C/O (01/24/10) PERMIT No: x1 920990 03/12/01 SIS -MD FINAL 02/29/12 WJH proposed CTD sidetrack API No: 50- 029 - 22291 -00 09/07/01 RN/TP CORRECTIONS SEC 35, T12N, T12E, 1684' FNL & 1929' FWL 06/03/03 MH/TLP GLV C/O (09/20/07) 07/09/09 HLS /SV TBG /LNR CORRECTIONS BP Exploration (Alaska) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM Choke Panel Standpipe 2" Circulation_ Line Driller Gauge .`� , M 10 �!� MM 11 MM 9 Manual Choke CIRCULATING MANIFOLD — :M , MM 20 •• El MM 22 O • •• � r re SLB Transducer — • MM 6 PVT Sensor • 7 -1/16" 5kpsi BOPE _ s _ • MEM - Air Blow down - • • lr MM . ® Blind Shears ` , Line • 'l - Baker Choke MM 15 � MM 4 MM 5 ..... MM 21 AS BUSTER • - 2-3/8" TOT PIS Combi • • Rev Cir Line \ III t R I , MM14 ••,• • \ \i ]1I18�'S 11 1I MM 12 .. l ;x II! w tow,. t -4 e. C4*- - ki .3,0 iMtI . _ i ' �� 1 BOP 24 111 ss 4----- 4----- Coded Tubing — 2 -318" - 3 -112" '11 II ;i VBR ram Baker Choke 2 -318" Combi MM 1 2 ..... • MP1 in • • MM 1 3 • , ,m •4 i 1- O Kill Line ' °" Outlet r- Cement Line to Ground Mud •2 in V . -■ Pu...s In a .. Tranducers COILED TUBING "noke t ine / / CIRCULATING SYSTEM Cellar S 9°°° Area . 1- 40 4% IAlnnr4 HP14 Flow cross'f To Inner Reel Outlets Valve --- -.♦ HP ,0 II HP7 HP3 — :I-I.' HP 2 HP 1 - HP 1 ' • 1 il • cement line N2 SLB NORDIC'S 2 1 Circulate Mani /old -1 11 CHOKE MANIFOLD in Cellar — _°W- HP 11 N2 TriFlow `; l f CM 85 qq��,, Gauge :II [ $lp' _I '• •� is Test Pump Inlet — ul �.n I,. 4 CM3 1 HDI Gauge CM18 In F • low f /lock row - To PITS O 4Way Block \ \CM CM1 CM8 C t 2 CM5 CM6 C ■ 11 IM Inlet u . Baker Choke Line from Baker Choke Line from wall KcR BAKER CHOKE LINE CM13 + — ' . ' CM7 — Baker Choke Line CM2 — CM19 • — use tot Micro Blowing CM 26 CM 29 Motion Back MM CM2O -lligl_ CM4 — CM21 M 4 — FLOW PATH + + • + Pi% CM 30 CHOKE LINE C M 75 CM 10 — T. Tige Tank CM 25 ® Outside • r • Page 1 of I Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and t./ operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS ~ ~~~~l~~~ 1(ll_ ~~, ~ ~r~~~i 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ Performed: Alter Casing ~ Puil Tubing ~ Perforate New Pool ~ Waiver~ Time,~k~io~~ ~jgg (;~~y ~~mm~~5~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~- Re-enter Suspended Well ~~ F 2. Operator BP Exploration (Alaska), inc. 4. Current Well Class: 5. Permit to Drill Number. rvame: De~elopment r~ Exploratory I~ ~s2-osso - 3. Address: P.O. Box 196612 Stratigraphic ~ Service (~ 6. API Number: Anchorage,AK 99519-6612 50-029-22291-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 69.3 KB - PBU S-37' 8. Property Designation: 10. Field/Pool(s): ADLO-028257 ~ PRUDHOE BAY Fieid/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9770 , feet Plugs (measured) None true vertical 9223.88 feet Junk (measured) None Ef~ective Depth measured 9692 feet true vertical 9142 feet Casing Length Size MD ND Burst Collapse Conductor 76 20" Surface - 141 Surface - 141 Surface 2923 10-3/4" 45.5# NT-80 Surface - 2923 Surface - 2910 5210 2480 Intermediate 9108 7-5/8" 29.7# NT-95-HS SurFace - 9108 Surface - 8637 8180 5120 Liner 876 5-1/2" 17# 13cr 8894 - 9770 8456 - 9219 7740 6280 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Verticai depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR SURFACE - 8902' 0 0 - Packers and SSSV (type and measured depth) 4-1/2" BKR PERM S-3 PKR 883T _. 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): .`~~ ~- ti s m~ ~ (~} ~(~ ~ ~ ~`wyr~;~1.'~.~~ zw~ tit~ #~; , 't,~~ ~~3~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbf Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 78 52 1617 220 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 1~ Development I~i - Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~- Gas ~ WAG ~ GINJ r WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Prebie Printed Name Gary Preble Title Data Management Engineer Signature ~ ~ _....,._ Phone 564-4944 Date 7/28/2009 Form 10-404 Revised 04/2006 ~~~ ~~ ~ S~ Submit Original Only ~ ~c~ ~.i ~ 2~0~ ~r ~~=..~/',~'/~ S-37 192-099 PERF ATTACHMENT C~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-37 2/10/93 PER 9,255. 9,279. 8,770.15 8,790.99 S-37 2/10/93 PER 9,279. 9,303. 8,790.99 8,811.85 S-37 2/10/93 PER 9,303. 9,327. 8,811.85 8,832.75 S-37 2/10/93 PER 9,327. 9,351. 8,832.75 8,853.68 S-37 2/10/93 PER 9,351. 9,360. 8,853.68 8,861.53 S-37 2/10/93 PER 9,418. 9,426. 8,912.27 8,919.28 S-37 4/19/93 RPF 9,255. 9,285. 8,770.15 8,796.2 S-37 7/26/09 APF 9,115. 9,128. 8,649.27 8,660.45 S-37 7/26/09 APF 9,128. 9,148. 8,660.45 8,677.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE . ~ ~ S-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ~- ~ 7/26/2009;"'*WELL SHUT~IN ON ARRNAL""* (E-LINE PERFORATE) ; ' ~INITIAL T/I/O: 1650/1650/0 PSI i , i ;PERFORATED FROM 9115'-9148' WITH 3 3/8" 3406 POWERJET HSD ~ ' lGUNS LOADED 6 SPF. API DIAMETER=0.37". PENETRATION=36.5". ; 'TUBING PRESSURE UNCHANGED AT 1600 PSI BEFORE AND AFTER 3 ~ ~PERFORATING. PAD OPERATOR ASKED TO POP WELL ON t sDEPARTURE. WELL SHUT IN ON DEPARTURE. ~ iSWA6 AND WING VALVES ARE CLOSED AND TREE CAP IS ; ; ~PRESSURE TESTED. MASTER IS OPEN. ~ ~ ~FINAL T/I/0=1600/1650/0 ~ ~ ~*"*JOB COMPLETE*''* ~ FLUIDS PUMPED BBLS 2 MEOH 1 diesel 3 Total ~ • bp BP Exploration (Alaska) Inc. ~ ' ~. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ` Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, .fi ~= ZraC~ ,, r ~ ;,,~°1~~~v ~ v ~. . , ~~~ Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion i~hibitor, Sealant Top-off Report of Sundry Operetions (10-404) S-pad Date 6/25/2009 Well Name PTD A Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Cortosion inhibitor Corrosion inhibitod sealant date f[ bbls ft na al 5-016 1952020 0.25 NA 025 NA 2.6 5/30/2009 S-o2A 1941090 0.25 NA 0.25 NA 1.7 5/25/2009 S-03 ~ 7811900 1325 NA 1325 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 19U230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 0.25 NA 0.25 NA 3 6/2/2009 S-17C 2020070 0.25 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1867160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA 025 NA 1.3 5/79/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1907270 025 NA 025 NA 7.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/37I2009 S-29A17 1960120 0 NA 0 NA 0.85 5/27/2009 S30 7900660 0.5 NA 0.5 NA 5.1 5/31/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5l26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 NA .BSin 5/31I2009 S36 1921160 0.75 NA 0.75 NA 425 5/27/2009 ~ S37 1920990 125 NA 125 NA 11.9 5/27/2009 S38 1921270 025 NA 025 NA 102 5/27/2009 S-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-700 2000780 2 NA 2 NA 21.3 5/29/2009 S-101 2001150 125 NA 125 NA 1~.9 5/29/2009 5-102L1 2031560 125 NA 1.25 NA 11.1 5/31/2009 5-~03 2001680 1.5 NA 1.5 NA i7.9 . 5/18/2009 5404 2001960 1.75 NA 175 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-tos 2010120 1625 NA 1625 NA 174.3 6/2/2009 S-107 2011130 225 NA 225 NA 28.9 5l18/2009 S-70e 2011000 3.5 NA 3.5 NA 40 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-710 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 5-111 2050510 2 NA 2 NA 19.6 5/30/2009 S-~ 12 2021350 0 NA 0 NA 0.5 5/30/2009 5-i13 2021430 1.75 NA 1.75 NA 22.7 5/18/2009 S-tiaA 2021980 7.25 NA 125 NA tOZ 5/30/2009 S-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2037870 1.5 NA 1.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-~te 2032000 5 NA 5 NA 76.5 5/28/2009 S-179 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-127 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-1Y2 2050810 3 NA 3 NA 21.3 5/29/2009 S-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1.75 NA 11.9 5/26/2009 S-t25 2070830 2.25 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 125 NA 15.3 6/7/2009 5-200 1972390 125 NA 125 NA 14.5 5/28/2009 5-201 2001&40 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 7s.7 6/1/2009 5-218 2001970 4.75 NA 4.75 NA 57 5/29/2009 5-217 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 76 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.85 5/28/2009 S-37 (PTD #1920990) Under Evalua. for sustained casing pressure - TxIA ¡mmunication Regg, James B (DOA) Page 1 of 1 From: o. ,q(ICt/ 07 '\ '--t'(i Sent: To: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Monday, September 17, 20076:00 AM Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; NSU, ADWWell Operations Supervisor; Rossberg, R Steven; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Roschinger, Torin T.; Austin, Paul A; Holt, Ryan P (ASRC); NSU, ADWWI Tech Subject: S-37 (PTD #1920990) Under Evaluation for sustained casing pressure - TxlA communication Attachments: S-37.pdf All, ./ Well S-37 (PTD #1920990) has been found to have sustained casing pressure on the IA. The TIOs were SSV/21 00/130 psi on 09/14/07. A subsequent TIFL failed on 09/16/07. The well has been classified as Under Evaluation and may be produced under a 28-day clock. The plan forward for this well is as follows: 1. D: TIFL - FAILED 2. S: Caliper & C/O GL Vs 3. D: Re-TIFL 5~ED SEP 2 1 1.007 A wellbore schematic has been included for reference. «S-37.pdf» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 9/19/2007 . TREE = 4-1/16"5MCIW W8...LHEAD = 11" 5M FMC A CTUð. TOR = OTIS KB. ELEV = 65' BF. ELEV = 32' KOP - 5654' Max An Ie = 7177' DatumMD= 9366' DatumTVD = 8800' SS 8-37 . 110-314" CSG, 45.5#, NT-80, ID = 9.953" H 2923' Minimum ID = 3.725" @ 8890' 4-112" PARKER SWN NIPPLE 4-1IZ' TOO, 12.6#, NSCT 13-CR, .0152 bpf, ID = 3.958" TOP OF 5-1IZ' LNR I 8894' 8902' 7-518" CSG, 29.7# NT-95-HS, ID= 6.875" ÆRFORA TON SUMMARY REF LOG: SWS SONIC ON 11/03/92 ANGLE AT TOP PERF: 31 @ 9255' No1e: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9255 - 9285 0 04/19/93 3-3/8" 4 9255 - 9360 0 02/10/93 3-3/8" 4 9418 - 9426 0 02/10/93 5-1/2"TBG, 17#, 13-CRFL4S, .0232 bpf, ID =4.892" D6. TE REV BY COMMENTS 11/06192 ORlGINA.L COMR.EOON 03109/01 SIS-MH CONVERTED TO CANV AS 03112/01 SIS-MD FINA. L 09/07/01 RN/TP CORRECll0NS 06103103 MHITLP GLV C/O DATE REV BY COMMENTS . SAFElY NOTES: 13 CR CHROME TaG AND LNR 2228' 4-1/2" 011S SSSV NIP, ID - 3.813" GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT D6.TE 6 3018 2940 0 CAMeO DOME BK 16 06103103 5 5104 5026 2 CAMeO DOME BK 16 06103103 4 6712 6555 29 CAMeO DOME BK 16 06103103 3 7885 7543 33 CAMeO DOME BK 20 06103103 2 8333 7917 33 CAMeO SO BK 06103103 1 8438 8005 33 CAMeO DIllY BK *GLM#2 -SOPORTSIZE7/16"X 1/4" Pù77' 4-1/2" PARKERSWS NIP, 0 =3.813" 8837' -17-5/8" BAKER ÆRMSABL-3 PKR I 8870' 4-1/2" PARKERSWS I\IP, 0=3.813" 8890' 4-1/2" PARKER SINN NIP, 0 = 3.725" 8902' 8898' 9400' HTOPOF CEMENT/SANDBACK I PRUDHOE BAY UNIT WELL: S- 37 PERMIT JIb: 1920990 API JIb: 50-029-22291-00 SEC 35, T12N, T12E, 1684' FNL & 1929' FWL BP Exploration (Alaska) PERMIT DATA 92-099 5553 92-099 5463 92-099 SURVEY 92-099 DWOP 92-099 407 92-099 SSTVD 92-099 SBT/CCL/GR 92-099 PROD AOGCC Individual Well Geological Materials Inventory T DATA_PLUS T 9028-9680 CH/CN/GR 1 T 8079-9779 BCS/DTE & CH/GR 1 R 0-9044 MWD SPERRY SUN R 10/23-11/06/92 R COMP DATE:02/ll/93 L 9105-9754 L 8850-9675 L 9100-9590 92-099 PLS L 9110-9628 92-099 PISFL L 9105-9754 92-099 PFC/GR/CCL L 8350-9660 92-099 PFC L 9252-9596 92-099 PFC L 9150-9660 92-099 CNL/GR 92-099 BHC/SL/GR L 9050-9684 L 8100-9726 Are dry ditch samples required? yes ~n%~ And received? Was the well cored? yes /~o~ Analysis & description received? Are well tests required?~/~yes~ Received? yes~ Well is in compliance //~('-j COMMENTS Page' 1 Date: 01/09/95 RUN DATE_RECVD 03/15/93 11/25/92 03/25/93 03/25/93 03/25/93 1 11/18/92 1 02/18/93 1 04/05/93 1 04/29/94 1 11/18/92 I 02/22/93 1 04/12/93 1 03/01/93 1 02/18/93 1 11/18/92 yes n~ yes~ STATE OF ALASKA ALAS"'~'OIL AND GAS CONSERVATION COMMISSIC .... REPORT OF SUNDRY WELL OPEhATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging Pull tubing i Alter casing Repair well__ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1684' SNL, 1929' EWL, SEC. 35, T12N, R12E At top of productive interval 2038' SNL, 1534' WEL, SEC. 35, T12N, R12E At effective depth 2083' SNL, 1353' WEL, SEC. 35, T12N, R12E At total depth 2133' SNL, 1284' EWL, SEC. 35, T12N, R12E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=69.3' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-37(32-35-12-12) 9. Permit number/approval number 92-99 / 10. APl number 50- 029-22291 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 76 2923 9770 feet Plugs (measured) 9208 feet 9692 feet Junk (measured) 9142 feet Size Cemented 20 11 yds Arcticset 10 3/4 1756/500 c.f /I//I 7 5/8 1305 c.f C/ass "G" -. 876 measured 5 1/2 157 c.f. Class "G" 9255'- 9360', 9418'- 9426' Measured depth 141 2923 9106 8894-9770 True vertical depth BKB 141 2910 8637 8456-9219 true vertical subsea 8768'- 8858', 8908'- 8914' Tubing (size, grade, and measured depth) 4 1/2", 13 CR @8902' Packers and SSSV (type and measured depth) Packer 75/8" SABL-3 @8837' 13. Stimulation or cement squeeze summary See Attachment RECEIVED 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 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1640 1699 432 1093 2009 /'~- 2956 2972 1808 Tubing Pressure 262 164 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended 7. I hereby certify that the foregoinaqs.true and correct to the best of my knowledge. Si~ned ~_., ~.{~,+-S.~.~,~1 ~/// ~'~£C'~) TitleSeniorTechnicalAssistantl Form 10-404 Rev 06/15/88 ,/ Service Date ,~/~//?',/¢ 1 SUBMIT IN D~PLfCATE 4/19/93 4/25/93 fjh 6/20/94 WELL S-37(32-35-12-12) REPERF/FRAC The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9255'-9285'MD Performed a Hydraulic Fracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: DATA FRAC: 135 138 20 FRAC: 20 102 36 7 10 12 14 15 16 27 103 70 16 316 BBLS 20# GEL 20 BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK GEL PAD W/5.5% ESL (320 GAL) BBLS 20# GEL DATA FRAC FLUSH BBLS DSL TO FREEZE PROTECT WELL BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK GEL PAD W/*.*% ESL (*** GAL) Dirty 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 8 PPG 20/40 8 PPG 16/20 10 PPG 20# LINEAR GEL FLUSH LOAD VOLUME: 1077 (TOTAL FLUIDS PUMPED DOWN HOLE) 75 100 Total diesel pumped downhole Diesel Recovered REC."EIVED APfl 9 1-994 Atad~ Oil & 13as C~s. ~m~t~ ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: Sent by: 21 April 1994 Transmittal of Data Dear Sir/Madam, Enclosed, please find the data as described below: WELL s-34 DESCRIPTION PLS STATIC FINAL BL 1 PLS STATIC RF SEPIA PLS STATIC FINAL°BL 1 PLS STA~ RF SEPIA s-20 C~ ~,__Oi,~ S-37 (32-35-12-12) t PLS STATIC FINAL BL /1 PLS STATIC RF SEPIA / ?1 PLS STATIC FINAL BL PLS ST~ RF SEPIA /1 PLS STATI/C FINAL BL 1 PLS S~2~TIC RF SEPIA 0-0% D-11 1 PLS STATIC FINAL BL /1 PLS SEPIA ~IPLS STATI~,C~FINAL BL PLS ST4KTIC RF SEPIA ~t--~-~ M-04 (23-31-12-13) 1 PLS STATIC FINAL BL /1 PLS S~C RF SEPIA 8 3-/3~- R-23 (42-33-12-13) 1PLS STATIC FINAL BL PLS STSC RF SEPIA ~---100 U-14 (11-20-11-13) 1 PLS STATIC FINAL BL 1 PLS STATI'C RF SEPIA ~'©~l~-, F-14 (33-35-12-13) .1 CN/GR FINAL BL /1CN/GR FINAL RF SEPIA 1PFC/GR/CCL FINAL BL PFC/GR/CCL RF SEPIA Run # 1 Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run ~ 1 Run ~ 1 Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 5856.06 2187.03 6169.00 6173.00 5879.06 5617.05 4880.03 2097.05 6102.01 6014.02 5810.02 959.04 Cont/ ~--~ C-38 (41-18-11-14) ~5~ D-27 (24-14-11-13) 1~ PFC/PERF FINAL BL 1 PFC/PERF FINAL BL /1 PFC/P~.RF RF 1~ P~.S STAT¢C FCNAL /1 P~S S~C RF 1PL STATIC FINAL BL ]~L~STATIC RF SEPIA 1PLS FINAL BL 1 PLS FINAL RF SEPIA Run # 1 5785.02 Run # 1 Run # 1 5132.01 Run # 1 Run # 1 4979.03 Run # 1 Run # 1 6162.00 Run # 1 Run # 1 5783.03 Run # 1 . Please sign and return to: Atlas Wireline Services ~'~ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/27/93 T# 84513 BP/PBU~OGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 4 [,IS ~,~"~ - 3 3 PRODUCTION LOG -07A PFC '~ ~-33 ,.(A PFC ),' ~;-S- 3 3 .~\PDK-100 S- 3 7 q0 PFC 04/22/93 #1 04/21/93 #1 04/19/93 #1 04/20/93 #1 03/28/93 #1 04/19/93 #1 10665.00-10901.00 ATLAS 5 " 10900.00-11350.00 ATLAS 5 " 10710.00-11100.00 ATLAS 5 " 9163.00- 9232.00 ATLAS 5 " 9000.00- 9270.00 ATLAS 5 " 9252.00- 9596.00 ATLAS 5 Information Control Well Records BP EXPLORATION .. · BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/01/93 T# 84417 BP/PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ~b.~~- 10 PRODUCTION LOG ~,~- 18 PFC ~'~"~-~1-02¢4~ PRODUCTION LOG ~-08 PRODUCTION LOG ~-~ ~P-O 6 PRODUCTION LOG ~-%'~-04 PERF _'~'~,~ 5-37 PRODUCTION LOG ~~- ~ ~ PRODUCTION LOG ~~-11 PRODUCTION LOG ~~X-14A PDK-100/GR Information Control Well Records 03/24/93 #1 03/30/93 #1 03/25/93 #1 03/21/93 #1 03/29/93 #1 03/25/93 #1 03/23/93 #1 03/26/93 #1 03/22/93 #1 03/22/93 #1 03/27/93 #1 11000.00-11400.00 9350.00- 9595.00 9900.00-10190.00 12050.00-12460.00 9950,Q0-10300.00 ' - 9500.00- 9782.00 9100.00- 9590.00 9750.00-10080.00 9000.00- 9680.00 9000.00- 9680.00 11550.00-12000.00 ATLAS 5" ATLAS' 5" ATLAS 5" ATLAS 5" ATLAS 5" ATLAS 5" ATLAS 5" ATLAS 5" ATLAS 5" ATLAS 5" ATLAS 5" RECEIVED APR 0 5 1993 Alaska 011 & Gas Cons. Commission Anchorage I G I N A L ALASKA OIL AND GAS GONSfiRVATION GOMM WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEhE)ED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 92-99 3. Address 8. APl Number P. O. Box 196612, Anchora~Te, Alaska 99519-6612 50- 029-22291 4. Location of well at surface .-.-. ......... 9. Unit or Lease Name 1684' SNL, 1929' EWL, SEC. 35, T12N, R12E Prudhoe Bay Unit At Top Producing Interval ~ l : ~;~:,~- ~ 10. Well Number S-37 (32-35-12-12) 2038' SNL, 1534' WEL, SEC. 35, T12N, R12E At Total Depth ............ ~':.~ -~ ....... ' ....... Prudhoe Bay Field/Prudhoe Bay Pool 2133' SNL, 1284' WEL, SEC. 35, T12N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 69.3' I ADL 28257 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [15. Water Depth, if offshore 116. No. of Completions 10/22/92 11/2/92 2/10/93I N/Aeet MSL ! One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey p0. Depth where SSSV set 21. Thickness of Permafrosl 9770' MD/9208' TVD 9692' MD/9142' 7'VD YES [] t,D []! 2228¢eet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/BHC/GR/RD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' 91.5# H-40 Surface 76' 30" 11 ,vds Arcticset 10-3/4"' 45.5# NT-80 36' 2923' 13-1/2" 1756 cu ft AS 111/500 cuft AS I 7-5/8' 29.9# NT95HS 32' 9106' 9-7/8" 1305 cu ft Class "G" 5-1/2' 17# 13CR80 8894' 9770' 6-3/4" 157 cuft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET(MDI Gun Diameter 3-3/8" 4spf 4-1/2", 13CR 8902' 7-5/8"SABL-3 @ 8837' MD TVD 9255'-9360' 8768'-8858' 9418'-9426' 8908'-8914' 26. ACID, FRACTURE, CEMENT SQUEF_Z~, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 2/11/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S[ZE IGAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Alaska 0il & Gas Cons. C~)rnrnissio~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS ~-~,RIVIATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, ME/kS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9106' 8641' Shublik 9150' 8679' Top Sadlerochit 9255' 8768' Alaska Oil & Gas Cons, Corr~l~Jssior~ AnChorago 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge , 'x V: Signed :t~ Title Drilling Engineer Suoervisor 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 injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: S-37 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/22/92 10:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 10/23/92 (1) TD: 900' ( 900) 10/24/92 ( 2) TD: 2932'(2032) 10/25/92 (3) TD: 2932' ( 0) 10/26/92 ( 4) TD: 4150' (1218) 10/27/92 (5) TD: 5460'(1310) 10/28/92 (6) TD: 6875'(1415) 10/29/92 (7) TD: 7925' (1050) 10/30/92 (8) TD: 9035'(1110) 10/31/92 ( 9) TD: 9117' ( 82) DRILLING MW: 8.9 VIS:320 MOVE IN & RIG UP RIG. TAKE ON WATER. DRILL TO 310' FLOW LINE JET PROBLEMS CAUSING FLOW LINE TO PLUG OFF. DRILL TO 900' CIRCULATE AT TD MW: 9.4 VIS:252 DRILL TO 1971'. WIPER TRIP TO 850'. DRILL TO 2511' WIPER TRIP TO 1420' DRILL TO 2932' CASING POINT. CBU. TEST BOPE & ANNULUS MW: 9.6 VIS: 56 CIRCULATE. WIPER TRIP. PUMP SWEEP & CIRCULATE. DROP SINGLE SHOT SURVEY & PUMP DRY JOB. RUN 10-3/4 CASING. CEMENT. PERFORM TOP JOB. TEST BOPE & ANNULUS. DRILLING MW: 9.7 VIS: 40 TESTING BOPE. SAFETY MEETING. CBU. TEST CASING. CIRC. DRILL FLOAT SHOE. PERFORM LEAK OFF TEST. DRILL TO 4013'. WIPER TRIP. DRILL TO 4150' DRLG. MW:10.0 VIS: 38 DRLG F/ 4150'-4933'. CBU. POOH. RIH W/ BHA. WASH F/ 4843'-4933' DRLG F/ 4933'-5460'. DRLG. MW:10.3 VIS: 44 DRLG F/ 5460'-5944' CBU. SHORT TRIP 10 STDS. DRLG F/ 5944'-6875' DRILLING AT 7925 MW:10.3 VIS: 42 DRILL TO 7275' DROP SURVEY. POH. TEST BOP. RIH TO 7177' WASH TO 7275' DRILL TO 7925' DRLG. MW:10.3 VIS: 44 DRLG F/ 7925'-8885' CBU. POOH. TEST BOPE. RIH. WASH F/ 8800'-8885' DRLG F/ 8885'-9035' RUNNING 7-5/8 CASING MW:10.3 VIS: 44 DRILLED TO 9117'. CBU. SHORT TRIP TO 6455'. CBU & PUMP PILL. CHANGE RAMS TO 7-5/8. PULL WEAR RING. INSTALL TEST PLUG & TEST BOPE. RUN 7-5/8 CASING. Gas Oons. Commission Anchorage WELL : S-37 OPERATION: RIG : NABORS 28E PAGE: 2 11/01/92 (10) TD: 9117' ( 0) 11/02/92 (11) TD: 9540' ( 423) 11/03/92 (12) TD: 9770'( 230) 11/04/92 (13) TD: 9770' ( 0) 11/05/92 (14) TD: 9770 PB: 9692 PU 3-1/2 DP MW:10.2 VIS: 37 RUN 7-5/8 HANGER & CEMENT HEAD. CIRC & RECIPROCATE PIPE. TEST CEMENT LINES. TEST PACKOFF. CHANGE RAMS & KELLY TO 3-1/2. TEST BOPE. INSTALL WEAR RING. PU 3-1/2 DP. DRILLING AT 9540 MW: 9.2 VIS: 40 TEST 7-5/8 CASING. DRILL OUT FLOAT COLLAR & CEMENT TO 9105' TEST 7-5/8 CASING. DRILL OUT SHOE, CEMENT & NEW HOLE TO 9127'. CIRC & CONDITION MUD. DRILL TO 9228' POH TO 7-5/8 SHOE RIH TO 9226'. DRILL TO 9540' RIH - WIPER TRIP MW: 9.2 VIS: 42 DRILLED TO 9665'. REPLACE ROTARY CHAIN. DRILL TO 9770' CIRC. SHORT TRIP TO 7-5/8 SHOE. CBU. DROP SURVEY. RUN ~1 DIL/BHC/GR & RD. RIH. TRIP MW: 9.1 VIS: 39 RIH FOR WIPER TRIP. CIRC. PUMP DRY JOB. POH. RUN 5-1/2 LINER & HANGER. RIH W/LINER ON 3-1/2 DP. CIRC & COND. PUMP CEMENT. BUMPER PLUG. SET LINER HANGER & PACKER. RELEASED FROM LINER. REVERSE CIRC. RUN COMPLETION MW: 8.4 Seawater TIH. CBU. TEST CASING. RETEST LINER. CIRC. POOH. RU & RUN 4-1/2 COMPLETION. 11/06/92 (15) TD: 9770 PB: 9692 RIG RELEASED MW: 8.4 Seawater RUN 4-1/2 COMPLETION. TEST CONTROL LINES. LAND TUBING. SET PACKER & TEST TUBING. TEST TUBING ANNULUS. SET BPV. ND BOPE. NU TREE. TEST CONTROL LINES. TEST TREE. FREEZE PROTECT TREE. SET BPV. SECURE WELL. RELEASED RIG 24:00 HRS. 11/5/92. SIGNATURE: (drilling superintendent) DATE: . .qiask,q ~)iJ & 6',itc', Cons. Anchora~ls SP"'-"~'RY-SUN DRTLLTNG SERVTCES '~"~1~'""~'~ PAGE ANCHORAGE ALASKA PRUDHOE BAY DRZLLZNG PBU/S'37 500292229100 NORTH SLOPE COMPUTATZON DATE: 11/ 6/92 DATE OF SURVEY: 10/31/92 MWD SURVEY JOB NUMBER: AK-MW-20082 KELLY BUSHZNG ELEV. = 69.30 FT. OPERATOR: BP EXPLORATZON TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH COURS COURSE DL ZNCLN DZRECTZON DG MN DEGREES DG/1 S TOTAL RECTANGULAR COORDZNATES VERT. O0 NORTH/SOUTH EAST/WEST SECT. 0 .00 -69.30 372 372.00 302.70 392 392.00 322.70 541 540.98 471.68 630 629.93 560.63 0 0 N .00 E 0 12 S 30.50 E 0 6 N 15.30 E 1 12 N 25.10 E 2 30 N 36.20 E .00 .OON .OOE .00 .05 .56S .33E .43 1.40 .57S .35E .45 .74 .97N 1.05E .86 1.51 3.38N 2.59E 1.94 722 721.76 652.46 811 810.40 741.10 907 905,76 836,46 1002 999,96 930.66 1099 1096,02 1026.71 4 18 N 48,50 E 5 54 N 43.60 E 7 11 N 38.60 E 7 41 N 44.50 E 8 18 N 42.10 E 2.10 7.28N 6.36E 4.94 1.86 12.80N 12.01E 9.50 1.48 21.08N 19.17E 15.04 .96 30.27N 27.34E 21,42 .71 40.10N 36.59E 28.74 1193 1189,09 1119.79 1289 1284,15 1214.85 1382 1376.23 1306,93 1479 1472.33 1403,03 1575 1567,61 1498.31 7 48 N 34.70 E 8 11 N 29.9O E 8 0 N 31,00 E 7 35 N 31.90 E 6 24 N 28.20 E 1.22 50.38N 44.77E 34.93 ,81 61.67N 51.89E 39,89 .27 72,97N 58,53E 44,38 ,43 84.20N 65.40E 49.10 1.33 94.30N 71.28E 53.06 1670 1662,16 1592.86 1765 1756,97 1687.67 1861 1852,91 1783.61 2051 2042,81 1973,51 2243 2234,72 2165,42 4 35 N 26.80 E 2 12 N 16.40 E 1 42 N 10.90 E 2 5 N 17.90 E 1 6 N 21.00 E 1.90 102.37N 75.50E 55.76 2.60 107.52N 77.73E 57.02 .56 110.68N 78,52E 57,23 .24 116.76N 80.12E 57,70 .52 121,83N 81.87E 58.50 2428 2419.69 2350.39 2655 2646.64 2577.34 2854 2845.60 2776.30 2986 2977,58 2908,28 3271 3262.56 3193.26 1 12 N 22.80 E 1 6 N 18.70 E 1 6 N 14.40 E 0 54 N 4.60 E 0 24 N 10,70 W .06 125.28N 83.25E 59.24 .06 129.53N 84.87E 60.07 ,04 133.19N 85.96E 60,48 ,20 135.45N 86.36E 60,46 .18 138.66N 86.35E 59.87 3559 3550.55 3481.25 3845 3836.52 3767.22 4130 4121.49 4052,19 4417 4408.48 4339.18 4703 4694,48 4625,18 0 48 S 74.90 W 0 48 S 83.20 W 0 42 S 65.40 W 0 6 S 23.00 E 0 0 N .00 E · 32 139.12N 84.23E 57.70 .04 138.37N 80.32E 53.99 ,09 137.41N 76.76E 50.66 ,25 136.45N 75.26E 49.36 ,04 136.22N 75.36E 49.50 4859 4850,48 4781,18 0 18 N 28.50 E 4923 4914.48 4845,18 0 30 N 36.30 E 5050 5041.40 4972.10 3 17 N 87.20 E 5177 5168,13 5098,83 4 11 S 83,40 E 5273 5263.86 5194.56 4 18 S 83.60 E · 19 136.58N 75.55E 49.63 .32 136.95N 75.80E 49.80 2.37 137.57N 79.78E 53.60 .86 137.22N 88.05E 61.80 .11 136.41N 95.12E 68.90 SF~'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/S'37 500292229100 NORTH SLOPE COMPUTATION DATE: 11/ 6/92 DATE OF SURVEY: 10/31/92 MWD SURVEY JOB NUMBER: AK-MW-20082 KELLY BUSHING ELEV. = 69.30 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/NEST VERT. SECT. 5368 5358.45 5289.15 6 11 S 76.90 E 2.10 134,85N 103.65E 5527 5516,23 5446,93 7 54 S 78,50 E 1,08 130.73N 122,72E 5654 5641.55 5572,25 10 41 S 77,30 E 2.21 126,40N 142.78E 5780 5764,91 5695,61 12 41 S 74,10 E 1,67 120,03N 167.51E 5876 5858.06 5788.76 15 11 S 73,40 E 2.61 113.54N 189,72E 77.58 97.08 117.59 143,06 166,08 5939 5918.52 5849.22 17 23 S 71.70 E 3.57 108.23N 206.58E 6034 6008,62 5939,32 19 30 S 71.70 E 2,21 98.79N 235.12E 6129 6097.50 6028.20 21 47 S 73.80 E 2.54 88.89N 267.11E 6225 6186,38 6117,08 22 36 S 72,40 E 1.00 78.34N 301.81E 6320 6273,76 6204.46 23 36 S 73,10 E 1.09 67.29N 337.41E 183,62 213,40 246.65 282,69 319.69 6415 6360,40 6291.10 24 47 S 73,20 E 1.26 56.00N 374.68E 6512 6447,80 6378.50 26 36 S 76.10 E 2.26 44.91N 415,23E 6606 6531.15 6461,85 28 30 S 81,50 E 3.34 36.53N 457.85E 6702 6615,23 6545,93 29 12 S 81,30 E ,74 29,61N 503.65E 6797 6697,87 6628.57 29 53 S 81.70 E .77 22.68N 549.99E 358.39 400.28 443.71 490.01 536.84 6893 6780,97 6711.67 30 12 S 81,30 E .38 15,58N 597.53E 6989 6863.20 6793,90 31 53 S 83,10 E 2.02 8.88N 646.58E 7082 6941,86 6872.56 32 35 S 82,60 E .81 2.70N 695.82E 7177 7021,10 6951,80 34 24 S 75.50 E 4,54 7.32S 747.20E 7334 7151,41 7082,11 33 24 S 71,50 E 1.56 32.14S 831,12E 584.88 634,33 683,88 736.23 823.25 7461 7257,62 7188,32 33 5 S 73,20 E ,77 53.25S 897,47E 7586 7362,27 7292,97 33 12 S 73,10 E ,09 73,07S 962.89E 7773 7518,57 7449,27 33 24 S 73,80 E .23 102.31S 1061,30E 7963 7677,46 7608.16 33 5 S 75,20 E .43 130.15S 1161,68E 8152 7835,52 7766,22 33 24 S 73,80 E ,44 157,85S 1261.53E 892.32 960.24 1062,31 1166,07 1269.28 8341 7993,40 7924,10 33 17 S 72,00 E .53 188,39S 1360,83E 8589 8201.50 8132.20 32 35 S 70.40 E .45 231~84S 1488.51E 8811 8389.45 8320,15 31 42 S 69.60 E .45 272.23S 1599,52E 8937 8496.77 8427,47 31 30 S 70,00 E .23 295,03S 1661,48E 9044 8588,15 8518.85 31 12 S 68.30 E .87 314,84S 1713.50E 1372,47 1505.90 1622.38 1687,44 1742,18 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD, HORIZONTAL DISPLACEMENT = 1742,18 FEET AT SOUTH 79 DEG, 35 MIN, EAST AT MD = 9044 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 100,41 DEG, SP~-~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/S-37 500292229100 NORTH SLOPE COMPUTATION DATE: 11/ 6/92 DATE OF SURVEY: 10/31/92 JOB NUMBER: AK-MW-20082 KELLY BUSHING ELEV. = 69.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINAT NORTH/SOUTH EAST/WE ES MD-TVD VERTICAL ST DIFFERENCE CORRECTION 0 ,00 -69.30 .00 N .00 1000 997.98 928.68 30.08 N 27.15 2000 1991.84 1922,54 114,99 N 79,55 3000 2991.58 2922.28 135,67 N 86.38 4000 3991,50 3922.20 138.07 N 78.20 E .00 E 2.02 2.02 E 8,16 6.14 E 8,42 .26 E 8.50 .08 5000 4991,46 4922.16 137.39 N 77,42 6000 5976.57 5907,27 102.35 N 224.35 7000 6872.54 6803.24 8,18 N 652.35 8000 7708.46 7639.16 135,31 S 1181,21 9000 8550,51 8481.21 306.41 S 1692,32 E 8.54 .04 E 23.43 14.89 E 127.46 104.02 E 291.54 164.08 E 449.49 157.94 9044 8588.15 8518,85 314.84 S 1713,50 E 455.85 6.36 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SF'-~'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/S'37 500292229100 NORTH SLOPE COHPUTATION DATE: 11/ 6/92 DATE OF SURVEY: 10/31/92 JOB NUMBER: AK-MW-20082 KELLY BUSHING ELEV. = 69.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR DEPTH DEPTH DEPTH NORTH/SOUTH COORDINATES EAST/NEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -69,30 .00 N .00 E .00 69 69,30 .00 .00 N .00 E ,00 .00 169 169.30 100,00 ,00 N .00 E ,00 .00 269 269.30 200,00 .25 S .15 E ,00 .00 369 369.30 300.00 .55 S .32 E .00 .00 469 469.30 400.00 .33 S .44 E .00 .00 569 569.30 500.00 1.50 N 1.30 E .02 ,02 669 669.30 600.00 4.79 N 3.66 E .11 .09 769 769.30 700,00 9,81 N 9.13 E .39 ,28 870 869.30 800.00 17,48 N 16,29 E .95 .55 971 969,30 900,00 27.31 N 24,44 E 1.76 .81 1072 1069.30 1000.00 37,21 N 33.98 E 2,70 .94 1173 1169,30 1100.00 48.15 N 43,23 E 3,73 1.03 1273 1269,30 1200.00 59,81 N 50.82 E 4,69 .97 1375 1369,30 1300.00 72,13 N 58,03 E 5.71 1.01 1475 1469.30 1400.00 83.85 N 1576 1569.30 1500.00 94,47 N 1677 1669,30 1600.00 102.88 N 1777 1769.30 1700,00 107,97 N 1877 1869,30 1800.00 111,16 N 65.18 E 6.65 .94 71.37 E 7.40 .76 75,76 E 7.87 .46 77,87 E 8.04 .17 78,61 E 8.09 ,05 1977 1969,30 1900.00 114,20 N 2077 2069,30 2000.00 117.69 N 2177 2169,30 2100.00 120,66 N 2277 2269,30 2200,00 122.45 N 2377 2369,30 2300,00 124,30 N 79 8O 81 82 82 .3O E 8.14 .O5 .42 E 8,21 .07 ,42 E 8.26 .O5 .10 E 8.28 .02 .84 E 8,30 .02 2477 2469,30 2400,00 126.23 N 2577 2569.30 2500.00 128,12 N 2677 2669.30 2600,00 129.94 N 2777 2769,30 2700,00 131,77 N 2877 2869,30 2800.00 133.63 N 83.66 E 8.32 .02 84,40 E 8.34 .02 85.01 E 8.36 ,02 85.60 E 8,38 ,02 86.07 E 8.40 ,02 2977 2969,30 2900,00 135,32 N 3077 3069.30 3000.00 136,89 N 3177 3169.30 3100.00 138.02 N 3277 3269.30 3200.00 138,71 N 3377 3369.30 3300,00 139,39 N 86.35 E 8.41 .02 86.47 E 8.43 ,01 86,47 E 8.43 .01 86.34 E 8,44 .00 86.21 E 8.44 ,00 SP~RY-SUN DRZLLZNG SERVZCES .... ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLTNG PBU/S-37 500292229100 NORTH SLOPE CONPUTAT:[ON DATE: 11/ 6/92 DATE OF SURVEY: 10/31/92 JOB NUMBER: AK-MW-20082 KELLY BUSHZNG ELEV. = 69,30 OPERATOR: BP EXPLORATZON FT. ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASD DEPTH TRUE SUB-SEA TOTAL VERTZCAL VERTZCAL RECTANGULAR COORDZNATES DEPTH DEPTH NORTH/SOUTH EAST/WEST DZFFERE TVD VERTZCAL NCE CORRECTZON 3477 3577 3677 3777 3877 3469.30 3400.00 139.42 N 85 3569.30 3500.00 139.06 N 83 3669.30 3600,00 138,69 N 82 3769,30 3700.00 -138,48 N 81 3869,30 3800.00 138,31 N 79 .32 E 8.45 ,01 .97 E 8.46 .01 .63 E 8.47 ,01 ,25 E 8.47 .01 ,86 E 8,48 .01 3977 4077 4177 4277 4377 3969,30 3900,00 138,15 N 78 4069.30 4000.00 137.67 N 77 4169,30 4100.00 137.16 N 76 4269,30 4200.00 136,68 N 75 4369,30 4300.00 136,51 N 75 .47 E 8.49 .01 ,34 E 8.50 .01 .23 E 8.51 .01 .18 E 8.52 .01 .23 E 8.52 .00 4477 4577 4677 4777 4877 4469.30 4400,00 136,35 N 75 4569.30 4500.00 136,22 N 75 4669.30 4600.00 136.22 N 75 4769.30 4700.00 136.22 N 75 4869.30 4800.00 136.66 N 75 .30 E 8.52 .00 .36 E 8.52 .00 .36 E 8.52 .00 .36 E 8.52 .00 ,60 E 8.52 .00 4977 5077 5178 5278 5378 4969,30 4900,00 137.28 N 76 5069.30 5000.00 137.65 N 81 5169,30 5100,00 137.21 N 88 5269,30 5200,00 136,37 N 95 5369,30 5300,00 134.59 N 104 .71 E 8.53 .01 .38 E 8.64 .12 .14 E 8.88 .23 .52 E 9,15 .28 .80 E 9,61 .46 5479 5580 5682 5784 5887 5469.30 5400.00 132.03 N 116 5569.30 5500.00 129.10 N 130 5669.30 5600.00 125,24 N 147 5769,30 5700.00 119,76 N 168 5869.30 5800,00 112,67 N 192 ,34 E 10.32 .71 ,48 E 11.36 1.04 .90 E 12.94 1.58 .46 E 15.20 2.26 ,65 E 18,35 3.15 5992 6098 6206 6315 6424 5969.30 5900.00 103.13 N 221 6069,30 6000.00 92,03 N 256 6169.30 6100.00 80,49 N 295 6269,30 6200.00 67,85 N 335 6369,30 6300.00 54.81 N 378 .99 E 23.02 4.67 ,29 E 29,33 6.31 .04 E 37,20 7.87 ,55 E 45.84 8.63 .61 E 55.50 9.66 6536 6649 6764 6879 6996 6469.30 6400.00 42.44 N 6569,30 6500.00 33.46 N 6669,30 6600,00 25.05 N 6769,30 6700,00 16.60 N 6869.30 6800.00 8.42 N 425,84 E 66,80 11.30 478.38 E 80,13 13.33 533.73 E 94,74 14.61 590.82 E 110,20 15.46 650.35 E 126.88 16.68 S~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 PRUDHOE BAY DRILLING PBU/S-37 500292229100 NORTH SLOPE COMPUTATION DATE: 11/ 6/92 DATE OF SURVEY: 10/31/92 JOB NUMBER: AK-MW-20082 KELLY BUSHING ELEV. = 69.30 OPERATOR: BP EXPLORATION FT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA HEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST DIFF MD-TVD VERTICAL ERENCE CORRECTION 7114 6969.30 6900.00 .01 S 713,37 E 145.39 18.51 7235 7069.30 7000,00 15,59 S 779,15 E 166.11 20,73 7355 7169,30 7100.00 35,88 S 842,31 E 186.13 20.02 7474 7269,30 7200,00 55.45 S 904.76 E 205.65 19.52 7594 7369.30 7300.00 74,40 S 967.29 E 225.10 19.45 7713 7469.30 7400.00 93.25 S 1030.10 E 244.68 19.59 7833 7569,30 7500.00 111,64 S 1093.42 E 264.47 19.78 7953 7669.30 7600.00 128,79 S 1156,53 E 283.96 19.49 8072 7769,30 7700,00 145,67 S 1219,60 E 303.38 19,42 8192 7869,30 7800.00 164.06 S 1282.92 E 323.16 19.78 8312 7969.30 7900.00 183.50 S 1345.77 E 342.87 19.71 8431 8069.30 8000.00 203.80 S 1408.24 E 362,51 19,65 8550 8169,30 8100,00 224.93 S 1469.11 E 381.48 18,96 8669 8269.30 8200.00 246.39 S 1529.35 E 400,18 18,70 8787 8369,30 8300.00 267.90 S 1587.85 E 418.01 17.83 8904 8469,30 8400.00 289.27 S 1645,66 E 435.48 17,47 9021 8569.30 8500,00 310,62 S 1702.89 E 452.66 17,18 9044 8588.15 8518.85 314.84 S 1713.49 E 455.85 3.19 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS BP EXPLORATION RECEIVED MAR I 5 1995 Alaska 0il & 6~s Cons, Commission Anchorage BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03/11/93 T# 84357 BP/PBU CH MAGNETIC TAPE Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. S-37 CH/CNL FIN 02/07/93 #1 9028.00- 9680.00 1600BPI API#500292229100 9263->TP# ATLAS REF#5879.02 Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 02/22/93 T# 84335 BP/ PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. J-23%~ .~Q PRODUCTION LOG' ,.--. ~-05"~ '"' ~ P~C P- 1 4 64'¥~. CCL S-376~~ PFC 02/12/93 #1 02/11/93 #1 02/10/93 #1 02/10/93 #1 9450.00- 9750.00 ATLAS 5 " 9484.00- 9766.00 ATLAS 5 " 0.00- 2830.00 ATLAS 5 " 9150.00- 9660.00 ATLAS 5 " Information Control Well Records RECEIVED BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP/PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. DATE: 02/12/93 T# 84309 D~18~f~ PRODUCTION LOG 02/09/03 #1 q PFC 02/09/93 #1 ~/'~' PFC/~/CC~ 02/08/93 #1 10800.00-11130.00 ATLAS 5 " 10450.00-10710.00 ATLAS 5 " 9230.00- 9848.00 ATLAS 5 " 8350.00- 9660.00 ATLAS 5 " Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard · - RO. 'Box 196612 .. · :: Anchorage, Alaska 99519-6612 ';', (907) 561-5111 DATE: 02-11-93 T# 84317 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. - -20 .~ CH c. 37q~~a c. 02/06/93 REF#124639 02/07/93 REF#124657 02/06/93 REF#124656 02/07/93 REF~124640 CASING COLLAR LOG (PERF ATLAS PRODUCTION LOGGING SERV ATLAS PRODUCTION LOGGING SERV ATLAS COMPENSATED NEUTRON GAM ATLAS Information Services Well Records RECEIVED Alaska 0jJ .& Gas Cons, C0mmlsslor~ ~ohorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE' 02/11/93 T# 84301 BP/ PBU OH TAPES (REPLACEMENTS) Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) ~ S-33 OH/BHC FIN 10/19/92 #1 8044.00- 9529.50 1600BPI API~500292229300 9138->TP# 8079.50- 9779.00 ~ 1600BPI API#500292229100 9145->TP# Information Control Well Records RECEIVED FEB 1 8 t99 AJaska 0il & Gas Cons. CommJsS[o;rl Anchorage If you have any 564-4004. SCH REF#92620 SCH REF#92662 Please NOTE that these tapes are replacement tapes for previously distributed materials. S-33; replaces tape S-33 which has the GR in casing curve missing and was sent in transmittal #84041 S-37; replaces tape S-37 which had one blank tape in the previous distribution and was sent in transmittal #84085. Because one tape was blank all were redone and are being redistributed. BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 02/09/93 T# 84295 BP/PBU CH LOGS Enclosed is yOur copy of the materials listed below. If you have any questions,?'please contact BP Well Records at (907) 564-4004. .,~B--32~~?'' PRODUCTION LOG 01/31/93 #1 ~_M-19A 2~.~ PFC 01/30/93 #1 ~M 1 wv'' - 9A'~l~"' CCL 01/29/93 ~1 /-36~%~ PFC 02/04/93 ~1 ~-37q~/CC~/~Z 02/04/93 ~1 10100.00-10744.00 ATLAS 5 " 9900.00-10450.00 ATLAS 5 " 8400.00-10531.00 ATLAS 5 " 9380.00-10200.00 ATLAS 5 " 8850.00- 9675.00 ATLAS 5 " Information Control Well Records BP EXPLORATION BP/PBU OH EDIT TAPE BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/19/92 T# 84085 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ~' S~-37 ~ O~V~3H / BHC FIN 11/03/92 #1 8079.50- 9779.00 1600BPI API#5002 9222 9100 9145->TP# SCH REF#92 662 Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/09/92 T# 84064 BP OH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. S-37 S-37 S-37 ss TVD ~/ 11/03/92 #1 11/03/92 #1 11/03/92 #1 8100.00- 9726.00 SCH 2/5" 9105.00- 9754.00 $CH 2/5" 9105.00- 9754.00 SCH 1/2" Information Control Well Records / ECEIVED NOV 18 1992 Alaska Oil & Gas Cons. Commission' Anchorage ALASI~A OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCttORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 16 1992 Bill Kirton Workover Engineer Supervisor BP Exploration P O Box 196612 Anchorage, AK 99519-6612 Rs: Prudhoe Bay Unit S-37 BP Exploration Permit No: 92-99 Sur. Loc. 1684'SNL, 1929'EWL, Sec. 35, T12N, R12E, UM Btmhole Loc. 2043'SNL, 1278'WEL, Sec. 35, T12N, R12E, UM Dear Mr. Kirton: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~hnston ~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA O~_ AND GAS CONSERVATION COb,,v. ISSlON PERMIT TO DRILL 20 AAC 25. O05 la. Type of work Drill [] RedrillBIlb. Type of well. Exploratory FI Stratigraphic Test [] Development Oil[] Re-Entry [] DeepenBl Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator :5. Datum Elevation (DF or KB) 10. Field and P°ol BP Exploration KBE = 32'feet Prudhoe Bay Field/Prudhoe 3. Address 6. P. roperty Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28257 4. Location of well at surf-ace 7. Unit or property Name 11. Type BOnd(see 20 ^^c 25.025) 1684' SNL, 1929' EWL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1975' SNL, 1550' WEL, SEC. 35, T12N, R12E S-37 (32-35-12-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 2043'SN!~ 1278' WEL, SEC. 35, T12N, R12E ~ /0/~;~¢. $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and mVD) property line . . ADL 28280/3235' fee[ S-12A 26'@ 600'MD feet 2560 9768'MD/9217'TVDVDfeet 16. To be completed for deviated wells i17. Anticipated pressure (se~ 2o AAC 25.035 (,,)(2)) Kickoff depth 5ooofeet Maximum hole angle 3~.5 o Uaximurn surface 3330ps~g At total depth (TVD) 8800'/4390Ps~g 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole . Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 32' 32' 110' 110' 450 # Poleset 13-1/2" 10-3/4" 45.5¢t NTaOIhe BTC 2873' 31' 31' 2904' 2890' 905 sx AS 111/685 sx AS I 9-7/8" 7-5/8" 29. 7# NT95HS l NSCC 9055' 30' 30' 9085' 8633' 651 sx Class "G" 6-3/4" 5-1/2" 17# 13CR8O FL4S 833' 8935' 9682' 9768' 9217' 121 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate Production S~P ?- 5 Liner . Alaska .Oil & 6as Cons. Commis$~o~ Perforation depth: measured ' ' ' true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis l-I Seabed.report[] 20 AAC 25.050 req,uirementsl--I 21. I hereby cert, ify~ ~/'~ --~,- _that thy/,, foregoing is true and correcttol,~sthe best of my knowledge Y'/25'-/ Signed . -- '~T~e · ~-, /¢_.~-//,,.-- Workover EngineerSupervisor Date Commission Use Only t_ Number IAPI number IApprov~al date ISee cover letter Permic//.~'_ 4:~ * 150- os?- 2..z ~9'/ I 1~-'/~,--:¢~;~, Ifor other requirements Conditions of approval Samples requir?d [] Yes ,,I~NO Mud Icg required []Yes ~'No Hydrogen sulfide measures [] Yes .~ No Directional survey required ~ Yes [] No Required working pressure for BOPE I'-12M; i-]3M; ~5M; []10M; []151~t;' Other: by order of Approved by Original Signed By Commissioner ~ne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well: S-37 [32-35-12-12] PBU LOCATION: Surface: Target: T.D.: 1684' FNL 1929' FWL S35 T12N R12E 1975' FNL 1550' FEL S35 T12N R12E 2043' FNL 1278' FEL S35 T12N R12E ESTIMATED START: OPR. DAYS TO COMPLETE: CONTRACT~: OCT 2, 1992 21 (15 days drilling, 6 days completion) Nabors 28E MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 31.5/S75E/5000'/2.5/2112' Estimated Ground level elevation is 37' AMSL. KB to ground level elevation is 32'. Item TVD(BKB) MD(BKB), Mud Wt. 20" CONDUCTOR 8 0 8 0 8.5 10-3/4" SHOE 2890 2904 9.1 TOP UGNU SANDS 3 61 9 3 6 3 3 9.1 SEABEE 5 2 6 9 5 2 8 3 9.5 KUPARUK 6 71 9 6 8 4 8 9.8 7-5/8" SHOE 8633 9085 SAG RIVER SANDSTONE 8 6 3 3 9 0 8 5 9.3- 9.5 TOP SADLEROCHIT 8 7 5 2 9 4 2 2 9.3- 9.5 TARGET 8752 9422 9.3-9.5 TOTAL DEPTH 9 Z. t7 9 "/68 9.3- 9.5 CASING PROGRAM: Hole Csg Wt Grade Conn Length Top 30" 20" 91.5# H-40 WELD 8 0 3 2 1 3- 1/2" 1 0-3/4" 45.5# NTSOLHE BTC 2873 3 1 9-7/8" 7-5/8" 29.7# NT95HS NSCC 9055 30 6-3/4" 5-1/2" 1 7# 13Cr-80 FL4S 833 8935 Btm 110 2904 9085 9768 COMPLETION: Tubing: GLMs: Packer: 4- 1/2" 1 2.6# 13Cr-80 hC:::C"T 8856 2 9 8885 4-1'/2" x 1" est 6 required, all dummies except RP shear in shallowest GLM Baker SABL3 7-5/8" x 4-1/2" set at 8935' or +/- 50' above TOL 9-7/8" Hole: None L~ING PROGRAM: Open Hole - RECEIVED S E P 2 5 1992 Alaska 0il & Gas Cons. 6ommissior~ Anchorage Cased Hole 6-3/4" Hole: DIL/BHCSICNL/GRISP CET/CBT/GR after rig leaves location REC[IVED ,~ E P 2 5 1992 ,Alaska OJJ & Gas Cons. Cornmission Anchorage S-37 Slimhole September23, 1992 16:01 Page 2 PROPOSED DRILLING AND COMPLETION PROGRAM WELL S-37 [32-35-12-12] PBU MIRU. NU diverter and function test same. Drill 13-1/2" hole to casing point. Run and cement 10-3/4", 45.5#, casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. A formation leak-off test will be performed 10' below the 10-3/4" shoe. Directionally drill 9-7/8" hole to the 7-5/8" casing point above the top of Sag River. Run a 7-5/8", 29.7 # NSCC casing string to within 10' of 9-7/8" TD and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected by dead crude oil. Directionally drill the 6-3/4" hole to TD. Run 5-1/2" liner from TD to 150' inside 7- 5/8" casing shoe and cement using Class G cement. Clean out to 5-1/2" float equipment. Change over to NaOI completion fluid. Test casing and lap to 3500 psi. Run 7-5/8" production packer on tubing. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with Diesel from surface to 2300' TVDBKB. Set and test packer. The well will be perforated after the rig has been released. Fluids incidental to the drilling of a well will be injected in a permitted P-pad 10- 3/4" x 7-5/8" annulus. The completion will include 4-1/2" 13OR NSCT tubing with dummied GLMs, one equalizing dummy, and one RP shear valve ANNULAR INJECTION The S-24 surface annulus is available for injection at present. Fluids can also be injected at the central CC-2 injection facility. AOGCC has informed PB Drilling that only associated fluids from drilling operations can be pumped down the surface x intermediate annulus-ie: completion fluids cannot be pumped. CEiVED S-37 Slimhole September23, 1992 16:01 Page 3 0il .& 6as Cons. Ar~chorage FREEZE PROTECTION The 4-1/2" tubing along with the 4-1/2" annulus will be freeze protected with gas or diesel using the RP shear valve in the shallowest GLM. Dry crude needs to be injected down the 10-3/4" x 7-5/8" annulus after the well is completed. CLOSE APPROACHES/SHUT-INS Note near well proximity of wells S -2 and S 12a. The S-12 close approach occurs at 50' md'. The SSSV will be shut-in. The well can be brought back on line once surface td is reached. The S-12a close approach occurs at 50' md. The SSSV will be shut-in. The well can be brought back on line once surface td is reached. Notify WOA PE's when wells can be brought back on line. ~"P ~ ,5 19,92 & Gas 00ns. 6ommissio,q Anchorage S-37 Slimhole September 23, 1992 16:01 Page 4 MUD PROGRAM: Well S-37 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS;- SURFACE HOLE Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ',,300 <1 00 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/100ft2 60 - 80 20 - 30 pH 9- 10 9 - 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top of Sag River Sandstone' LSND Gel/Water System Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/1 00ft2 10 min Gel Ibs/100ft2 APl Fluid Loss mi/30 min pH Hardness m g/I 9.0-10.0 10.0 to Casing Point 10 - 15 5-10 10 - 20 <15 9.5 - 10.0 NC-no control MUD SPECIFICATIONS-PRODUCTION INTERVAL: Watered back mud system used in intermediate hole. Mud Weight ppg 9.5 Yield Point Ibs/100ft2 8 - 13 10secGel Ibs/100ft2 5- 10 10 min Gel Ibs/100ft2 7 - 15 APl Fluid loss mi/30 min DH -- Hardness m g/I t r (To to the LCU) S E P 2 5 7992 alaska 0il & Gas Co~s. Commission Arlchorage 6.0 - 8.0 (fluid loss lowered to below 6 cc prior to entering K-shales 8.0 - 9.0 < 4000 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at < 3500 ppm chlorides. Over Balance in the ,Production H(;;)le S-37 Slimhole September 23, 1992 16:01 Page Design Mud Wt. (6-3/4" Hole): 9.5 ppg. Formation pressure at top Sag River: Formation pressure at Sadlerochit: Pressure at top Sadlerochit: 4200 psi. 3700 psi at 8800' TVDSS 3723 psi. Over Balance Sag River: 215 psi Over Balance Top Sadlerochit: 770 psi. Current GOO: Above top Sad. For more detailed information refer to the Prudhoe Bay Drilling Mud Policy that resides in DRILLING VOLUME #1(file server) under the MUD POLICY folder. A!ask~ 0il & Gas Cons. Anchorage S-37 Slimhole September 23, 1992 16:01 Page PRUDHOE BAY S ?AD WELL DRILLING #37p3 VERTICAL VIE/,,/ SCALE 1000 -Ft, REFERENCE: WELL O-- 1000'~ 1949~: 2000 2890-- 3000-- 361~ 4000-- 6769 0.00' 8 0 MD 0.00° ~ 400 MD 5,00" 8 600 ND 10.00'~ 800 MB 15,00'@ 1000 MD 10.00°8 1200 MD 5,00° 8 1400 MD 0.00° @ 1600 ND 0.00' ~ 1963 MD BASE OF PERNAFRDST 0,00° ~ 2904 MD SURFACE CASING 0.00' ~ 3633 MD UGNU 0,00° ~ 5014 MD 4,00° ~ 5214 MD 5.39° 8 5283 MD SEABEE 8,00° 8 5414 MD 12.00° ~ 5614 MD 16 00' 8 5814 MD 20,00° 8 6014 MD 24.00* @ 6214 MD 28.00° 8 6414 MD 31,15' @ 6571 MD 31.15' @ 6848 MD KUPARUK/PUT RIVER 31.15' ~ 6907 MD IKRU/LCU / DIVISISN HEAD HBRIZONTAL VIEL/ SCALE 200 -Ft, / REFERENCE: WELL 0 200~00 800 1200 1600 2000 oo? (TRUE NBRTH> DIVISIBN HEAD 8633 9000 31,15' 8 9085 MD TOP SAG RIVER 31.15' @ 9133 MD TOP SHUBLIK 31,15° 8 9422 MD ZONE 3 31.[5' @ 9492 MD ZONE 2C 31.15' 8 9768 MD R E 'E VED S E P 2,5 1,9,°~' .... ' ,~ i-- Naska Oil & Gas Cons. CommissioH Anchorage 10000 I I 1000 2000 3000 VERTICAL SECTION PLANE: 100,95° BHL TVD 9217,39 MD 9767,51 VS 2112.16 South 401,30 East 2073,69 Smith International, Inc. Survey Reference: WELLHEAD Reference Wortd Coordinates: Lat. 70.35 N - Long. 149.02 W Reference GRID System: Alaska State Plane Zone: Ataska 4 Reference GRID Coordinates (feet): 5979855.00 N 620090.00 E Vertica[ Section Reference: WELLHEAD North Aligned To: TRUE NORTH PRUDHOE BAY DRILLING S PAD WELL #37p~ Survey Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 100.32 deg. R[C[ VED Page 1 Date: 9/23/92 Weltpath ID: 371~ Date Surveyed: 9/22/92 Last Revision: 9/23/92 P 2 5 199 Gas Co~.s. Commissio~ Inc[ Drift TVD T 0 T A L Dir. Rectangutar Offsets (deg) (deg) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 N 0.00 E START NUDGE 0.00 0.00 400.00 0.00 N 0.00 E 2.50 30.00 499.97 1.89 N 1.09 E 5.00 30.00 599.75 7.55 N 4.36 E 7.50 30.00 699.14 16.98 N 9.80 E 10.00 30.00 797.97 30.15 N 17.41 E 12.50 30.00 896.04 47.05 N 27.16 E BEGIN OF DROP 15.00 30.00 993.17 67.63 N 39.05 E 12.50 30.00 1090.30 88.21 N 50.93 E 10.00 30.00 1188.37 105.11 N 60.68 E 7.50 30.00 1287.20 118.28 N 68.29 E 5.00 30.00 1386.59 127.71 N 73.73 E 2.50 30.00 1486.37 133.37 N 77.00 E END OF DROP 0.00 30.00 1586.34 135.26 N 78.09 E BASE OF PERMAFROST 0.00 0.00 1949.00 135.26 N 78.09 E GRID Coordinates Easting Northing (ft) (ft) 620090.00 5979855.00 620090.00 5979855.00 620091.06 5979856.91 620094.24 5979862.62 620099.53 5979872.14 620106.92 5979885.43 620116.40 5979902.48 620127.96 5979923.25 620139.51 5979944.02 620148.99 5979961.06 620156.38 5979974.36 620161.67 5979983.87 620164.85 5979989.58 620165.91 5979991.49 620165.91 5979991.49 Ctosure Dist. Dir. (ft) (deg) 0.00 a 0.00 0.00 @ 0.00 2.18 a 3o.oo 8.72 @ 30.00 19,61 a 30.OO 34.82 @ 30.00 54.33 @ 30.00 78.09 @ 30.00 101.86 @ 30.00 121.37 @ 30.00 136.58 @ 30.00 147.46 @ 30.00 154.00 @ 30.00 156.18 @ 30.00 156.18 @ 30.00 Vertical DLS Section (ft) (dg/lOOft) 0.00 0.00 0.00 0.00 0.73 2.50 2.94 2.50 6.60 2.50 11.73 2.50 18.30 2.50 26.30 2.50 34.30 2.50 40.87 2.50 45.99 2.50 49.66 2.50 51.86 2.50 52.60 2.50 52.60 0.00 Geographic Coordinates Latitude / Longitude 70.3536 N 149.0248 70.3536 N 149.0248 70.3536 N 149.0248 70.3536 N 149.0248 70.3536 N 149.0247 70.3536 N 149.0247 70.3537 N 149.0246 70.3537 N 149.0245 70.3538 N 149.0244 70.3539 N 149.0243 70.3539 N 149.0243 70.3539 N 149.0242 70.3539 N 149.0242 70.3539 N 149.0242 70.3539 N 149.0242 Subsea Depth (ft) -69.00 331.00 430.97 530.75 630.14 728.97 827.04 924.17 1021.30 1119.37 1218.20 1317.59 1417.37 1517.34 1880.00 SURFACE CASING 0.00 0.00 2890.00 135.26 N 78.09 E UGNU 0.00 0.00 3619.00 135.26 N 78.09 E KOP @ 2° / 100' 0.00 0.00 5000.00 135.26 N 78.09 E 2.00 105.05 5099.98 134.81 N 79.78 E 4.00 105.05 5199.84 133.45 N 84.83 E SEABEE 5.39 105.05 5269.00 131.97 N 90.32 E 6.00 105.05 5299.45 131.18 N 93.25 E 8.00 105.05 5398.70 128.02 N 105.02 E 10.00 105.05 5497.47 123.96 N 120.12 E 12.00 105.05 5595.62 119.01 N 138.55 E 14.00 105.05 5693.06 113.17 N 160.27 E 16.00 105.05 5789.64 106.45 N 185.27 E 620165.91 5979991.49 620165.91 5979991.49 620165.91 5979991.49 620167.60 5979991.06 620172.68 5979989.79 620178.19 5979988.40 620181.13 5979987.66 620192.95 5979984.68 620208.12 5979980.87 620226.62 5979976.21 620248.43 5979970.72 620273.53 5979964.40 156.18 @ 30.00 52.60 0.00 156.18 @ 30.00 52.60 0.00 156.18 @ 30.00 52.60 0.00 156.64 @ 30.62 54.34 2.00 158.13 @ 32.44 59.55 2.00 159.92 @ 34.39 65.21 2.00 160.95 @ 35.41 68.24 1.99 165.58 @ 39.36 80.38 2.00 172.62 @ 44.10 95.97 2.00 182.64 @ 49.34 114.99 2.00 196.20 @ 54.77 137.41 2.00 213.67 @ 60.12 163.20 2.00 70.3539 N 149.0242 W 2821.00 70.3539 N 149.0242 W 3550.00 70.3539 N 149.0242 W 4931.00 70.3539 N 149.0242 W 5030.98 70.3539 N 149.0241 W 5130.84 70.3539 N 149.0241 W 5200.00 70.3539 N 149.0241 W 5230.45 70.3539 N 149.0240 W 5329.70 70.3539 N 149.0239 W 5428.47 70.3539 N 149.0237 W 5526.62 70.3539 N 149.0235 W 5624.06 70.3539 N 149.0233 W 5720.64 Smith International, Inc. Survey Report Page 2 Date: 9/23/92 Weltpath ID: 37p3 Inc[ Drift TVD Dir. (deg) (deg) (ft) 18.00 105.05 5885.27 20.00 105.05 5979.82 22.00 105.05 6073.17 24.00 105.05 6165.21 26.00 105.05 6255.84 28.00 105.05 6344.94 30.00 105.05 6432.39 END OF BUILD 31.15 105.05 6481.92 KUPARUK/PUT RIVER 31.15 105.05 6719.00 TOTAL Rectangular Offsets (ft) (ft) 98.86 N 213.50 E 90.41 N 244.94 E 81.11 N 279.55 E 70.96 N 317.28 E 59.99 N 358.09 E 48.21 N 401.93 E 35.62 N 448.74 E 28.03 N 477.00 E 9.18 S 615.39 E IKRU/LCU 31.15 105.05 6769.00 17.03 S 644.57 E TOP SAG RIVER 31.15 105.05 8633.00 309.58 S 1732.58 E TOP SHUBLIK 31.15 105.05 8674.00 316.01 S 1756.51 E TARGET ENTRY 31.15 105.05 8752.01 328.26 S 1802.05 E ZONE 3 31.15 105.05 8922.00 354.94 S 1901.27 E ZONE 2C 31.15 105.05 8982.00 364.35 S 1936.29 E ORIGINAL OWC 31.15 105.05 9089.01 381.15 S 1998.75 E TOTAL DEPTH 31.15 105.05 9217.39 401.30 S 2073.69 E GRiD Coordinates Easting Northing (ft) (ft) 620301.88 5979957.27 620333.44 5979949.32 620368.19 5979940.58 620406.08 5979931.05 620447.06 5979920.73 620491.08 5979909.66 620538.09 5979897.83 620566.47 5979890.68 620705.42 5979855.71 620734.73 5979848.34 621827.27 5979573.45 621851.30 5979567.41 621897.02 5979555.91 621996.66 5979530.85 622031.83 5979522.00 622094.55 5979506.23 622169.80 5979487.31 C[osure Verticat Dist. Dir. Section (ft) (deg) (ft) 235.28 @ 65.15 192.34 261.09 @ 69.74 224.78 291.07 @ 73.82 260.49 325.12 @ 77.39 299.43 363.08 @ 80.49 341.55 404.81 @ 83.16 386.79 450.16 @ 85.46 435.10 477.83 @ 86.64 464.27 615.45 @ 90.85 607.08 644.79 @ 91.51 1760.02 @ 100.13 1784.71 @ 100.20 1831.70 @ 100.32 1934.12 @ 100.57 1970.27 @ 100.66 2034.77 @ 100.80 2112.16 @ 100.95 637.19 1760.01 1784.71 1831.70 1934.10 1970.24 2034.70 2112.03 DLS (dg/lOOft) 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 0.00 Geographic Coordinates Latitude / Longitude Subsea Depth (ft) 70.3538 N 149.0231 ~ 5816.27 70.3538 N 149.0228 W 5910.82 70.3538 N 149.0226 ~ 6004.17 70.3538 N 149.0223 ~ 6096.21 70.3537 N 149.0219 W 6186.84 70.3537 N 149.0216 ~ 6275.94 70.3537 N 149.0212 ~ 6363.39 70.3536 N 149.0210 ~ 6412.92 70.3535 N 149.0198 ~ 6650.00 0.00 70.3535 N 149.0196 W 6700.00 0.00 70.3527 N 149.0108 ~ 8564.00 0.00 70.3527 N 149.0106 ~ 8605.00 0.00 70.3527 N 149.0102 ~ 8683.01 0.00 70.3526 N 149.0094 W 8853.00 0.00 70.3526 N 149.0091 ~ 8913.00 0.00 70.3525 N 149.0086 W 9020.01 0.00 70.3525 N 149.0080 ~ 9148.39 Smith International, Inc. Travelling Cylinder Report ~ Computed by the Sii Win-CADDS System Calculated using the Minimum Curvature Method Normal Plane Method Page 1 Date: 9/22/92 REFERENCE WELL: PRUDHOE BAY DR[LL]NG S PAD 14ELL #37p3 TVD, N/S and E/14 are measured from the 1,/ELLHEAD We[[path Slot Distance sO1 S-01 1172.77 sOlr S-O1R 1172.83 sO2 S-02 1060.62 sO3 S-03 949.83 sO4 S-04 841.88 s05 S-05 177.44 sO6 S-06 623.12 s07 S-07 512.58 sO8 S-08 402.55 sO9 S-09 292.16 slO S-10 111.84 sll S-11 73.20 s12 S-12 37.28 s12a S-12A 26.33 s13 S-13 132.28 s14 S-14 224.63 s15 S-15 1106.25 s16 S-16 1199.26 s17 S-17 1335.73 s17a S-17A 1335.53 s18 s-18 1386.66 s19 s-19 1095.63 s20 S-20 951.05 s21 S-21 916.01 s22 S-22 1134.27 s23 S-23 983.93 s24 S-24 651.37 s25 S-25 804.76 s26 S-26 652.83 s27 S-27 695.84 s28 s-28 658.71 s29 S-29 465.74 s30 s-30 546.96 s31 S-31 475.52 s32 S-32 217.95 Closest Points Direction Ref MD Ref TVD 270.89 50.00 50.00 270.89 50.00 50.00 270.80 350.00 350.00 270.82 400.00 400.00 270.78 400.00 400.00 181.08 5669.37 5650.00 270.90 50.00 50.00 271.11 400.00 400.00 270.60 400.00 400.00 270.21 400.00 400.00 320.74 3863.66 3850.00 270.85 50.00 50.00 91.10 50.00 50.00 113.68 600.25 600.00 118.08 955.42 950.00 119.61 1211.81 1200.00 289.68 4613.66 4600.00 281.35 4813.66 4800.00 245.36 50.00 50.00 245.37 50.00 50.00 241.26 0.00 0.00 271.00 200.00 200.00 238.53 5163.73 5150.00 270.87 150.00 150.00 270.91 400.00 400.00 270.87 400.00 400.00 313.89 4563.66 4550.00 270.98 400.00 400.00 232.90 5516.23 5500.00 271.10 250.00 250.00 270.91 400.00 400.00 270.71 400.00 400.00 270.88 400.00 400.00 270.88 400.00 400.00 271.21 450.00 450.00 ,, EEEIVED ~, r-" ._r') Oil & Gas Cons. Corr~rnission 10-3/4" SURFACE CASING CEMENT PROGRAM - DOWELL CASING SIZE: 10-3/4" CIRC. TEMP 38°F SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: ASIII ADDITIVES: retarder WEIGHT: 12.1 ppg YIELD:1.94 ft3/sx MIX WATER: 11.1 gps APPROX #SACKS: 905 THICKENING TIME: 4:30 hrs TAIL CEMENT TYPE: ASI ADDITIVES: As Required WEIGHT: 15.7 ppg APPROX #SACKS: 435 YIELD:0.93 ft3/sx THICKENING TIME: 4 hrs MIX WATER: 3.59 gps TOP JOB CEMENT TYPE: ASI ADDITIVES: retarder WEIGHT: 15.7 ppg YIELD:0.93 ft3/sx MIX WATER' 3.59 gps APPROX #SACKS: 250 CENTRALIZER PLACEMENT: 1. Run one(l) bow type centralizer per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Run two cement baskets inside the conductor pipe on stop collars. CEMENT VOLUME: 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 435 sx 3. Top job volume 250 sx. ,~Jaska, 0il & Gas Cons. ~chora[!,o S-37 Slimhole September 23, 1992 16:01 Page 7 7-$/8" INTERMEDIATE CASING CEMENT PROGRAM- DOWELL CIRC. TEMP' 140° F SPACER: 50 bbls Mudpush XT, weighted 1 ppg above mud current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 2% D79 + 0.2% D46 + D800 as required for 4.5 hr thickening time WEIGHT: 11.5ppg YIELD' 2.75ft3/sx MIX WATER: 16.9 gps APPROX #SACKS: 388 THICKENING TIME: 4.5 hrs TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.35% D156 + 0.2% D65 + 0.15% D800 + 0.05 gps D47 for 3-4 hrs thickening time. WEIGHT: 15.Sppg YIELD: 1.15ft3/sx MIX WATER' 5.0 gps APPROX #SACKS: 263 THICKENING TIME' 3-4 hrs CENTRALIZER PLACEMENT' 1 Turbulator centralizer per joint on the bottom 500' of 7-5/8" casing ( 12 required ). One solid body 7-3/4" x 9-1/4" centralizer or turbolator just inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. Batch mix tail cement - perform fluid loss test. Fluid loss should be 40 cc or less. CEMENT VOLUME: 1. Lead G neat slurry to 500'md above top of Ugnu @ 3633' md (TOC @ 3133' md). 2. Tail G slurry to 1000' md above casing point with 30% excess. 3. 80' md 7-5/8", 29.7# capacity for float joints. NOTE: The intermediate casing string should be isolated from the Cretaceous,.JnZerval. ~.!aska 0il & Gas Cons. Anci~orage S-37 Slimhoie September 23, 1992 16:01 Page 8 CIRC. TEMP 140© F 5-1/2" PRODUCTION LINER CEMENT PROGRAM - DOWELL SPACER: 50 bbls fresh water w/3 ppb ARCO preflush and 1% S-400 or equivalent. CEMENT TYPE: CLASS G ADDITIVES' 1.0 gps D600 + 0.25% D65 + 0.1 gps D135 + 0.05 gps D47 + D800 as required WEIGHT: 15.8 ppg YIELD:I .1 6 ft3/sx MIX WATER' 5.1 gps APPROX #SACKS: 121 THICKENING TIME: 4.5 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/ cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 6-8 bpm. LINER CEMENT VOLUME: , , Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 5-1/2", 17# casing capacity below landing collar. 150' liner lap (6.750" x 5-1/2") 200' of cement on top of the liner in the_ 7-5/8" casing. & 6as ~,ons. 6omr~ission Anchorage S-37 Slimhole September23, 1992 16:01 Page S-37 Casing Design Specificatior SURFACE CASING 10-3/4", 45.5# NT-80LHE BTC CASING BURST COLLAPSE NT-80LHE 521 0 3130 PBYS (Ct) 1040000 TJYS (Ct) 1097000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SI PRESSURE 14 2890 2104 Burst S.F. 2.48 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2890 1428 Collapse S.F. 2.1 9 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 45.5 2904 PBYS Tension $.F. 9.21 Mud Wt. 9.5 ppg TJY$ 9.71 String Wt. (#) 112946 Anchorage S-37 Casing Design Specificatior Intermediate Casing 7-5/8", 29.7#,NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-95HS 81 80 7150 PBYS (#) 811000 TJYS (#) 841000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SFFP 3330 Burst S.F. 2.46 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10 8800 0.1 3696 Collapse S.F. 1.93 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29.7 9085 PBYS Tension S.F. 3.56 Mud Wt. 10.0 TJYS 3.69 String Wt. (#) 227759 Gas Co~]s. Corr~mission Anchorage S-37 Casing Design Specificatior PRODUCTION LINER 5-1/2", 17#,L-80, 13Cr, FL4S Casing GRADE BURST COLLAPSE L-80 6280 7740 PBYS (#) '397000 TJYS (#) 24800O Burst Pressure Calculation Burst rating based on formation pressure on top of 9.6 ppg fluid SITP Fluid wt (ppg) 3420 9.6 Burst S.F. 1.74 back up (ppg) Burst Pressure 9.2 36O3 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.6 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.6 8800 0.1 3513 Collapse S.F. 2.20 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) I 7 833 9.6 I 1 953 Tension S.F. PBYS TJYS 33.21 20.75 SUF,.," L, ._ HOLE DIVERTER SYSTEM .. .... Two lines venling 90 deg. apart in directions Ihat ensure safe down wind venting, and ex- tending to a point at least 100' from any' polentiai source of tgnilion. ,_10' Full Opening Valves . ... .... 35' or as required Dresser Sleeve 10' Diveder Uno 1. Ali pipe connections 150# ANSI Ranges or welded c~nnedions and secured Io prevent rnovemenL 2. Manual 10" full opening valves mechanically' connected lo ensure that one valve is fail-sale open at all limes. 3. All tums are 90 deg. and larger, ed. 10' Full opening ball valve w/Hydraulic Actuator o.,,.. RECEIVED 20' Diverter Spool w/10' Side Culler S E P 2 B 1992 Alaska Oil & 6as Cons. Commission Anch0raga MEM 1/3/90 NABORS 28E 13 5/8" 5,000 psi Stack t 2.42 10.93 4.50 4.~2 1.51 3.07 I' 2.13 1.13 1.5 GROUND LEVEL RKB 1 I HYDRIL ! I PIPE RAM BLIND RAM KB TO RF 13.18 5.58 8.06 MUD CROSS PIPE RAM MUD CROSS TBG SPOOL k~ASE FLG ~ // .. 12.58 I16.25 17.33 19.75 4!aska 0ii ~., Ga:; Cciis. Commission Anchora?,a BP EXPLORATION BP Exploration(Alaska)tn~. P.O. ~ox196612 Anchorage, Alaska 99519-6612 ARCO Alaska, Inc. TO: Name-; Company: _.. Location' TELECOPY SATELLITE UNIT . ..~_a ~-- c~ ., Fax # ..... ~'7 G ---..-Z(;"zf ¢ FROM' · Name & Ext., Department: NOTES: gg'g' PAGES TO FOLLOW ,. (Do not include cover sheet) SECURITY CLASSIFICATION PRIVATE .............. SECRET CONFIDENTIAL i iiii---- . ...... FAX# SATELLITE FAX, MACHINE 907 564-5193 CONFIRM# , iiii ;]dld OltYJ.'$ O.L =- O0'M~ ~m lg~ 'ir dYU.i. i · OlO;llN¥11 z J.1Nil 9dl'q'~d OmXil~ f g~3ddOH oriel 3HI1:11:1 ~NY£ d I.I:LI, I~ I;%,L I V SEP u 1992 A..!a~ka Ud & Gas Cons. Commission UNR' I TRIP TANK 1TO BBL FILL LINE L. VOLU~IZ VO L~JME lA I~IK 180 BElL D~OH TO CHOI(E MANIFOLD TRAP ¢ BBL PtOI~EE~ MI( I · ! BO.L DESILTER TO STAND PIPE KILL LI4E SUGTIO# 11T BBL MUD PUI~P~ ITO D;STRIBUTIO~I WAIER 61r BIBL MUO HOPPEfl~ l~ MIXIIIG PUMPS 5UGTION 134 tll~L · - I~AIBOR8 I;)RIIIJQ LI~ '~ RIG :~o. 28E MUD BYII. TEM 8URFAGE FACIL~ TOTAL. AGTLVE 8Y~TE~: 600 BBL L, ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS APPROVE DATE t ru " "-- [~J ~-I~'ru 13 ] [ 10 & 13] (4) Casg ,J/4- [14 thru 22] (5) BOPE dg--' ?/~ [23 thru 28] [ 29 thru 31] (7) Contact A,//~ "~[32 ] (8) Addl Company ~ ~ Lease & Well 9eoloc~y' engineering' DW-~ BEW~ rev 08/18/92 YES NO 1. Is permit fee attached ............................................... ~ 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from pro'i3erty line ................... .... 4. Is well located proper distance from other wells ..................... , _ 5. Is sufficient undedicated acreage available in this pool ............. z~ 6. Is well to be deviated & is wellbore plat included ................... /.~ . ... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ - .. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24 25 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nL~nber appropriate .......................................... ~'- Does well have a unique name & number ................................ Is conductor string provided ......................................... Wil 1 surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ ~" Will cement tie in surface & intermediate or production strings ...... Will cement cover all k..nown productive horizons ..................... Will all casing give adequate safety in col lapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... REMARKS Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed Is a di v erter system required ..................................... Is drilling fluid program schematic &iist of equipment adequate. Are necessary diagrams & descriptions of diverter & BOPE attached Does BOPE have sufficient pressure rating -- test to b--o,:~o psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... /' Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE / remarks' m z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history' file. To improve :the readability of the Well History file and to simp!ify finding information, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. S -37 PRUDHOE BAY RECEIVED MAR 1 5 199b Alaska 0il & Gas Cons. Commission 8 IC, OFILM Date. ~,., ,,.'%/% ,:"-~, /% ,,.. ~,~. /%. /,.., j"~_, /,... ./ ;.~ /:% .~'.-. .,,.;.,. :,+ ...... ,.;;. .~,., ~c..., _,,',.. /-.,. ./'.,. .,--%. ./-,.,. Run 1' 07 - February - 1993 CNIGR Cased Hole 9028 J680 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING S - 37 (32-35-12-12) 500292229100 B.P. EXPLORATION (ALASKA) ATLAS WIRELINE SERVICES 04-MAR-93 5879.02 R. IORIO J. WELCH INC. 35 12N 12E 1684 1929 69.30 68.30 35.60 RECEIVED MAR I 5 199 AJaska Oil & Gas Cons. Commission Anchorage OPEN HOLE BIT SIZE (IN) CASING SIZE (IN) 10.750 7.625 5.500 4.500 DRILLERS DEPTH (FT) 2923.0 9108.0 9770.0 8902.0 CASING WEIGHT 45.50 29.70 17.00 12.60 (LB/FT) CURVE SHIFT DATA - ALL PASSES TO STANDARD BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: UNKNOWN BASELINE DEPTH GRCH 9020.0 9020.0 9106.0 9106.5 9107.5 9108.0 9117.0 9118.5 9153.0 9154.5 9158.5 9160.5 9160.0 9162.0 9171.5 9173.0 9183.0 9185.0 9194.0 9195.5 9200.5 9202.5 9211.0 9212.5 9223.0 9224.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 9231.5 9244.0 9251.5 9254.5 9265.0 9272.5 9291.0 9298.5 9301.5 9315.5 9361.5 9382.0 9392.0 9405.0 9409.0 9416.5 9421.5 9428.0 9439.5 9500.5 9514.0 9555.5 9575.0 9582.5 9618.5 9643.0 9665.5 9668.5 9695.0 $ REMARKS: 9232.5 9244.5 9252.0 9254.5 9264.5 9272.0 9290.5 9298.0 9301.0 9315.0 9361.0 9381.5 9391.5 9404.5 9408.5 9416.5 9421.0 9428.0 9439.0 9500.5 9514.0 9556.0 9576.0 9583.5 9619.0 9644.0 9666.0 9668.5 9695.0 CN/GR LOG TIED TO BHCS LOG RUN 03-NOV-92. WELL NOT PERFORATED. COMPENSATED NEUTRON LOGGED ON SANDSTONE MATRIX WITH 2 3/4" CASED HOLE TOOLS. LOGGED FOUR PASSES. NO CASING CORRECTIONS APPLIED. CHISM FILTERING NOT ACTIVE. OPEN HOLE GAMMA RAY FOR DEPTH MATCHING SUPPLIED BY ARCO ALASKA INC (15-FEB-93) . SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9029.0 9673.0 9038.0 9680.0 BASELINE DEPTH NPHI 9020.0 9020.0 9103.5 9103.5 9107.5 9107.5 9113.0 9113.0 9153.0 9154.5 9160.0 9162.0 9175.5 9177.0 9183.0 9185.0 9186.0 9186.5 9194.0 9196.0 9196.5 9198.0 9201.0 9202.5 9246.5 9248.0 9251.0 9251.5 9254.5 9254.5 9265.0 9265.5 9272.5 9272.0 9291.0 9290.5 9298.5 9298.0 9407.5 9407.0 9409.5 9409.5 9439.5 9438.5 9501.0 9500.5 9575.0 9575.0 9582.0 9582.0 9643.0 9643.5 9695.0 9695.0 $ REMARKS: CN WN FN COUN STAT (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH files. : BP EXPLORATION : $ - 37 : PRUDHOE BAY : NORTH SLOPE : ALASKA PASS 1. GRCH SHIFTED TO OPEN HOLE GAMMA RAY. FUCT, NUCT, NRAT, & TENS WERE ALL SHIFTED WITH NPHI. $ * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 NRAT 2418 68 1 4 6 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 38 Tape File Start Depth = 9695.000000 Tape File End Depth = 9020.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9458 datums Tape Subfile: 2 205 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9028.0 2418 9037.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 9020.0 9033.5 9042.5 9095.5 9102.5 9106.0 9108.0 9108.5 9109.0 9111.0 9115.0 9116.0 9116.5 9144.5 9145.0 9146.0 9153.5 9154.0 9166.0 9167.5 9175.5 9176.0 9176.5 9187.0 9190.5 9191.0 9191.5 9197.5 9200.0 9207.5 9208.5 9219.5 9221.5 9224.5 9225.5 9226.5 9227.5 GRCH 9020.0 9032.5 9107.0 9109.0 9112.5 9146.0 9147.0 9177.5 9178.5 9179.0 9189.0 9192.5 9193.5 9194.0 9202.0 9209.5 9210.0 9221.0 9222.5 for each pass in separate files. STOP DEPTH 9673.0 9680.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 9020.0 9041.5 9096.0 9102.5 9108.5 9109.5 9115.5 9116.0 9116.5 9147.5 9155.0 9156.0 9168.0 9169.0 9199.0 9202.0 9226.5 9227.0 9228.0 9228.5 9229.0 9229.5 9237.5 9246.0 9249.0 9249.5 9255.5 9259.5 9260.5 9261.0 9262.5 9263.0 9273.5 9274.5 9286.5 9287.0 9303.0 9303.5 9366.5 9398.0 9400.5 9401.5 9402.5 9403.0 9403.5 9409.0 9413.0 9434.0 9435.0 9444.5 9515.0 9517.0 9567.0 9568.5 9569.5 9576.0 9586.5 9588.0 9589.0 9590.0 9591.5 9592.0 9592.5 9594.0 9595.0 9620.5 9653.0 9663.5 9664.5 9665.5 9668.0 9695.0 $ REMARKS: PASS FUCT, $ 9238.5 9249.5 9250.0 9255.5 9261.0 9262.5 9302.5 9303.5 9366.5 9397.5 9408.5 9413.0 9434.0 9434.5 9444.0 9515.0 9517.0 9568.5 9570.0 9570.5 9577.0 9588.0 9590.5 9591.0 9592.5 9593.5 9594.5 9596.0 9596.5 9621.0 9695.0 9230.0 9231.0 9247.5 9260.0 9261.0 9262.0 9263.5 9273.0 9274.0 9285.5 9286.0 9400.5 9401.5 9402.0 9402.5 9403.5 9588.0 9653.5 9664.0 9664.5 9665.5 9668.5 9695.0 Se NUCT, NRAT, & TENS WERE ALL SHIFTED WITH NPHI. : BP EXPLORATION : S - 37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 NRAT 2418 68 1 4 6 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 38 Tape File Start Depth = 9695.000000 Tape File End Depth = 9020.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9458 datums Tape Subfile: 3 157 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9028.0 2418 9037.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 9020.0 9020.0 9033.5 9032.5 9042.5 9106.0 9106.5 9107.0 9108.0 9108.5 9111.0 9112.0 9119.0 9120.0 9120.0 9143.0 9144.5 9146.0 9154.0 9154.5 9155.5 9157.0 9166.0 9168.0 9169.5 9170.5 9170.0 9171.0 9170.5 9172.0 9191.5 9193.0 9199.0 9201.0 9200.0 9202.0 9201.0 9202.5 9202.5 9203.0 9206.0 9218.0 9219.5 9219.0 9220.0 9220.0 9223.5 9224.5 9225.5 9226.5 9227.5 9228.0 9231.5 9232.0 for each pass in separate files. STOP DEPTH 9673.0 9680.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 9020.0 9041.5 9106.0 9120.0 9147.0 9155.0 9156.0 9167.5 9169.0 9203.5 9204.5 9207.5 9222.0 9225.5 9226.0 9226.5 9227.0 9227.5 9229.0 9232.5 9233.5 9235.5 9236.5 9237.5 9245.5 9249.0 9249.5 9252.5 9256.5 '9261.0 9266.5 9267.0 9271.0 9275.0 9279.0 9285.0 9285.5 9291.0 9296.0 9312.0 9313.0 9376.5 9377.0 9399.5 9400.5 9401.0 9401.5 9402.5 9404.5 9413.5 9434.0 9443.5 9445.0 9457.0 9568.5 9576.5 9589.0 9590.0 9591.5 9592.0 9594.0 9595.0 9652.0 9653.0 9653.5 9654.5 9655.5 9656.0 9657.0 9657.5 9658.5 9660.5 9661.0 9662.5 9663.5 9664.5 9665.5 9666.5 9667.0 9673.5 9674.0 9236.5 9237.0 9238.0 9249.0 9249.5 9256.0 9260.5 9265.5 9266.5 9278.5 9284.0 9285.0 9290.5 9295.0 9375.5 9376.5 9399.0 9399.5 9403.5 9413.0 9433.5 9442.5 9444.0 9569.5 9590.0 9590.5 9592.0 9593.0 9595.0 9595.5 9657.0 9662.5 9663.0 9666.0 9667.5 9247.0 9252.5 9261.0 9270.5 9274.5 9311.0 9312.0 9400.5 9401.0 9401.5 9456.0 9576.5 9652.0 9652.5 9653.5 9654.5 9655.0 9656.0 9657.5 9658.0 9660.0 9661.0 9664.5 9665.0 9673.0 9674.5 9695.0 $ REMARKS: 9695.0 9695.0 PASS 3. FUCT, NUCT, NRAT, & TENS WERE ALL SHIFTED WITH NPHI. $ CN : BP EXPLORATION WN : S - 37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 NRAT 2418 68 1 4 6 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 38 Tape File Start Depth = 9695.000000 Tape File End Depth = 9020.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18916 datums Tape Subfile: 4 166 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9029.0 9673.0 9038.0 9680.0 BASELINE DEPTH 9020.0 9033.5 9105.5 9107.5 9112.0 9112.5 9113.0 9117.5 9118.5 9120.0 9143.5 9146.5 9156.0 9156.5 9164.5 9168.0 9190.0 9190.5 9191.0 9192.0 9198.5 9202.0 9207.0 9218.5 9219.5 9223.5 9224.5 9227.5 9228.0 9228.5 9232.5 9234.0 9237.5 9240.0 9246.0 9249.0 9252.0 GRCH 9020.0 9033.5 9106.0 9108.0 9113.0 9113.5 9114.5 9119.0 9119.5 9145 9191 9192 9193 9193 9200 9204 9208 9220 9220 .0 .5 .5 .0 .5 .5 .0 .5 .0 .5 9235.0 9249.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 9020.0 9120.0 9148.0 9157.5 9158.5 9166.5 9169.5 9225.0 9225.5 9228.5 9229.5 9230.0 9233.5 9238.5 9241.5 9247.5 9252.0 9256.5 9258.5 9259.5 9260.5 9263.0 9285.5 9286.5 9296.5 9302.0 9302.5 9303.5 9305.0 9348.0 9400.0 9401.0 9403.0 9409.5 9415.0 9432.5 9443.5 9444.5 9568.5 9570.5 9571.5 9574.5 9576.5 9586.0 9587.0 9588.0 9589.0 9590.0 9591.5 9592.0 9593.5 9594.5 9595.0 9606.5 9618.5 9638.0 9640.0 9656.0 9657.5 9658.5 9666.5 9667.0 9673.5 9674.0 9695.0 $ REMARKS: CN WN UN COUN STAT 9258.5 9259.0 9285.0 9285.5 9295.5 9301.5 9302.0 9302.5 9304.0 9347.5 9399.5 9400.0 9408.5 9414.5 9432.0 9442.5 9443.5 9569.5 9571.5 9572.0 9575.0 9587.0 9590.0 9590.5 9592.0 9593.0 9594.5 9595.0 9595.5 9608.0 9618.5 9639.0 9641.0 9656.5 9658.0 9658.5 9666.5 9667.5 9695.0 9256.5 9261.0 9263.5 9402.0 9576.5 9587.0 9587.5 9673.5 9674.5 9695.0 PASS 4. FUCT, NUCT, $ NRAT, & TENS WERE ALL SHIFTED WITH NPHI. : BP EXPLORATION : S - 37 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 NRAT 2418 68 1 4 6 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 38 Tape File Start Depth = 9695.000000 Tape File End Depth = 9020.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18916 datums Tape Subfile: 5 153 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: 1, 2, 3, 4 1, 2, 3, 4 GRCH, NPHI, FUCT, NUCT, & NRAT WERE AVERAGED FOR ALL PASSES. CN : BP EXPLORATION WN : S - 37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 NRAT 2418 68 1 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) Total Data Records: 33 1014 BYTES * Tape File Start Depth = 9695.000000 Tape File End Depth = 9020.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27023 datums Tape Subfile: 6 55 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9029.0 2418 9037.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9680.0 9689.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-FEB-93 FSYS256 REV:G002 VER:2.0 1107 07-FEB-93 9660.0 9685.0 9050.0 9684.0 1200.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323XA 0.000 9770.0 0.0 SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS) : 40 NEAR COUNT RATE HIGH SCALE (CPS) : 1040 TOOL STANDOFF (IN) : 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : S - 37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 CLSN 2418 68 1 CPS 4 6 SSN 2418 68 1 CPS 4 7 CSSN 2418 68 1 CPS 4 8 CNRA 2418 68 1 4 9 CCL 2418 68 1 4 10 SPD 2418 68 1 F/MN 4 11 TEN 2418 68 1 LB 4 12 TTEN 2418 68 1 LB 4 4 19 991 67 5 4 86 720 65 6 4 31 149 96 6 4 27 466 87 5 4 27 466 87 5 4 28 122 23 5 4 28 122 23 5 4 58 226 31 1 4 79 150 21 1 4 65 866 87 0 4 31 402 87 0 4 31 402 87 0 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 142 Tape File Start Depth = 9695.000000 Tape File End Depth = 9023.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53874 datums Tape Subfile: 7 217 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9028.0 2418 9036.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9679.0 9688.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-FEB-93 FSYS256 REV:G002 VER:2.0 1142 07-FEB-93 9660.0 9685.0 9050.0 9684.0 1200.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323XA 0.000 9770.0 0.0 SEAWATER O.0O 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS) : 40 NEAR COUNT RATE HIGH SCALE (CPS) : 1040 TOOL STANDOFF (IN) : 0.0 REMARKS: PASS 2. $ CN : BP EXPLORATION WN : S - 37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 CLSN 2418 68 1 CPS 6 SSN 2418 68 1 CPS 7 CSSN 2418 68 1 CPS 8 CNRA 2418 68 1 9 CCL 2418 68 1 10 SPD 2418 68 1 F/MN 11 TEN 2418 68 1 LB 12 TTEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 27 466 87 5 4 4 28 122 23 5 4 4 28 122 23 5 4 4 58 226 31 1 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 48 * DATA RECORD (TYPE# 0) Total Data Records: 142 994 BYTES * Tape File Start Depth = 9694.000000 Tape File End Depth = 9022.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 61981 datums Tape Subfile: 8 217 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9028.0 2418 9036.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9677.0 9686.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATKIX DENSITY: HOLE CORRECTION (IN): 07-FEB-93 FSYS256 REV:G002 VER:2.0 1219 07-FEB-93 9660.0 9685.0 9050.0 9684.0 1200.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323XA 0.000 9770.0 0.0 SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS) : 40 NEAR COUNT RATE HIGH SCALE (CPS) : 1040 TOOL STANDOFF (IN) : 0.0 REMARKS: PASS 3. $ CN : BP EXPLORATION WN : S - 37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 CLSN 2418 68 1 CPS 6 SSN 2418 68 1 CPS 7 CSSN 2418 68 1 CPS 8 CNRA 2418 68 1 9 CCL 2418 68 1 10 SPD 2418 68 1 F/MN 11 TEN 2418 68 1 LB 12 TTEN 2418 68 1 LB 4 19 991 67 5 4 86 720 65 6 4 31 149 96 6 4 27 466 87 5 4 27 466 87 5 4 28 122 23 5 4 28 122 23 5 4 58 226 31 1 4 79 150 21 1 4 65 866 87 0 4 31 402 87 0 4 31 402 87 0 48 * DATA RECORD (TYPE# 0) Total Data Records: 142 994 BYTES * Tape File Start Depth = 9693.000000 Tape File End Depth = 9020.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 88884 datums Tape Subfile: 9 217 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE GR 2418 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): START DEPTH STOP DEPTH 9029.0 9678.0 9037.0 9687.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM GR CN CCL $ PULSE CODE MODULATOR GAMMA RAY COMPENSATED NEUTRON CASING COLLAR LOC. BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-FEB-93 FSYS256 REV:G002 VER:2.0 1257 07-FEB-93 9660.0 9685.0 9050.0 9684.0 1200.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323XA 0.000 9770.0 0.0 SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 40 NEAR COUNT RATE HIGH SCALE (CPS): 1040 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 4. $ CN : BP EXPLORATION WN : S - 37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 CLSN 2418 68 1 CPS 6 SSN 2418 68 1 CPS 7 CSSN 2418 68 1 CPS 8 CNRA 2418 68 1 9 CCL 2418 68 1 10 SPD 2418 68 1 F/MN 11 TEN 2418 68 1 LB 12 TTEN 2418 68 1 LB 4 19 991 67 5 4 86 720 65 6 4 31 149 96 6 4 27 466 87 5 4 27 466 87 5 4 28 122 23 5 4 28 122 23 5 4 58 226 31 1 4 79 150 21 1 4 65 866 87 0 4 31 402 87 0 4 31 402 87 0 48 * DATA RECORD (TYPE# 0) Total Data Records: 142 994 BYTES * Tape File Start Depth = 9693.000000 Tape File End Depth = 9021.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 96939 datums Tape Subfile: 10 217 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 11 is type: LIS 93/ 3/04 01 **** REEL TRAILER **** 93/ 3/ 4 01 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 4 MAR 93 4:38p Elapsed execution time = 52.94 seconds. SYSTEM RETURN CODE = 0 AbASKA COMPUTING CENTER COMPANY NA~E : BP EXPbORATION rIEbO NAME C PRUDHOE BAY BOROUGH I NORTH SbOPE STATE I ALA&KA API NUMBER I 50029222g~O0 REFERENCE NO I g2662 Tape Verification Listing ~chlumberger Alaska Computing Center · 9'"FEB-1993 08:09 **** REEL HEADER S~RV.ICE NA~E : EDIT DAT~ : 92/1!/17 ORIGIN : FLIC REEL NAME : 92662 CONTINUATION # .{ PREVIOUS REEL CON,ENT : BP EXpLORATIoN,PRUDHOE BAY,S-37 (32-35-12-12),500292229100 TAPE HEADER SERVICE NAME DATE ORIGIN TAPE NAME CONTINUATION PREVIOU:S TAPE COMMENT EDIT FLIC # : ! BP EXPLORATION,PRUDHOE BAY,S-37 (32',,35""12-:12),500292229{00 TAPE HEADER P~UDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NA~E: API NUMBER: OPERATOR: LOGGING COMPANY: TAP~ CREATION DATE: g DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FSL: FEL: FWL: ELEVATION(FT FRO~ ~SL O) KELLY BUSHING: DERRICK FLOOR: GROUgD LEVEL: WELL CASING RECORD ~ST STRING 9ND STRING RUN I RUN 2 RUN 3 92662 V4ARNER 1_2N 1684 1929 6 0 35,60 OPEN HOLE CASING DRILLERS BIT SIZE (I~) SIZE (IN) DEPTH eFT) 6.750 7.625 9108'0 bis Tape verification Listing ~Chlumberger Alaska CompUting Center 9~FEB-t993 08:09 3RD STRING PRODUCTION STRING # RFMARKS~ FIELD ENGINEER'S REMARKSl 1.0 IN RUBBER FIN STANDOFFS ~SED TO CE.~TRALIZg TDOLSTRING SFL SPIKE AT 9262 AND 9115' REPEATED ON BOTH PASSES. SONIC HAS SOME AREAS THAT DON'T REPEAT EXACTLY WHICH ARE FROM TOOL STICKING, THE MEASURE POINTS FOR THE TRANSIT TIMES ARE 36-41' FROM HTENS CURVE, $ **** FILE HEADER **** VERSION :O01A07 DATE : 92/11/17 MAX REC SIZE : 1024 FILE TYPE : LO FIL~ HEADER FILE NUMBER:~ 1 EDITED CURVES All. tool str~n~s; DePth DEPTH' INCREMENT 0.5000 FILE SUMMARY TOOL CODE ~R DTE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 9691 0 9686 0 9673 5 9670 0 9659 0 964~ 5 964~ 0 9620 0 96t9,0 9618.5 9583.5 Shifted and clipped curves; all runs merged; no cased hole data, START.DI~PTH 8TOP DEPTH ..am~m~i, mmmmm g?06,0 910,5 os.o 975 0 9108,0 --=-------EOUIVALENT UNSHIFTED DEPTH- ..... BCS DTE ~m).~m.mmmm 888,0 9686,0 q674.0 9643.0 9619,5 95~2.0 9670.0 9659.0 643,0 964].0 619,0 9619.0 Tape Verification Listing ~Chlumberger AlasRa Computing Center 9-F~;B..1993 08=09 PAGE= 9575.5 9570,5 9558,~ 9557 9504 5 950! 0 9491 5 9443 i~ 9440 9439:0 9432 .0 9428 5 9416 5 9405 5 02 0 9382 5 93:82 0 9363:5 9362 5 9362 0 93575 93430 9326 0 9302 0 9300 5 9295 0 9291 0 9290.5 9271.5 9257.5 9246 5 9230i0 921! 0 9196 0 9161 0 9153.0 9150.5 9149.5 9106.0 9105.5 100.0 $ MERGED DATA SOURCE PBU TOOL CODE $ 9556.0 9501,0 9487.5 9440,0 9.428,5 9392-0 9362 · 0 934! ,5 9302 ,.0 9295,5 9246.5 9575.5 9501,0 9439,5 9428'5 9416,5 .9392 9362,0 9291:. :5 9229.5 9211 ,,0 91.96.5 9160.5 9153,0 9150,0 9149.5 9106,0 9106,0 100.5 100.0 9570,5 9 9439.5 94156,5 940 . 5 9382,0 9362,0 9357.5 :9326,5 9301-5 929~ 9272.5 i01,0 RUN NO, PASS NO, MERGE TOP MERGE BASE mmmmmmmmmm REMARKS: THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT DT TO GR, TO GR (CARRYING ALL OTHER DTE CURVES) & SP TO GR. LIS FORMAT DATA ,~I$ Ta~e V.eri~Ication ~chlumberger Alas~e Computing Center 9-FEB-1993 08:09 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64ES ** TYPE REPR CODE VALUE I 66 0 3 73 52 4 66 i 5 66 6 73 7 65 9 65 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 .66 0 ** SET TYPE - CHAN ** mmmmmmmmmmm~mmmmmmmm~mmmmmmmmmmmmmmmmm~mmmmmmmmm~mmmmmmmm~mmmm~mmmmmmm~m~mmmmm~mmmmm~mm NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # hOG TYPE CHASM MOD NUMB SAMP .ELEM CODE (HEX) mm~mmmmmmmmm~mmmm~mmmmmmmm~mmmm~m~mmmmmmmmmm~m~mmmmmmmm~mm~mmmm~mmm~m~m~mmm~mm~m~ DEPT FT' 599509 O0 000 O0 0 I I I 4 68 0000000000 DT ECS US/F 599509 O0 000 O0 0 i I I 4 68 0000000000 GR ECS GAPI 599509 O0 000 O0 0 1 I 1 4 68 0000000000 TENS ECS LB 599509 O0 000 O0 0 I I i 4 68 0000000000 TEND ECS LB 599509 O0 000 O0 0 I 1 I 4 68 0000000000 IDPH DTE OHMS 599509 O0 000 O0 0 I I I 4 68 0000000000 IMP.H DTE OH~M 599509 O0 000 00 0 I 1 I 4 68 0000000000 ILD DTE OHMM 599509 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OHMS 599509 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE 599509 O0 000 O0 0 1 1 I 4 68 0000000000 BP DTE NV 599509 O0 000 O0 0 1 I I 4 68 0000000000 STEM DTE DEGF 599509 O0 000 O0 0 1 1 I 4 68 0000000000 MRES DTE OHMS 599509 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT 9767 000 DT,BCS ~99 250 GR,BCS -999._250 TEN TEND.BC$ 163,396 IDPH,DTE 99..250 IMPH,DTE -999,250 IL D E IbM.DT~ -999,250 SFL,DTE -999,250 SP,DTE -999,250 MTEM,DTE M~ES.DTE 1,0~0 845,000 ~999.250 187.305 JlS Tape verification hi. sting ~chlumberger Alaska Computing Center 9-FEB-lgg3 08:09 PAGE: DEPT g600,000 PT.SCS TEND:SCS 389.681 IDPH,DTE !LM.DTE 3.324 SFL.DTE MRES.DT~ 1.066 DEPT. 9300,000 DT.BCS TEND,BCS 421,273 IDPH DTE I~.D?E 22.125 SF~:DTE NRES.DTE Io131 D_EPT 9i05 000 DT,BCS TEND:BCS 495:204 IDPH,~DTE ILN.D?E '999.250 SFL.DTE MRES.DTE I ,.198 END OF DATA 93.8 80 GR, :BCS 3,368 IMPH.:DTE 8 , 2 57 $ P. DT E 8i!~46 GR.:SCS 74 IMPH'DTE 66, .999.:25~0 GR':BC$ 0 IMPH":DTE -99'9,250 SP~DTE !7.008 T'ENS,BCS 3.254 ILD,DTE -29.t25 MTE~.DTE ,100, 3802 TENS.BC$ :gg9.25 ILD.DTE 999,250 MTEN,DTE 4440 000 183,404 4350,000 22.46.9 176'o22 4375. 000 99g;250 169; 304 **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01A07 DATE : 92/11/!7 MAX REC SIZE : 1024 FIL~ TYPE : LO LAST FILE ~ **** FILE HEADER **** FILE NAME ~ EDIT ,002 SERVICE : FLXC VERSION : O01A07 DATE : 92/1t/17 M~X REC SIZE : 1024 FILE TYPE : LO FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole loQS run into casing. PASS NUMBER: 3 DEPTH INCREMENT 0,5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9105.0 8090.0 $ ;chlumberger AlasKa Computing Center g-FEB'!gg3 08:09 PAGE~ BASELINE CURVE FOR SHIFTS~ GR,BCS CURVE SHIFT DATA (M£ASURED DEPTH) BASELINE DEPTH 88888.0 9092'0 9064,0 go04 100'0 R~MARKS) ------.----EQUIVALENT UNSHIFTED DEPTH----------. GRCH 88888.5 9092'5 9064,5 9004'0 8993,5 99.5 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT GRCH TO GR. THE GRCH WAS FIRST SHIFTED TO THE OPEN HOLE GR AND THEN CLIPPED AT CASING SHOE, LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 5 66 6 73 7 65 8 68 0 5 1! 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 o 66 ! ~chlumberqerAiast<a Comp~t~nq Ce~er 9-F~B=1993 08:09 ** SET T NA~E SERV UNiT ID 0 DEPT FT 5 GRC~ BC$ GAPI TEND SCS LB 5 TENS BC$ LB 5 MRES BC$ OHMS 5 ~TE~ BC$ DEGF 5 YPE - CHAN ** ERVXCE API AP1 AP1 API FILE NUMB NUMB SIZE REPR PROCESS RDER # bOG TYPE CLASS ~OD NUMB SAMP EbEM CODE (HEX) 99509 O0 000 O0 0 2 ! 1 4 68 0000000000 99509 O0 000 O0 0 ~ I 1 4 68 0000000000 99509 O0 000 O0 0 2 1 I 4 68 0000000000 99509 O0 000 O0 0 ~ I 1 4 68 0000000000 99509 O0 000 O0 0 ~ I 1 4 68 0000000000 99509 00 000 O0 0 2 1 I 4 68 0000000000 ** DA?A DEPT.,i g!O~ MRES.BC$ D~PT, 9000 ~RES.BCS DEPT, 8700 M~E$,.BCS DEPT, 8400 DEPT,. 8100 ~RES,BCS DEPT, 8090 RES.SCS .000.221 GRCH-BCSMTEM.BC$. 164~83_~7756 TEND.SCS 467.591. TENS.SCS ' GRCH.'BCS 80 178 TENDoBCS 478.~086 TENS.BC5 '000 GRCH,BCS 57,.532 TEND,BC~ 480..355 TENS,BCS ,276 MTE~.BCS !58.776 ,000 GRCH'BC$ 81.652 TEND,BCS 448.283 TENS"BCS ,325 MTEM.BCS 154,722 ,O00 GRCH'BC$ 65,001 TEND.BCS 441,148 TENS,BC$ · 372 ~TE~,.BCS 150,340 ,000 GRCH.BCS 76.681 TEND,BC$ 437,483 TENS.BCS ,372 MTE~,BC$ 150,136 4425. 000 4370,000 4240,000 3865,000 3870,000 3855,000 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FbIC VERSION : 001A07 DATE : 92/~1/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ;¢hiumber~er Al. as~a Computing Center 9-FEB-igg3 08:09 PAGE: **** FILE HEADER FILE NAME : EDIT ,003 SERVICE : FLI¢ VERSION : 00lA0? DATE : 92/11/17 MAX REC SIZ~ : !024 FILE TYPE : LO LAST FILE : NUMBER Curves an~ Sadleroch~t run presented first (Primary deoth control~strlng used t~ depth shltt the Sad!~r interval) ~OlLowed by tiles tot other main Oass strings'Per'run, RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: 2 DEPTH INCREMENT: 0,5000 FTL~ SUMMARY VENDOR TOOL CODE START DEPTH ~~m~,~~mm ~m~mmm~ GR 9706.0 BHC 9726'0 DTE 9756.0 LOG HEADER DATA DATE LOGGED: SOFTWARE VER$IONI TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP bOG INTERVAL CFT): BOTTOM bOG INTERVAL LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOO!, TYPE GR GR BHC BHC DTE DTE $ STOP DEPTH mmmmmmmmmm 9105,0 9105,0 9105,0 03-Nov-g2 5C0-423 2145 02-Nov-g2 116 03-NOV-g2 9770.0 9766.0 B090,O 9754 0 7oo.6 mmmmmmmm! AUXIbLIARY MEASUREMENT TELEMETRY GAMMA RAY HOUSING GAMMA RAY CARTRIDGE BOREHOLE SONIC CART. BOREHOLE SONIC SONDE DUAL INDUCTION CART. DUAL INDUCTION SONDE TOOL NUMBER TC~'B )20 SGH-K 62 SGC-SA 6O SbC-UA 278 SLS-WA 2001 DIC-EB 427 DIS-NB 434 ~chlUmberger Alaska ComPut ~ Center 9-FEB-iR93 08)09 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH LOGGERS CASING DEPTH 75 9105'0 ROREHOLE CONDITIONS MUD TYPEI MUD DENSITY (LB/G): MUD VISCOSITY MUD FLUID LOSS (C33: MAXIMUM RECORDED TE PERATURE (DEGF.):EG RESISTIVITY (OHMS) AT TEMPERATURE ~UD AT MEASURED TEMPERATURE {MT) MUD AT BOTTO~ HOLE TEMPERATURE MUD FILTRATE AT (MT): MUD FILTRATE AT('BHT): MUD CAKE AT MUD CAKE AT~BHT)~ 9,~0 42,00 8,90 580 !96,0 3,190 3.730 1,950 64.0 64.0 64,0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)~ ~ATRIX: MATRIX DENSITY: HOLE CORRECTIO~ (IN): SANDSTONE 2.65 TOOL STANDOFF (IN)~ REMARKS: 1..0 IN RUBBER FIN STANDOFFS..US~D T0 CENTRALIZE TOObSTRI SFL SPIKE AT 9262' AND 9115' REPEATED ON BOTH PASSES SONIC HAS SOME AREAS THA'T DON'T REPEAT EXACTLY WHICH'AR FRO~ TOOL STICKING., THE ~EASURE POINTS FOR THE TRANSIT. TIMES ARE 36-41' FROM HTEN$ CURVE. S LIS FORMAT DATA PAGE:: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR,CODE VALUE 1 66 0 2 66 0 3 73 i64 4 66 1 5 66 6 73 7 65 9 65 ~.~$ Tape verifficatlon Listin )¢hlumber,.ger AlasKa ¢omput n~ Center 08)09 PAGE: 10 TYPg REPR CODg VALUE I) 66 6 t~ 68 13 66 0 15 66 68 16 66 1 o 66 ! m~mm~mm~m~m~mm~~m.~~l~ SET TYPE - CHAN ** mm~mmm~m~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mMm~.mmmmmmmm~mmmmmmmm~m~m~mmmm~m~m~mmmmmm NA~E SERV UNIT ID D~PT FT DT BHC US/F T1 BHC US T2 BHC US TT3 BHC US TT4 BHC US SP BHC GR BHC GAPI TENS BHC bB MTE~ BHC DEGF MRES BHC OHMM HTEN BHC CIOP DTE MMHO IPPB OTE OMMM CIMP DTE MMHO I~PM D?~ 'OH~M CDER DTE MMHO IDE~ DTE OHMM C~ER DTE MMHO IMER DTE OHMM CDV~ DTE MMHO IDVR DTE OHMM CMVR OTE MMHO ~MVR ~TE OHMM CTbD DTE MMHO ILD DTE OH~M CIL. DTE IL~ DTE ID~F DTE I~F DTE IIRD DTE MMHO IIXD DT~ MMHO IIRM DTE MMHO IIXM DTE MMHO SFLU DT~ SP D?£ MV G~ DT~ GAP! TENS DTE LB SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ORDER # 50G TYPE CLASS MOD NUMB SA'MP EhE~ CODE (MEX) ~IS Tape Verif.lcation Listing schlumberger Alaska ComputiNg Center 9-FEB-1993 08:09 PAGEs NA~E SERV U~IT SERVICE API API AP API FIhE NU~ NU.iB SIZE REPR PROCESS ID ORDER # 5OG TYPE CSASS MOD NUMB SA~P ELEM CODE (HEX) DT: DL. GF 599509 O0 000 O0 0 3 1 14 68 0000000000 N~ES DTE OH~M 599509 O0 000 O0 0 3 I I 4 68 0000000000 HTEN DTE LB 599509 O0 000 O0 0 3 ! 1 4 68 0000000000 ~* DATA DgPT, TENS,BHC ClDP.DTE CDER.DTE CDVR.,DTE CILD.DTE IDQF.DTE IIRM.DTE HTEN,DTE DEPT.;, TT3.SHC TENS'B~C CIDP.DTE CDE~.DTE CDYR.DTE CXbD.DT£ XD~F'DTE IXR~.DTE G~.DTE MTEN.DTE DEPT. TT3.BHC TENS.BHC CXDP.DTE CDER.DTE CDVR.DTE CXLD.DTE IDQF.DTE IIRM.DTE G~.DTE HTEN.DTE DEPT. TT3.BH~ TENS.B~ CIDP.DTE CDE~.DTE CDVR.DTE CILD.DTE 779,000 DT'BHC 80,!00 TTI,BHC 523.200 T?4-BHC 357.~00 SP BHC 2205 000 MTEM.BHC 187,]05 682:000 XDPH,DTE ~.466 ~XMP..DTE 680.652 ~DER.DTE !,469 C~ER.DTE 714. 10 XLD'DTE 1.400 0.000 iMOF.DTE 0'000 652'012 IIX~.DTE .69.427 8FbU.OTZ 10.992 TENS,DTE 2205*000 MTE~'DTE -426.976 9600.000 DT.BHC 94'000 TTI.BHC 572.000 TT4'BHC 396'000 SP.BHC 4440,000 ~TEM,BHC 183,506 NRES,BHC 289.943 IDPH,DTE 3'449 CIMP.DTE 320.964 XDER'DTE 3,:116 CMER,DTE 328,80¢ IDVR,DTE 3,041 CNVR'DTE 293.790 ILD, DTE ,.404 CILM.DTE 000 I~F..DTE 0,000 IIRD,DTE 28 494 XIX~'DTE 25,918 SFLU.DTE 17.008 TEN&.DTE 4440.000 ~TEM.DTE 389.68! 9300:000 DT.BHC 80.~00 TTI,BHC 518:800 TT4eBHC 352,~00 SP,BHC 4350.000 MTEM,BHC 176,i95 MRES,BHC - 39.283 IDP",DTE 25.4~6 CIMP,DTE 32.928 ~DER.DTE 30.370 C~ER.DTE 31.496 IDVR.DTE 31.750 C"VR.DTE 40.596 XLD.DTE 24.633 CILN.DTE 0.000 IMQF.DTE 0.000 IfRD.DTE 44.512 IIX~.DTE !2.498 SF5U.OTE 39.771 TEN$.DTE 4~50.000 MTE~.DTE 491.273 9000,000 DT.BHC , MTEM,BHC 41.723 IDPH.DTE 35.340 IDER.DTE 32.748 IDVR.DTE 44.585 ILD.DTE 53 600 291 200 165 064 ~97 3O 22 28 TTX.BHC SP.BHC MRES.OHC CIMP.DTE CMER.DTE CMVR.DTE CXLM.DTE 540~800 -20 000 I 030 7!9 114 038 207 051 O24 187.305 1.067 ~o7;878 18.793 325 .280 ,602 7.742 t83'506 537.200 .625 -131 39.948 37,660 36.524 46-,844 36.536 35.992 176.195 407 000 .228 :s .o4v 53.613 -55.702 -58.217 TT2.BHC GR.BHC HTEN.BHC IMPH DTE IMER D'TE XMVR DTE IL~.DTE IIXD.DTE SP.DTE MRES.DTE T?2'BHC GR.,BHC ~TEN,BHC XMPH.'DTE IMER'DTE XMVR.DTE Ib,.DTE IXXD.DTE SP.DTE ~RES.DTE TT2.BHC GR.BHC HTEN.BHC IMPH.DTE IMER.DTE IMVR.DTE ILN.DTE IIXD.DTE SP.DTE ~RES.DTE TT2.BHC GR.BHC HTEN.BHC IMPH.DTE IMER.DTE IHVR.DTE IbM.DTE 386.400 . 0,992 4~6.976 1,39! t.391 i 39O t i95 )07 ooo 1.030 93, 00 17'~08 389,681 ,'248 .137 3..076 34.010 -29,125 1,067 346.800 39.771 421.273 25.032 26.553 27.379 21.347 1,122 5.625 1.131 287.600 77.021 451.351 1950.000 1950.000 1950.000 1950,000 'IS Tape; Verification Listing ;ehlumberger AlasKa Computin~ Center IDQF.DTE 0,000 IMOF.DTE IIRM.DTE -55.722 !IXM.DTE GR.DTE 77.021 TEN&!'DTE HTEN.DTE 451,351 · ,T3.'BHC 999'250 TT4.BHC TENS.BHC 4265,000 MTEM.BHC Ci!DP.DTE 41.923 IDPH.DTE 35.340 XDER.DTE 32.748 CDE~.,DTE CDV~,DTE IDVR,DTE CILD.DTE 44.588 XLO,.DTE IDQF,DTE 0.000 IMQF.DTE IIRM.DTE -68.,:134 I!XM.DTE GR'DTE 64.506 TEN$~DTE HTEN.DTE 469.:862 END OF DATA 9-FEB-Igg3 08=09 0,000 IIRD,DTE ,373 SFLU,DTE 5 .600 -99~ TT1.BHC .689 MRES.BHC .967 CIMP,DTE ]~.297 C~ER,OTE · 536 CMVR,DTE 22'428 CIL~,DTE 0.000 IIRD,DTE ;:iO40 SFLU.DTE ~2'5 A00 ~TE~.DTE 40.290 IIXD.DTE 0,586 SP.DTE I65.064 MRES.DTE °o H. TEN*BHC 53. .DTE IMVR.DTE -58.:217 IL~.DT~ 40'032 IIXD'DTE ~64.689 ~R~S~DTE 742 2:875 ,228 -999.950 64,506 469.862 1950.000 ~950,000 1950'000 1950'000 -1.868 -2.250 1,234 **** FILE'TRAILER **** FI NA~E = EDIT .003 _EbE ~ RVICE = FLIC ' VERSION : 001A07 DATE :~ 92/1~/~7 MAX REC~SIZ~ =t024 FILE TYPE = LO LAST FILE = **** FILE HEADER FILE NAME = EDIT .004 SERVICE : FLIC VERSION = 001A07 DATE : 92/11/~7 MAX REC SXZ~ : 1024 FILE TYPE : LO LAST FILE = ' FILE HEADER FILE NUMBER 4 RaW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER~ TOOL STRING NUMBER: 1 P~SS NUMBER: DEPTH INCREMENT= 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Tape Yeriftcatlom Listing )chlumberoer Alaska Computlmg Center 9-FEB-t993 08:09 PAGE" GR 9706 0 BHC 9726i0 DTE 9756 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT]: BOTTOM 50G INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GE GR BHC DTE DTE $ AU.XIbLIARY MEASUREMENT TELEMETRY GAMMA RAY HOUSING GAMMA RAY CARTRI.DGE BOREHOLE SONIC CART, BOREHOLE SONIC SONDE DUAL INDUCTION CART, DUAL INDUCTION SONDE ,.9105.0 9t05'0 9105,0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN)t DRILLERS CASING DEPTH LOGGERS CASING DEPTH (F'T) BOREHOLE CONDITIONS MUD TYPE~ MUD DENSITY (LB/G): MUD VISCOSITY MUD FLUID LOSS MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE MUD AT BOTT0~ HOLE TEMPERATURE (BHT)~ MUD FILTRATE AT (MT): MUD FILTRATE AT MUD CAKE AT (MT): ~UD CAKE AT NEUTRON TOOL TOOL TYPE (EPITHERMA~ OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTIDN (IN): 03-NOV-92 5C0-423 2145 02=,NOV-g2 116 03=Nov=g2 9770,0 9766,0 8090.0 9754~0 ~700,0 AMM~AAT~4 TCC-B 320 SGH-K 62 SGC,-SA 60 SLC'UA 278 SLS'WA 2001 D!C-EB 427 DIS-HO 434 75O to .o 9~05,0 LSND 9,20 42,00 8,90 5:80 t 6.o 3,190 3,730 1,950 64.0 64.0 64.0 SANDSTONE 2,65 0000000000 89 9 t ~ ) 0 O0 000 O0 60~66~ WWHO ~H~ 0000000000 89 ~ I I ~ 0 O0 000 O0 60~66~ JD~O ~H~ 0000000000 89 ~ I I ) 0 O0 000 O0 60~66~ ~q ~H~ ~N~ 0000000000 89 ) I ) 9 0 O0 000 O0 60~66S IdVD ~HB 0000000000 89 ~ I I ~ 0 O0 000 O0 60~66~ AW ~H~ d~ 0000000000 89 ~ I I ~ 0 O0 000 O0 60~66~ ~fl ~H~ 0000000000 89 ~ t I ~ 0 O0 000 O0 60~66~ gfl ~H~ 0000000000 89 ~ I t ~ 0 O0 000 O0 60~66~ ~fl ~H~ 0000000000 89 t t t ~ 0 O0 000 O0 60S66g ~fl ~H~ 0000000000 89 ~ ~ I ~ 0 O0 000 O0 60566g ~/gfl ~H~ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 605665 ~ (X~H) ~OOD W3q3 dWVg 8NflN OON ~Vq~ ~4R& DOq # U30~O mm~m~m~m~m~m~mm~m~mm~m~m~m~mmmm~mm~mm~m~mmm~m~mmmmmm~mm~mmmmmmmmm~m~mm m~mmmmmm~m~mmmmmmmmmmmmmmmmm ~ 99 0 I 99 89 99 SI 0 99 89 gl 9 99 g9 6 ~9 ~L 9 99 ~ 99 ~9%' EL, 0 99 0 99 ~NqVA 3a03: Ud~l~l # $ 60:80 E66I-B3J-6 008'06E 000'0~' 906'~0i ~6£'~ T6E~I 6~9 BSg' O0 8IQ'H~I S6['86[ ~&Q'~WID ELg'E ~H8'~9 EgO'IE- ~HS'dg OO9'E6E 6gg'SBg- ~&O'gN3& 889'9I ~&O'NXII L)8']S9 H&o'oqI 6[)'SiL a£o'oqID ~&O'~3O! 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