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Home My WebLink About177-024MEMORANDUM TO: Jim Regg < P.I. Supervisor P 17 11/761(z-- FROM: John Crisp Petroleum Inspector 0 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 26, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-11 PRUDHOE BAY UNIT NGI-I 1 Src: Inspector Reviewed By: P.I. SuprvJ610, NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-I 1 API Well Number 50-029-20283-00-00 Inspector Name: John Crisp Permit Number: 177-080-0 Inspection Date: 11/8/2012 Insp Num: mit121112062101 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell NGI-I I Type Ine I j G TVD 7311 IA 959 - 2108 - 1902 - — TD 1770800 - Type Test SPT Test psi 1828 OA� 15 12 14 --- Interval OTHER P/F F - Tubing 3382 3375 3375 Notes: MITIA post tubin atch. It took 8.5 bbls to test the IA . ctup- 4Z, l�,`� Press %ss �=, i F Z v l SCANNED Monday, November 26, 2012 Page 1 of I 0 MEMORANDUM TO: Jim ReggRex Id'j�ty P.I. Supervisor tt FROM: John Crisp. Petroleum Inspector � 1 �J State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 26, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-11 PRUDHOE BAY UNIT NGI-11 Src: Inspector Reviewed By: r P.I. Supry �1 NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-11 API Well Number 50-029-20283-00-00 Inspector Name: John Crisp 5� Permit Number: 177-080-0 Inspection Date: 11/8/2012 Insp Num: mit 121112062426 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-11 - Type Inj G - TVD 7311 IA 1902 2107 1987 - 1987 - TD 1770800 Type Test SPT Test psi 1828 OA 14 14 15 15 Interval (OTHER p/F P Tubing 3375 3378 3385 3385 — Notes' .6 bbls pumped for retest. Post tubing patch retest. Operator Rep. requested they repressure IA due to failed MIT with pressure loss of over 200 psi after 15 minutes on first test. I told the Rep. I would witness test & my Supervisor would review data & make judgment on pass fail. Pass - per J. Regg. SCANNED' 1 Monday, November 26, 2012 Page 1 of 1 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 20AAC 25.105 20AAC 25.110 ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero 1b. Well Class: ® Development ❑ Exploratory ❑ Service ❑ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 6/10/2010 12. Permit to Drill Number: 177-024 310-140 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 06/08/1977 13. API Number. 50-029-20248-00-00 4a. Location of Well (Governmental Section): Surface: 2428' FSL, 234' FWL, SEC. 32, T11 N, R15E, UM Top of Productive Horizon: 1317' FNL, 3575' FEL, SEC. 06, T10N, R15E, UM Total Depth: 1746' FNL, 4195' FEL, SEC. 06, TI ON, R15E, UM 7. Date T. D. Reached: 06/29/1977 14. Well Name and Number: PBU 05-08 8, KB (ft above MSL): 64' GL (ft above MSL): 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 9. Plug Back Depth (MD+TVD): 11250' 8833' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 697316 y- 5948597 Zone- ASP4 TPI: x- 693619 y- 5944755 Zone- ASP4 Total Depth: x- 693012 Y- 5944309 Zone- ASP4 10. Total Depth (MD+TVD): 11860' 9227' 16. Property Designation: ADL 028326 & 028329 11. SSSV Depth (MD+TVD): N/A 17. Land Use Permit: 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 18. Directional Survey: ❑ Yes ® No Submit electronic and printed information per 20 AAC 25.050 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL / SP / BHCS / GR, FDC / CNL / GR / CAL, GR / CNL / CCL, CCL / GR, Multishot 22. Re-DrilULateral Top Window MD/TVD: N/A 23• CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTINGRECORD PULLED 94# H-40 Surfa 109' Surfa 1 224 sx Arcti e 13-3/8" 72# MN -80 Surfa 2733' Surfa 2733' 17-1/2" 5000 sx Arcticset 9-5/8" 47# N- / Surfa 11837' Surf12' 12-1/4" 1200 sx lass 'G' 0 sx Arcticset J & L N- AL 95 1 24. Open to production or injection? - ❑ Yes ® No If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): MD TVD MD TVD %ow OCT 19 25. TUBING RECORD SIZE DEPTH .SET MD PACKER .SET MD /TVD 4-1/2", 12.6#, 13Cr80 / L-80 11118' 10927' / 8633' 11109' / 8745' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTHINTERVAL(MDA AMOUNT AND KIND OF MATERIAL USED 11080' P&A Perfs w/ 50 Bbls Class 'G' 11350' Mill Pilot Hole in Cement 11300' Set 1st Whipstock (Possibly moved downhole) 11250' Set 2nd Whipstock (Possibly moved downhole) 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: _F GAS -OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology andres_e�n%. $f, 0'1, water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analWNS�idtU6 50.071. None JUL Q q 2010 RBDMS JUL 0'3 2044t Ainks 00 & 6u Certs. Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only 29. GEOLOGIC MARKERS (List all formations and ma ncountered): 30. MATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Sadlerochit 10883' 8605' None Base Sadlerochit 11747' 9153' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre- Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. 1 hereby certify that the foregoing .s true and correct to the best of my knowledge. / Signed: Terrie Hubble Title: Drilling Technologist Date: PBU 05-08 177-024 310-140 Prepared ByName/Number. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Wilmer Hoffman, 564-4592 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-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • 05-08, Well History Date Summary Is 5/21/2010 Weekly BOPE test. Liquid pack wellbore. RIH w/ 2.7" cementing nozzle stop @ 11550. Load ct backside w/ diesel. Lay in 50 bbls of 17ppg cement. Pull up to safety @ 9950. 5/22/2010 Resume staging sqz pressure up to 1000 psi. Hold 500 psi swap to biozan and clean out to to 11045'. Make 3 down passes and pooh chasing returns @ 80%. MU Left hand BHA w/ motor, 3.79" string mill, 3.8 mill. RIH w/ LH milling assy. Milled out XN nipple at 11028' ELMD and cleaned out cement in tubing to planned 11080' ELMD. FP wellbore w/ 38 bbls diesel to 2500'. Left 400 psi on wellbore. SI swab, SSV. Mill and SR had no noticeable wear and gauged same as run. LWSI and turned well back to DSO. RDMO to 2-06. Job Complete. 5/28/2010 T/I/0= 0/0/0 (TWC previously set) Torqued tree to API specs, minimal to no movement on all nut. Pressure tested tree to 500 psi for 5 minutes for low test, no loss, no leaks. Pressure tested tree to 5000 psi for 5 minutes for high test, no loss, no leaks. Pulled 4" CIW H TWC #END2 thru tree @ 98" using 1-2' ext. Pre Nordic 1. 5/29/2010 T/1/0= 0/0/0 Temp= SI MIT -T PASSED to 3000 psi (Pre CTD). Pressured up Tbg with 1.5 bbls diesel. Tbg lost 100 psi in 1 st 15 mins and 40 psi in 2nd 15 mins for a total loss of 140 psi. Bled pressures back. Bled -1 bbl diesel. Final WHPs 0/0/0 06/07/10- Nordic #1 moved over the well but was unsuccessful at exiting the 9-5/8" casing. After several failed 06/14/10 attempts, the decision was made to move the rig off of the well to allow time to perform diagnostic work to evaluate the way forward. 7/4/2010 WELL S/I ON ARRIVAL. DRIFT TO TD 11,296' SLM W/ 10' x 2.50" D. PERF GUN, S.BAILER (bailer empty). WELL S/I ON DEPARTURE. 7/7/2010 WELL SHUT-IN ON ARRIVAL. INITIAL T/IA/OA = 150/ 0/ 0 RIH WITH EXPRO VIDEO LOG. DOWN CAMERA VIEW BLOCKED BY GREASE OR WELL FREEZE PROTECT. POOH AFTER AND CLEAN CAMERA. RIH AND HAD GOOD CAMERA VIEW BELOW 8800'. CONDUCT 5 FPM DOWN AND UP PASS OVER INTERVAL OF INTEREST. DROPPED INTO HEAVY MUD OR SHMOO THAT COVERED CAMERA LENS. PULLED BACK INTO TUBING AND DID 150 FPM CLEANING PASSES. CONDUCTED ONE FINAL 5 FPM DOWN PASS. RDMO AND HAND OVER TO DSO. WELL LEFT SHUT-IN AND SSV OPEN. TC INSTALLED AND PT. FINAL T/IA/OA = 100/0/0 PSI. JOB COMPLETED. Page 1 of 1 • • Common Well Name: 05-08 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 6/1/2010 End Date: X3-OOVM3-C (582,487.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name/No.: NORDIC 1 Spud Date/Time: 6/8/1977 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°15'49.411"1 Long: 0148°24'16.647"W Active Datum: 19: 08 7/16/1999 10:49 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) - 6/5/2010 00:00 - 18:00 18.00 MOB N WAIT PRE RIG WAS RELEASED FROM 05-25C AT 00:00 BUT IS STILL ON THAT WELL. WAITING FOR WIND TO SUBSIDE TO OPEN CELLAR DOORS. WIND IS 25-35 MPH BLOWING DIRECTLY FROM THE BACK OF THE RIG. REMOVE CAP FROM ANNULAR PREVENTER TO REPLACE CAP SEAL. CUT AND SLIP DRILL LINE. MOVE OFFICE TRAILER DOWN THE PAD NEAR THE NEXT WELL. 18:00 00:00 6.00 MOB N WAIT PRE GREASE CHOKE AND KILL LINE VALVES. CONTINUE MONITOR WIND CONDITIONS. 25-37 MPH AT CREW CHANGE, CONTINUING 28-37 MPH UNTIL 24:00. NEEDLE GUN AND PAINT INSIDE SHAKER ROOM AND DOGHOUSE. 6/6/2010 00:00 18:00 18.00 MOB N WAIT PRE CONTINUE WAIT ON WIND TO OPEN CELLAR DOORS. ADD TWO VALVES INTO FUEL LINE IN BOILER ROOM #2. CONTINUE CHIPPING AND PAINTING IN SHAKER ROOM. _ 118:00 00:00 6.00 MOB N WAIT PRE OPEN UP HERCULITE AND SPREAD IT AROUND WELL 05-08. HERCULITE IS NEEDED SO OUTSIDE OF RIG CAN BE WASHED DOWN. j SPOT RIG MATS ON HERCULITE. WHILE SPREADING OUT HERCULITE SMALL AMOUNT OF GAS IS SEEN BUBBLING UP THROUGH STANDING WATER AROUND ADJACENT WELLHEAD, 05-22. NOTIFY PAD OPERATOR, WHO INFORMS DHD. VAC TRUCK IS USED TO REMOVE WATER AROUND TREE, AND OA, IA BLED TO ZERO BY DHD. BUBBLING STOPS AFTER THIS. 6/7/2010 00:00 01:00 1.00 RIGD N WAIT PRE CONTINUE WAIT ON WIND. 01:00 02:30 1.50 RIGU P PRE PJSM THEN JACK UP RIG AND MOVE OFF WELL. MOVE DOWN THE PAD AND OVER WELL 05-08A. 02:30 04:00 1.50 RIGU P I PRE PJSM THEN USE MANLIFT TO REMOVE PRESSURE GAUGE ON TOP OF TREE CAP. USE TORQUE WRENCH TO CHECK TREE BOLTS, ALL WERE TIGHT. BACK OVER WELL AND SET RIG DOWN. ACCEPT RIG AT 04:00. 04:00 09:30 5.50 BOPSUR P PRE N/U STACK 09:30 10:00 0.50 BOPSUR P PRE FUNCTION TEST BOPS 10:00 18:00 8.00 BOPSUR P PRE BEGIN BOPE TEST. WITNESS OF TEST WAIVED BY BOB NOBLE OF AOGCC. Printed 6/11/2010 3:23:59PM Common Well Name: 05-08_DIMS AFE No X3-OOVM3-C (582,487.00 ) Event Type: MOBILIZATION (MOB) Start Date: 6/1/2010 End Date: Project: Prudhoe Bay Site: PB DS 05 Rig Name/No.: NORDIC 1 Spud Date/Time: 6/8/1977 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°15'49.411"1 Long: 0148°24'16.647"W _ Active Datum: 19: 08 7/16/1999 10:49 @64.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations i (hr) (ft) I 18:00 21:30 3.50 BOPSUR P PRE CONTINUE BOP TEST. FIRST ROUND 2-3/8 X 3-1/2 VBR AND LOWER 2-3/8 COMBI RAMS FAIL. CONTINUE TESTING BLIND RAMS AND FLOOR VALVES. _ 21:30 22:00 0.50 BOPSUR N SFAL PRE OPEN VBR AND REPLACE ELEMENTS. 22:00 23:15 1.25 BOPSUR P PRE RE -TEST VBR AND LOWER COMBIS, GOOD. 23:15 23:30 0.25 RIGU P PRE PJSM FOR PULLING CT ACROSS PIPE SHED. STORED ENERGY AND WORKING AT HEIGHTS WAS DISCUSSED. 23:30 00:00 0.50 RIGU P PRE PULL CT IN TENSION AND REMOVE SHIPPING BAR. PULL CT ACROSS PIPE SHED ROOF AND INTO INJECTOR. Printed 6/11/2010 3:23:59PM • Common Well Name: 05-08—DIMS AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 6/3/2010 End Date: X3-OOVM3-C (1,432,563.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name/No.: NORDIC 1 Spud Date/Time: 6/8/1977 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°15'49.411"1 Long: 0148°24'16.647"W Active Datum: 19 : 08 7/16/1999 10:49 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/8/2010 00:00 01:00 1.00 MOB P PRE CHECK CABLE FOR CONTINUITY, GOOD. M/U CT RISER TO WELLHEAD. _ 01:00 03:00 2.00 RIGU P PRE CIRCULATE BACKWARDS TO FILL REEL. AFTER ITS FULL PUMP 4 BPM SEVERAL TIMES TO MOVE SLACK BACKWARDS. POP OFF WELL, R/U HYDRAULIC CT CUTTER. CUT 50 FT OF CT TO FIND CABLE. i INSTALL CT CONNECTOR, PULL TEST TO 35K, GOOD. 03:00 0500 2.00 STWHIP P WEXIT INSTALL BHI CABLE HEAD. PRESSURE TEST INNER REEL VALVE AND CT CONNECTOR TO 3500 PSI GOOD. 05:00 05:45 0.75 STWHIP P WEXIT M/U CT RISER TO WELL, PT STRIPPER ELEMENT TO 250/3500 PSI, GOOD. PUMP SLACK FORWARD, 1 REEL VOLUME AT 2.5 BPM. Printed 6/11/2010 3:24:36PM 05:45 07:00 1.25 STWHIP P WEXIT POP OFF WELL. INSTALL CHECK VALVES IN LOC. 2.67BPM, 250OPSI FS, 100-150PSI MW, 2-2.5K 07:00 07:15 07:00 0.25 STWHIP P WEXIT PJSM RE PU BHA. ----- 07:15 07:40 0.42 STWHIP P WEXIT MU PILOT HOLE BHA. STALL_ --- 07:40 10:15 2.58 STWHIP P P WEXIT ---- RIH TO MILL PILOT HOLE WIPER TO 11,070FT & TO 11,194FT. 10:15 11:00 0.75 STWHIP P P _ WEXIT LOG TIE IN FROM 10985' MILL CEMENT PILOT HOLE FROM 11,194FT 11:00 11:05 0.08 STWHIP P WEXIT CORRECT -15'. RIH TO BEGIN MILLING PILOT HOLE USING 2% KCL WITH 2PPB BIOZAN AT 2.67BPM, 11:05 16:50 5.75 STWHIP P WEXIT TAG & MILL PILOT HOLE FROM IN HARD CEMENT Printed 6/11/2010 3:24:36PM 11,085FT USING 2% KCL WITH 2PPB BIOZAN AT 2.67BPM, 250OPSI FS, 100-150PSI MW, 2-2.5K WOB, 180 TF, 9.58 ECD, 25-30FT/HR ROP. MILL _TO STALL_ 16:50 17:10 0.33 STWHIP P WEXIT WIPER TO 11,070FT & TO 11,194FT. 117:10 18:00 0.83 STWHIP P _ WEXIT MILL CEMENT PILOT HOLE FROM 11,194FT USING 2% KCL WITH 2PPB BIOZAN AT 2.67BPM, 2330PSI FS, 100-15OPSI MW, 1.1-1.5K WOB, 180 TF, 9.58 ECD, 15-20FT/HR ROP. 18:00 18:45 0.75 STWHIP P WEXIT CONTINUE MILLING CEMENT PILOT HOLE AT 160L TF. STEADY 20-30 FT/HR. PVT = 307 BBLS. DHWOB = 1.5 KLBS. MILL TO 11226 FT. - 18:45 19:20 0.58 STWHIP P WEXIT _ WIPER TRIP TO 11,000 FT. PARK AT 11,000 FT AND FLOW CHECK WELL, OUT MM WAS SHOWING 0.05 BPM HIGHER THAN IN MM WHILE MILLING. FLOW CHECK NEGATIVE, RESUME MILLING. 19:20 - 22:15 2.92 STWHIP P— WEXIT MILL FROM 11226 FT AT 20-30 FT/HR. HOLD 160L TF. ROP IS STEADY 20-30 FT/HR WITH 1-2 i KLBS DWOB. 200-300 PSI MW. Printed 6/11/2010 3:24:36PM rr_1 Iafth Amen -ALA sKA - RP Page 24,10 0'Wat0h S.IIJI Regv�rt Common Well Name: 05-08 DIMS AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 6/3/2010 End Date: X3-OOVM3-C (1,432,563.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name/No.: NORDIC 1 Spud Date/Time: 6/8/1977 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°15'49.411"1 Long: 0148°24'16.647"W Active Datum: 19: 08 7/16/1999 10:49 @64.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:15 23:00 0.75 STWHIP P WEXIT WIPER TRIP FROM 11300 FTO TO 11000 FT. CLEAN PASS UP AND DOWN. 23:00 00:00 1.00 STWHIP P WEXIT MILL HARD CEMENT FROM 11300 FT, AT 160L TF. 200-300 PSI MW, 2K DWOB. _ PVT = 304 BBLS, ECD = 9.62 PPG. 6/9/2010 00:00 00:30 0.50 STWHIP P WEXIT CONTINUE MILLING PILOT HOLE TO 11350 FT. 00:30 02:00 1.50 STWHIP P WEXIT BACKREAM FROM 11140 TO 11100 AT OL TF, 2 TIMES. 02:00 04:30 2.50 STWHIP P WEXIT RUN BACK 'TO TD AND PUMP VISCOUS SWEEP AROUND, THEN POOH. PULL BACK TO 11000, RIH 80 FT AND OPEN EDC. PUMP 3.2 BPM ON THE WAY OOH. VISCOUS PILL BRINGS BACK LOTS OF MILLED UP CEMENT. _ PERFORM JOG AT SURFACE. 04:30 04:45 0.25 STWHIP P WEXIT PJSM FOR L/D BHA. 04:45 05:20 ! 0.58 STWHIP P WEXIT TAG STRIPPER AND L/D BHA. MILL IS 3.78" � NO-GO. TROUBLESHOOT ELECTRICAL CONNECTION IN UQC, WERE GETTING INTERMITTANT SIGNALS WHILE DRILLING. PROBLEM IS FOUND IN FLOW SUB, CHANGE IT OUT. 05:20 06:20 1.00 STWHIP N RREP WEXIT REPLACE E -LINE BOOT. TEST WIRE - GOOD. 06:20 07:00 0.67 STWHIP P WEXIT MU DRIFT BHA. STAB ONTO WELL. 07:00 09:10 2.17 STWHIP P WEXIT SLOW PUMP RATE AT SURFACE = 593PSI, 0.21 BPM. RIH WITH DRIFT BHA (BHA #2), CIRC MIN RATE 0.21 AT 593PSI. 09:10 09:35 0.42 STWHIP P WEXIT LOG DOWN FOR TIE-IN FROM 10,90OFT. MINUS _ 17FT CORRECTION. 09:35 09:55 0.33 STWHIP P WEXIT CONTINUE TO RIH. WT CK AT 11,070FT = 48K, RIW = 22.5K. RATTY AT 11,20OFT 3-5K WT BOBBLES, TAG AT 11,351 FT. 09:55 10:15 0.33 STWHIP P WEXIT _ PUH TO 11,065FT. PUW = 48K. PUMP 2.71 BPM/2720PSI. 10K OP AT 11,20OFT. 10:15 10:25 0.17 STWHIP P WEXIT RIH, PUMPING 2.78BPM/2878PSI. SLIGHT BOBBLE AT 11,20OFT. TAG AT 1,1351 FT. 10:25 10:38 0.22 STWHIP P WEXIT PUH TO 11,065FT, PUMPING 2.63BPM/2681FT. 2K 10:38 10:50 0.20 STWHIP P WEXIT OP AT 11,20OFT. _ RIH WITH NO PUMPS, 22K RIW. 1.5K SET DOWN AT 11,20OFT. TAG AT 11,351 FT 10:50 11:00 0.17 STWHIP P WEXIT PUH TO 11,065FT, PUMPING 2.78BPM/2878PSI. SLIGH OP AT 11,20OFT. 11:00 11:05 0.08 STWHIP P WEXIT RIH WITH NO PUMPS. 0.8K SET DOWN AT _ 11,20OFT. TAG AT 11,351 FT. 11:05 11:30 0.42 STWHIP P WEXIT PUH TO 11,065FT, PUMPING 2.86BPM/2893PSI. CLEAN AT 11,20OFT. 11:30 12:00 0.50 STWHIP P WEXIT � RIH WITH NO PUMPS AT 10FT/MIN. 0.7K WT fBOBBLE AT 11,20OFT. TAG AT 11,351 FT. Printed 6/11/2010 3:24:36PM Common Well Name: 05-08—DIMS AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 6/3/2010 End Date: X3-OOVM3-C (1,432,563.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name/No.: NORDIC 1 Spud Date/Time: 6/8/1977 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°15'49.411"1 Long: 0148°24'16.647"W Active Datum: 19: 08 7/16/1999 10:49 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (ft) 12:00 14:35 2.58 STWHIP P WEXIT POH PUMPING 2.53PM/2483PSI. CLEAN AT 11,200FT. 14:35 14:50 0.25 STWHIP P WEXIT PJSM REGARDING LD DRIFT BHA & MU WS SETTING BHA. 14:50 15:10 0.33 STWHIP P WEXIT POP OFF WELL. PLACE INJECTOR OVER BUNG HOLE. BLOW DOWN BHA. LD DRIFT BHA. 15:10 16:25 1.25 STWHIP P WEXIT HOIST BOT WS & WS SETTING BHA FROM GROUND TO PIPE SHED. MU WS & WS SETTING BHA. MU BHI INTEQ TOOLS TO WS SETTING BHA. STAB ONTO WELL WITH INJECTOR. 16:25 18:50 2.42 STWHIP P WEXIT RIH WITH WS SETTING BHA (BHA #3). CIRC THROUGH EDC AT 0.66BPM/930PSI. WT CHECK AT 10800 FT IS 46K. 18:50 19:20 0.50 STWHIP P WEXIT LOG FROM 10900 FT TO TIE-IN, CORRECT -14 FT. CONSISTENT WITH OTHER CORRECTIONS. CLOSE EDC. 19:20 19:40 0.33 STWHIP P WEXIT RIH TOSETTING DEPTH. SLIGHT WT LOSS AT 11200FT, <1 K. RIH Toll 312.81 FT WHICH PUTS TOP WHIPSTOCK AT 11300.0 FT. TF IS 180L. PRESSURE UP TO 1200 PSI, PRESSURE BREAKS OVER BRIEFLY THEN PRESSURE CLIMBS AGAIN WITH WT LOSS TO 4200 PSI SHEAR PRESSURE. HAD 8K DWOB BRIEFLY, FALLS OFF AFTER SHEARING. __. PICKUP IS CLEAN, 52K WITH NO PUMP. 19:40 - 21:00 1.33 STWHIP P WEXIT POOH, PUMP 1.3 BPM / 1890 PSI. PJSM FOR L/D BHA WHILE POOH. 21:00 - 22:30 1.50 STWHIP P WEXIT TAG STRIPPER AND UD WHIPSTOCK RUNNING TOOLS. J -HYDRAULIC SETTING TOOL HAS FUNCTIONED NORMALLY. REMOVE HOT FROM COILTRAK AND REPLACE DGS AND P&C. 22:30 - 23:100.67 STWHIP P WEXIT M/U BHA #4 - MlLL, STRING RgAMER MOTOR, _ SPIRAL CENTRALIZER, 2 JTS PH6 AND 3" COILTRAK. MILL IS 3.79 NO-GO, REAMER IS 3.78 NO-GO. BHA OAL = 119.65 FT. 23:10 00:00 0.83 STWHIP P WEXIT RIH BHA #4. PUMP 0.15 BPM /740 PSI THROUGH _ MILL. 6/10/2010 00:00 01:10 1.17 STWHIP P WEXIT CONTINUE RIH. STACK WT AT 10896 XN, PICK UP AND SPIN THROUGH IT. 01:10 01:35 0.42 STWHIP P WEXIT LOG GR FROM 10940 FT. CORRECT -15 FT. S- � O S-00ft Printed 6/11/2010 3:24:36PM TREE = CM/ WELLHEAD = AC -M JATOR = FMC 5M BAKER C KB. ELEV = 64' BF. ELEV = VLV KOP= ? Max Angle = 52' @ 6400' Datum MD = Datum TVD - 11300' 8800' SS 9-5/8" CSG, 47#, L-80 HYD 563, ID = 8.681" 2420' 9-5/8" BOT CSG PATCH, ID = 9.725" 2424- DATE VLV 13-3/8" CSG, 72#, MN -80 BUTT, ID = 12.347" 2733' Minimum ID = 3.725" @ 11034' 4-1/2" HES XN NIPPLE 4-1/2" TBG STUB I-- 11070' 4-1/2" TBG, 12.6#, 13C R-80 VAMTOP, 11080' .0152 bpf, ID = 3.958" 14-1/2" TBG, 12.6#, L-80 BTC -M) 11118' ELM .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: BHCS ON 06/26/77 ANGLE AT TOP PERF: 50' @ 11351' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE VLV 11351 - 11385 S 11/16/77 2 1 11400 - 11420 S 11/16/77 MMG MMG 11440 - 11450 S 11/16/77 4" 4 11450 - 11460 S 11/17/88 -- -- 11482- 11516 S 11/06/77 4" 4 11516- 11532 S 05/04/00 3-3/8" 6 11528- 11534 O 05/22/03 3 3/8" 4 11568 - 11590 S 11/26/87 4" 4 11589 - 11630 S 11/17/88 3 3/8" 4 11610- 11640 O 05/13/00 PBTD 11662' 9-5/8" CSG, 47#, J & L 95/N-80 BUTT, ID = 8.681" 11837' TD 11860' 1 1: SAFEfY*ES: ***CHROMETBG*** 2124' -�4-1/2" HES X NIP, ID = 3.813" 2338' 9-5/8" NALCO FOC 2408' �l8" HES CEMENTER 2461' 9-5/8" NALCO FOC GAS LIFT MANDRELS STf6920 REV BY TVD DEV TYPE VLV LATCH PORT DATE 2 1 HW/JDM 3554 6038 20 51 MMG MMG DMY DMY RK RK 0 0 01/21/10 01/21/10 10896' 1-1 4-1/2" HES X NIP, ID= 3.813" 10927' —19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10962' 4-1/2- HES X NIP, ID = 3.813" 11034' 1--14-1/2" HES XN NIP, ID= 3.725" 11081' (-19-5/8"X4-1/2"UNIQUE OVERSHOT 1 11109' 9-5/8" X 4-1 /2" BKR S-3 PKR, ID = 3.875" --T 1111 1 i�E JET CUTTAILPIPE(06/05/09) w i12so' Fk,ked tJ IpsAtcL 113()Z:)' ra,�� ( k.PS+oc�- Sc+ -` 1 \ 350 t��,Ma1ec� P;1o+- 44 {e 4?VA 11566' 1-1 FISH: JET CUT TT w /WRP (TAGGED 06/11/09) 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/04/77 PKR 141 ORIGINAL COMPLETION 09/26/08 HW/JDM DRLG DRAFT CORRECTIONS 09/07/83 N1 ES RWO 10/20/08 PJC DRAWING CORRECTIONS 11/21/88 WSR-1 RWO 06/05/09 RRD/TLH JET CUT TT, TAGGED 6/11/09 12/25/97 1316 RWO 01/31/10 CJN/PJC GLV C/O (01/21/10) 07/22/081 D16 RWO 08/02/08 1 JCM PJC FISH / GLV C/O (07/30/08) PRUDHOE BAY UNIT WELL: 05-08 PERMIT No: *1770240 API No: 50-029-20248-00 SEC 32, T11 N, R15E, 2428' FSL & 233' FWL BP Exploration (Alaska) OS-08A CTD suspended work • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, June 15, 2010 4:40 PM To: 'Hoffman, Wilmer' Subject: RE: 05-08A CTD suspended work (PTD 210-055 anQ PTD 177-024) Wilmer, As we discussed the work done so far is covered under the Sundry 310-140 for the P & A of the mother wellbore ( PTD 177-024) . The basic scope of the P & A has not changed so no new sundries need to be submitted. If during the diagnostic work you see something that would change the P & A or how you drill the well we will need to sit down and discuss a plan for documenting any changes. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Hoffman, Wilmer [mailto:hoffmawj@bp.com] Sent: Tuesday, June 15, 2010 2:33 PM To: Schwartz, Guy L (DOA) Subject: 05-08A CTD suspended work Guy, 'n N-. ~ ,.~ lJ As a follow up to our conversation, here is a summary of what we discussed for your records. Nordic Rig #1 rigged up on well 05-08 in preparation for performing a sidetrack (05-08A) out of the parent well's 9- 5/8" casing. This new sidetrack is covered under PTD# 210055. The pre-rig work that was conducted was a cement P&A laid in by service coil which was covered under Sundry #310-140. Nordic Rig #1 moved in and milled a 3.80 pilot hole in the cement plug that was laid in pre-rig. A 3-5/8" open hole anchor and steel tray whipstock was set inside of the pilot hole to exit the 9-5/8" casing and proceed with drilling the new sidetrack. We attempted to exit the 9-5/8" and were unsuccessful. We came up hole and set another whipstock with the same configuration inside of the pilot hole. A second attempt at exiting the 9-5/8" proved to be unsuccessful as well. Both attempts showed evidence of staying inside of the parent well's 9-5/8" casing. Due to the failing attempts at getting departure from the parent well, the decision was made to move the rig off of 05-08 and proceed to the next well on the schedule. This will allow us to do some diagnostic work on the well prior to moving the rig back on it. We suspect that the whipstocks were pushed down hole during the window exit attempts but need to confirm this with diagnostic work. As you and I discussed, any screening work done to determine what occurred will be covered by the P&A sundry that was granted and referenced above. The new lateral was never started and therefore the PTD should still be valid for the proposed lateral (05-08A). Could you please respond acknowledging receipt and confirmation of our discussion as outlined above? Regards, 6/15/2010 OS-08A CTD suspended work • Page 2 of 2 WJH . ~~., Operations Drilling Engineer Coiled Tubing Drilling BP (Exploration) Alaska, Inc. Direct 907.564.4592 Cell 907.250.2601 6/15/2010 • • John McMullen Engineering Team Leader BP Ex loration Alaska Inc. - ~ ~.~Fs P ~ ), .~<<~,.~~ ~~ ^ ~~ ~ P.O. Box 196612 ~' ~ '` ` ~':~.v `~ Anchorage, AK 99519-6612 ~ ~~ y Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-08 ~1 Sundry Number: 310 140 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of April, 2010. Encl. ~~ o (/I"' ~i'~~ STATE OF ALASKA ~~~ A~LASKI~L AND GAS CONSERVATION COMMIS~I Cj~1V~C~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 APR 2 6 2010 1. Type of Request: ^ Abandon ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Ap~ • ~O1f11NSS10tt ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ~tIC~P21q~ ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 177-024 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20248-00-00 - 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 05-08 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028326 & 028329 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11860' - 9227' - 11662' 9097' None 11566' Casin Len th Size MD TVD Burst Colla e Structural Conductor 1 1 1 0 Surface 273 ' 1 -3/ " 2733' 27 3' 5380 2 70 Intermediate Production Liner 11837' 9-5/8" 11837' 212' 6870 47 0 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11528' - 11640' 9010' - 9083' 4-1/2", 12.6# 13Cr80 / L-80 11118' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'S-3' packer Packers and SSSV 10927' / 8633' 9-5/8" x 4-1/2" Baker'S-3' Packer MD (ft) and TVD (ft): 11109' / 8745' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WA "Plugged ^ SPLUG Commission Representative: ~~L/S / 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Wilmer Hoffman 564-4592 Printed Name Jo rf M u ft Title Engineering Team Leader Prepared By Name/Number Signature ~' Phone 564-4711 Date 2 z /~} Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness ~' ... > / Sundry Number: `y ^ Plug Integrity ®'BOP Test ^ Mechanical Integrity Test ^ Location Clearance -* 35vc, P~~ Q©P s~-- / Other: ~ ~ n n ~ S ~' `~'"`"'~) -~ZSDo Pf~ Subsequent Form Required: /O ' ya APPROVED BY ~ p~ / ~+, D O V ate Approved By: COMMISSIONER THE COMMISSION Form 10-403 Revised ~~DMS A DD ~ Q 2010 y Z 7 / O Submit In Duplicate ~7 !i!"f~ v RIG 1 N A L ~ t//2T~~j To: Chairperson Alaska Oil & Gas Conservation Commission From: Wilmer Hoffman CTD Engineer Date: April 19, 2010 Re: OS-08 Sundry Approval by Sundry approval is requested for we1105-08. We1105-08 was originally drilled and completed in November 1977 as a Zone 2B/Zone 2A well. The producing intervals have been squeezed and re- perforated several times as production restraints have changed. A workover in 1997 replaced leaking tubing and eliminated a production straddle assembly. In 1999 a BCNL identified leaking Zone 2B squeezed perfs and these were squeezed again in 2000. At the same time lower Zone 2A perfs were shot and this dramatically reduced the gas production and improved well performance. In May of 2003, 6' of perfs were added in lower Zone 2B resulting in slightly higher c~il production. An STP log ran in 2005 identified the majority of flow from the Zone 2B perforations; A caliper log was run in October of 2005 and it indicated the tubing was in good condition. In November of 2005 the well was secured with a TTP set at 11,136' SLM. The well required several bleeds due to increasing tubing pressure indicating a leaking TTP. It was pulled and replaced with a WRP set at 11,104' in March of 2006. The well failed anMIT-T and MIT-IA but passed a CMIT TxIAxOA in May of 2006 confirming surface casing integrity. A workover was performed in 2008 to fix the production casing and tubing leak. Slickline was unable to pull the WRP and put the well on production. Additionally a bailer was stuck above the plug. Multiple fishing operations followed the workover but were all unsuccessful. In June of 2009 the tubing was jet cut at 11,118' and the fish was tagged. The well started to flow as a swing well for pad velocity constraints. It flowed as a full time producer after another well was choked back until December of 2009 when the GOR made it uncompetitive. An MIT-IA passed to 3,000 psi on 1/22/2010 and anMIT-OA failed to 2,000 psi on 1/26/2010. REASON FOR SIDETRACK: We1105-08 produces above marginal with minimal remaining value and no wellwork options left. The proposed location is intended to optimize off take in a ~55 acre drainage area targeting Z1B/Z2A. The proposed plan for OS-08A is to drill a pilot hole through a cement plug, finish it off with a cement ramp an si etrac with t e SLB/Nordic 1 Coiled Tubing Dri mg rig on or aroun une 10. he existing perforations will be isolated by a cement plug to be laid in y service coil pre-rig. The sidetrack, OS-08A, will exit the existing 9-5/8" and kick off into Zone 2 just below the base of the conglomerate. This sidetrack will be completed with a 3-1/2" x 3-3/16" x 2-7/8" tapered 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. ©SE~~ „~.~!/ yv~l~ Ihv~,t' T"~- `!'NkP yt1:'~ar q j~,.~. ~jr,~/~?J ~C~P1~ Gl~'%~/ ~~r~'igt~ I ~ 1(^Y' (~~y/l / /':.. ~~J'C. L'U r.. ~ i./-~ /r/.~ ~~' ~'*lV~. ~~t! % ~jj/4! ~/ p/ J ~,,,~,jl ~ ~ 'T .°'! • Pre-Rig Work: (scheduled to begin May 1, 2010) 1. S Drift and tag fill (done on 12/16/09) 2. F Function LDS, PPPOT-T, PPPOT-IC (passed on 1/14/10)• 3. S Dummy off GLVs #1 and #2 (done on 1/21/10) 4. F MIT-IA to 3,000 psi (passed on 1/22/10)' 5. F MIT-OA to 2,000 psi .(failed on 1/26/10) 6. D MIT-OA with nitrogen to 500 psi (passed on 1/31/10) 7. C Mill out XN Nipple at 11,034' to 3.80" - 8. C Set 40 bbl, 17 #/gal cement plug in 9-5/8" up to tubing tail 9. C Freeze protect the well and thoroughly wash the tree 10. C MIT-T to 1,000 psi for 30 mins 11. O Bleed wellhead pressures down to zero. 12. O Bleed production flow lines and GL lines down to zero and blind flange 13. O Remove wellhouse, level pad < Rig Work: (scheduled to begin around June 1, 2010) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Dri113.8" pilot hole and cement ramp from top of cement at 11,118' down to 11,350' 3. Mill 3.25" window at 11,3UU' and lU' of rathole in "Gone 2. Swap the well to Geo-V1s. 4. Drill Build: 4.125" OH, 400' (35 deg/100 planned) 5. Drill Lateral: 4.125" OH, 2,130' (12 deg/100 planned) with resistivity 6. Run 3-1/2" x 3-3/16" x 2-7/8" tapered L-801iner leaving TOL at 11,000' 7. Pump primary cement leaving TOC at 11,000', 32 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL/GR/CCL log 9. Test liner lap to 2,000 psi. 10. Perforate liner per asset instructions (800') 11. Set liner top packer 12. Freeze protect well, set BPV, RDMO. Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Generic GLV's 3. Test separator Wilmer Hoffman CTD Engineer 564-4592 Ps A- r --~' S~f NIA.;ps. f'r ~ pia mss' CC: Well File Sondra Stewman / Terrie Hubble ~ ~ TREE = ci WELLHEAD = FMC ', ACTUATOR= BAKER KB. ELEV = E ~. ELEV = KOP = Max Angle = 52' ~ 641 Datum MD = 1131 19-SA8' CSG, 47/, L-80 HYD 563, ID = 8.881° 9-5~" EX)T CSO PATCH, ID = 9.725" 13-318" CSG, 72/, MN-EO BUTT, ~ = 12.347" O ~ ~ ~ SAFEiYMOTES: ""•CFliDME T®6"" Minimum ID = 3.725" ~ 11034' 4-1f2" HES XN NIPPLE 12"HESXN~.~=3.813" ~9-SAB" X 4-1 /2" BKR S-3 PK R, ID = 3.875" ~ 4-1l2"FIESXN~,O =3.813" a_~ rr NFC xta a~+ m = ~ ~~s" 14-112' TBO STUB 4-1 A2" TBG, 12.64,17[R-N VAM TOP, 0152 bpt, D = 3.958" 4-1f2" TEr<3,12.6i,1-80 BTC-M, .0152 bpf, ~ = 3.958" X 4-112" UNIQUE OVERSFiBOT X 4-112" BKR S-3 PKR, ~ = 3.875" CUT TA~P~E (O6rD5109~ PERFORAT~N SUMMARY REF LOO: BRCS ON 06126/77 ANGLE AT TOP PERF: 50' ~ 11351' Note: Rater to Production ~ for historical erf data SIZE SPF INTERVAL OpnlSgx DATE -- 11351 - 1136.5 S 11M6A7 -- -- 11400-11420 S 11M6177 -- -- 11440- 11450 S 11M6R7 4" 4 11450-11460 S 11M7~8 -- 114 82 - 11 516 S 11106!77 4" 4 11516-11532 S OSAD4AD0 3.3~" 6 11528 - 11534 O 05/22~D3 3 3B" 4 11568 - 11590 S 11l26~7 4" 4 11589 - 11630 S 11 M 7/88 3 3rB' 4 11610 - 11640 O OSM 3AD0 sac i ~T n~aNnr~i ST MO TVD DEV TYPE VLV LATCH PORT DATE 1 3572 6920 3554 6038 20 51 MMO MMO bOME SO RK RK 16 22 07I30AD8 O7C30AD8 DATE REV 9V COMMENTS BATE REV BY CgdMENTS ii1MRi PIN17#1 ONN~NALCONIPLETNIN 09/26AD8 FNYAIDAI ORL(3DRAFTCORRECTIONS /lN~i7 NtES VINO 10-20A8 PJC ORAIMdO CORRECTKNJS 11Rf INI 1MlZ~-1 R1AID O61DSA09 BROKER JET CUT TT TA0f3ED Fi1111~ 1l~Jt7 Oli R1w10 IiRtON D'li ItN10 08A2iU8 JCM~PJC F~fi /GLV CAD (07130A08) PRUDMOE BAY IA+MT WELL 05-08 PERMIT Na 1770240 API No: 50.029-20248-00 T11 N, R15E, 2428' FSL 8 233' ~ Ea~tar~tias I~~q TREE = CNV WELLHEAD= FMCSM O ~ _~ SIIFETYNOTES: "'CHROME TBG"' ACTUATOR = BAKER C KB.ELEV= 64' Proposed CTD Side rack BF: ELEV._' ..................................._~. KOP = ? 2124 4-1l2" HES X NIP, ID = 3.813" Max Angle = _.52' (c~.6400' ' 2338' 9-5!8" NALCO FOC Datum MD = 11300 Datum TVD = 8800' SS 2408' 9-518" HES CEMENTER 9-518" CSG, 47#, L-80 HYD 563, ID = 8.681" 24211' 2461' 9-518" NALCO FOC 9-518" BOT CSG PATCH, ID = 9.725" 2424' 13-318" CSG , 72#, MN-80 BUTT , ID = 12.347" 2733' Minimum ID= ~.3tf" ~ 110Q0' 10896' 4-112"HESXNIP,ID=3.8f3" 3,3116" TOL 10927' 9-5!8" X 4-112" BKR S-3 PKR, ID = 3.875" 10962' 4-1 !2" HES X NIP, ID = 3.813" ° 10990' a-1 r° eI~:R ~.e LrP iD = , ~,,' 51 ~ 11000' ToL, Tic io = 2.3u° 4-112" TBG STUB 11070' I 11034' 4-1 l2" HES XN NIP, ID milled tc = 3 g0" 4-112" 780,12.6#,1]C&i0 VAM TOP, 11080' ~ 11081' 9-5!8" X 4-112" UNIQUE OVERSHOT .0152 bpf, ID = 3.958" 11109' 9-518" X 4-112" BKR S-3 PKR, ID = 3.875" 4-112" TBG, 12.6#, L-80 BTC-M, 11118' E LN i 11118' ELM JET CUT TAILPIPE (O6!OSN9) .0152 bqf. ID = 3.958" ~ PERFORATION SUMMARY REF LOG: BRCS ON 06/26/77 ANGLE AT TOP PERF: 50' ~ 11351' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE -- -- 11351 - 11385 S 11 M 6177 -- -- 11400 - 11420 S 111'16177 -- -- 11440 - 11450 S 11116/77 4" 4 11450 - 11460 S 11117188 -- -- 11482 - 11516 S 11!U6/77 4" 4 11516 - 11532 S 05/041D0 3-3!8" 6 11528 - 11534 0 05122/03 3 318" 4 11568 - 11590 S 11/26/87 4" 4 11589 - 11630 S 11 M 7188 3 318" 4 11610 - 11640 O 05113/00 J8 II .1 11700' h13-112" x 3-3-16" XO 3-5!B" Whipstock 3-:3M 8 x 2-?!~ x-over BCGL 113Q0' 51° 3-112" x 3-3116" x 2-7!8" liner 13830' 3.80" OD pilot hde down to'11350' 11566' FISH: JET CUT TT wM!RP DATE REV BY COMMENTS DATE REV BY COMMENTS 07104Ai PNR 141 ORIGNIAL COMPLETION 09126108 HW/JDM DRLG DRAFT CORRECTIONS Oil1071i] N1 ES RIArO 10C20f08 PJC DRAVWNGCORRECTIONS 11Il71ii 1NSN.1 RWO 06105N9 RRD/TLH JET CUT TT, TAGGED 6M1 N9 7~R51Ji D1i RIAfO 01126M0 MSE PROPOSED CTD SIDETRACK OiR210i D7i RWO 08/02AD8 JCM!PJC FISH / GLV C10 (07130108) PRUDHOE BAY UNIT WELL: OS-08:. PERMIT No: API No: 50-029-20248-01 T11N, R15E, 2428' FSL 8 233' FWL NP E~lontiara (INeak~ ~chlumt~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job k NO. 5481 ~~F. ;',~;--W~ ~ (~~~ ~'~ I V Company: .State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 log Description Date BL Color rn U-10 B3S0-00048 CROSSFLOW DETECT/IBP C-13A AVYO-00060 C CBL - ~ 03/02/10 1 1 ____ AGI-01A AVYO-00056 USIT `~ 02/16/10 1 1 03-37 BBSS-00002 SONIC SCANNER 02/10/10 1 1 __ _ 03-37 BBSS-00002 -MSIP - [, SS-ANALYSIS BEHIND CSG 02/14/10 1 1 ____ 07-21 83S0-00045 _ SPINNER LOG/PRE-IBP L 02/14/10 1 1 P2-48 AVYO-00057 PROD PROFILE REDO 02/24/10 1 1 AGI-OtA B9RH-00014 JEWELRY LOG W/PRESS/TEMP 02/11/10 1 1 W-204 B14B-00097 GLS (~ -- ( 02/27/10 1 1 09-41 BBSK-00010 CROSSFLOW RECORD 03/01/10 1 1 - 15-27 15-27 BBUO-00006 BBUO-00006 ,, RST GRAVEL PACK LDL _ 03/06/10 03/05/10 03/05/1 1 1 1 1 MPC-22A 05-08 BAUJ-00007 BBSK MEM PPRO W/GLS REVISED 0 02/11/10 1 1 1 1 D-048 -00001 10715393 RST ~ ~' ~' MCNL REVISED 01/17/10 1 1 E-19B 11767134 ~ MCNL 04!07/04 1 1 18-30A B2NJ-00052 REVISED - MCNL _ ~ ~' 07/21/07 1 W-56 09AKA0186 OH MWD/LWD EDIT _ L 01/31/10 1 1 12/19/09 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: un r: ,,,.~.,...,:~.. ,,,~ ......... ... . --- t'etrplectu'iical Ddla Center LR2-1 90~ E Benson filvrl- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 0:1/ 10l I O 1~ STATE OF ALASKA la' ~~~`'v `~ ALA OIL AND GAS CONSERVATION COMII~ION AU G 2 1 200c~ REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas CO~is. C~rrlf,;issi~r 1. Operations Performed: ~ ~ ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing f ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Exte nsion 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 177-024 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20248-00-00 7. KB Elevation (ft): 64, / 9. Well Name and Number: PBU 05-08 8. Property Designation: 10. Field /Pool(s): . ADL 028329 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11860 - feet true vertical 9227 feet Plugs (measured) 11120 Effective depth: measured 11662 feet Junk (measured) 11094 true vertical 9097 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 20" 109' 109' 1530 520 Surface 2733' 13-3/8" 2733' 2733' 5380 2670 Intermediate Production Liner 11837' 9-5/8" 11837' 9212' 6870 4760 ~'~~ A U u" 2 ~ 2008 Perforation Depth MD (ft): Below Plug: 11528' - 11640' Perforation Depth TVD (ft): 9010' - 9083' 4-1/2", 12.6# 13Cr80 / L-80 11167' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; 10927'; 9-5/8" x 4-1/2" Baker'S-3' Packer 11109' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut, pull and dress off tubing at 11065'. Cut, pull and dress off 9-5/8" casing to 2421'. Run 9-5/8" Tieback to 2424', cement w/ 164 BBIs Class'G' 921 cu ft / 787 sx . Run 4-1/2" Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ 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: Contact Howard West, 564-5471 308-231 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: ~~ _ / Signature Phone 564-4628 Date ~~ ~(!y Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ' ~ ~ ~ ~ ~ Submit Original Only O ~ S B~~ AUG ~ 61008 ~~C~ ~-~~ Digital Well File Page 1 of 1 • • ' Well: 05-08 Well History Well Date Summary 05-OS 6/23/2008 ***WELL S/I ON ARRIVAL*** DUMP BAILED 2 BAGS (SLUGGITS) ON WRP ~ 11,120' MD ***LEFT WELL S/1, NOTIFY DSO"*'* 05-08 6/24/2008 T/I/O=SSV/440/340 Temp =S/I Circ well (RWO planned) Road to location MIRU***Job in progress continued on 06-25-08*** 05-08 6/24/2008 ***WELL SHUT IN UPON ARRIVAL ***MASTER AND SWAB VALVES CLOSED ON ARRIVAL. INITIAL T/I/O = 150/500/350 RIH WITH 3.65" SCP POWER CUTTER AND CUT 4.5" TBG AT 11070'., FINAL T/I/O = 250/450/350 PSI. *** JOB COMPLETE *** 05-08 6/25/2008 *** Job continued from 06/24/08***T/I/0=400/440/340 Temp=S/I Circ weld- OMIT TxIAxOA PASSED to Pumped 10 bbls neat meth & 1208 bbls 110*F 1 % KCL down Tbg 2000 psi 3rd attempt (RWO planned) . tak'in`g rye urns up t roug tumper oop & down Flowline of well 05-20. Pumped 155 bbls 100*F diesel down Tbg & U-tubed for freeze protect TxIA. Pumped 12.9 bbls diesel to test for CMIT, T/I/O lost 30/30/30 psi in 1st 15 min and 10/10/10 psi in 2nd 15 mins for a total loss of 40/40/40 psi in 30 mins. Bled WHP's down -10 bbls. Final WHP'sT/I/0=0/0/0 Annulus casing valves tagged and left open to gauges DSO notified of valve positions upon departure. Swab= Closed, Wing= Closed, SSV= Closed, Master= Open, IA= Open, OA= Open 05-08 6/26/2008 T/I/0= VAC/0/20. Temp SI. T, IA, & OA FLs (RWO prep) call-in 5525. TBG FL near surface. IA FL near surface. OA FL near surface. 05-08 6/27/2008 T/I/O =0/0/0 Set 4-1/16 "ISA BPV #511 03104" 1-2 ext.used ..pre-rig...no problems. 05-08 6/27/2008 T/IA/OA=SI/0/0 Temp cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP bleed tools onto THA 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "Standard" (3) were tight but all moved with no problems. PPPOT-IC RU 2 HP bleed tools onto IC test void 50 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3450/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycle and torque LDS "Standard" all moved with no problems. 05-08 7/6/2008 T/I/0=0/0/0. Set 4" FMC ISA BPV 05-08 7/6/2008 T/I/0=vac/0/0 pull 4" fmc bpv thru tree Print Date: 8/14/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 8/14/2008 • • BP EXPLORATION Operations Summary Report Page 1 of 13 ~ Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 17/9/2008 100:00 - 07:30 I 7.501 WHSUR I P 07:30 - 09:00 1 1.50 I MOB I P 09:00 - 10:00 ! 1.00 I MOB ) P 10:00 - 13:00 3.00 MOB P 13:00 - 16:00 3.00 MOB P 16:00 - 17:00 1.00 MOB P 17:00 - 00:00 7.00 MOB P 7/10/2008 00:00 - 07:00 7.00 MOB P 07:00 - 18:00 I 11.001 CONS I P 18:00 - 20:00 2.00 MOB P 20:00 - 21:00 1.00 RIGU P 21:00 - 22:00 1.00 RIGU P 22:00 - 23:00 1.00 RIGU P 23:00 - 00:00 ! 1.001 DHB I P 1/2008 100:00 - 00:30 I 0.501 DHB I P 00:30 - 01:30 I 1.00 I KILL I P 01:30 - 04:00 2.501 KILL P 04:00 - 04:30 I 0.501 KILL I P 04:30 - 05:30 I 1.001 DHB I P RUNCMP Rig Down LRHOS. Rig Down Secondary Annulus Valve. Secure All Tree Valves, Install Gauges and Jewerly on Tree. Suck Out Slop Tank and Rig Down Circ Manifold in Cellar. Release Ri from L1-09 at 07:30 Hrs on 07/09/2008 PRE Bridle up derrick and R/D rig floor. Gave AOGCC 24 hr Notice of initial BOP Test on DS 05-08 at 08:45 hrs, 7/9/2008. PRE PJSM with rig crew. Discuss and prepare to lay down derrick. Lay down derrick mast. PRE Jack rig up and move off L1-09. Stage rig. PRE Remove BOPE from cellar and install on carrier. Install front and rear booster wheels. PRE Wait on Security escort. Continue to prep for rig move. PRE Move rig from L1 pad to DS 05. PRE Continue to move Doyon 16 from Li -Pad to DS-05. Double stack rip mats to leap frog and mat the DS 05 access road. _i nrs to move down access roatl on to DS 5. PRE Rig crew remove front and rear booster wheels. Rig welder repair derrick bolster. Inspect derrick repairs with Tuboscope. Prime and paint repair areas. Remove and replace pipe skate main ram. New pipe skate ram not functioning correctly after install, remove and reinstall old ram. PRE P/U rig and move over well slot 5-08. Shim rig into position. PRE PJSM with rig crew covering raising and pinning derrick mast. Raise derrick mast and secure. PRE R/D derrick bridle lines. R/U rig floor. PRE Spot and R/U #2 mud pump and #4 generator. R/U circulating hoses to tree, wellhead, and rig. DECOMP P/U DSM lubricator and tools. Load 120 deg seawater in mud pits. DECOMP R/U DSM lubircator and test to 500 psi, good test. Pull and UD BPV. R/D and L/D DSM lubricator and tools. DECOMP Inspect and finish R/U circulating lines. Continue to fill mud pits with hot seawater. Charge up lines and pressure test circulating lines 3500 psi, good test. DECOMP PJSM with rig crew and CH2MHill. Discuss pumping procedures for displacing wellbore fluids, taking safety precautions, and assign job assignments. Tubing Pressure- 0 psi, IA Pressure- 0 psi, OA Pressure- 80 psi. Open OA and bleed off pressure. Line up and reverse circulate 72 bbls to remove freeze protection off tubing at 2.6 - 4.7 bpm with 700 to 3000 psi. Line up and circulate down tubing. Pump 20 bbl high visc spacer and follow with 800 bbls of hot 8.4 ppg seawater at 8.4 bpm with 1250 psi. After diesel was pumped out of back side, increase pump rate to 10 bpm with 1600 psi. DECOMP Monitor well, tubing pressure at 0 psi, IA pressure at 0 psi, OA pressure at 0 psi. DECOMP R/D circulating lines. R/U and set BPV as per FMC Wellhead Tech. Test BPV to 1000 osi from below for 10 charted minutes. m off I Bump pressure back up to 1300 psi and maintain pressure for Printed: 8/14/2008 8:58:25 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Event Name: WORKOVER Contractor Name: DOYON Rig Name: DOYON 16 Date From - To Hours Task Code 7/11/2008 04:30 - 05:30 1.00 DHB P Page 2 of 13 Spud Date: 6/8/1977 Start: 7/8/2008 End: 7/22/2008 Rig Release: 12/24/1997 Rig Number: 16 NPT Phase Description of Operations DECOMP 10 charted minutes by pumping from amtain a visual on BPV. Nothing le 05:30 - 06:30 1.00 WHSUR P DECOMP and R/D circulatirg lines, circulating manifold and hoses. 06:30 - 09:00 2.50 WHSUR P DECOMP PJSM. N/D Tree and adapter flange. Bleed Down Control Line. L/D Tree and Adapter. Check Threads on Hanger, 8-1/2 LH Turns (5-3/4" LH Acme -Not NSCT as Tubing Tally Documents ). Install Blanking Plug. 10-1/4 LH Turns. 09:00 - 11:30 2.50 BOPSU P DECOMP N/U 13-5/8" BOPE. 3-1/2" x 6" VBR's, Mud Cross, Blind Shear Rams, and Annular Preventer. 11:30 - 12:00 0.50 BOPSU P DECOMP R/U Test Equipment for BOPE. 12:00 - 16:30 4.50 BOPSU P DECOMP Test BOPE. Test to 250 psi low and 3500 psi high with 4" and 4-1/2" Test Joints. Charted Test for minimum of 5 mins. AOGCC waived state's right to witness BOP test by John Crisp. Witnessed by BP WSL and Doyon Toolpusher. #1 - 4" Test Joint in VBR's #2 -Valves 12, 13, 14, Hydril, Kill HCR, Upper IBOP #3 -Manual Kill, Valve 9, 11, Lower IBOP #4 -Valve # 5, 8, 10 ,TIW #5 -Valve # 4, 6, 7, Dart #6 -Valve #2 #7 -Valve #3, 1 #8 -Choke HCR #9 -Choke Manual #10 - 4-1/2" Test Joint in VBR's Koomey Test= 3000 psi inital pressure, 1900 psi after function of preventers. 200 psi build up in 15 sec, full pressure in 1 min 14 sec. 5 bottles ~ avg pressure of 2150 psi. 16:30 - 17:00 0.50 BOPSU P DECOMP R/D Test Equipment and L/D Test Joints. P/U Landing Joint and M/U XO to Pull Blanking Plug. Pull Blanking Plug and L/D Landing Joint. B/O 4-1/2" IBT XO off Test Joint. 17:00 - 19:00 2.00 WHSUR P DECOMP P/U Dutch Lubricator Extension and set in rotary table. P/U Valve Shop Lubricator. Pressure Test Lubricator to 500 psi. Found leak in top connection. Replace O-Ring. Test Lubricator again to 500 psi - god test. Pull FMC ISA BPV from Tbg Hanger. Well on vac. R/D DSM lubricator and tools. 19:00 - 19:30 0.50 PULL P DECOMP P/U landing joint and crossover to 5-3/4" LH Acme. RIH and engage tubing hanger. M/U top drive to landing joint. BOLDS. 19:30 - 20:00 0.50 PULL P DECOMP PJSM with rig team to discuss pulling tubing hanger free of tubing spool and tolerances. Pull popped free of tubing spool at 160,000 lbs. Continue to POOH with a P/U Wt of 155,000 lbs. 20:00 - 21:00 1.00 PULL P DECOMP Line up and circulate hole volume at 10 bpm with 540 psi. No gas during circulation. Hole took 12 bbls to fill hole. No noticeable losses while circulatin .Monitor well well'sTa'bl 21:00 - 22:00 1.00 PULL P DECOMP Disconnect dual control lines from tubing spool and M/U to Camco control line spooler. B/O and L/D tubing hanger assembly. M/U TIW valve for AB Modified Buttress Tubing. B/D top drive. 22:00 - 00:00 2.00 PULL P DECOMP POOH and L/D 4-1/2" AB Mod Buttress Tubing. Recover 56 joints of 4-1/2" tubing, tubing hanger assembly, dual SS control lines, 55 SS bands, and 1 SSSV. Fluid loss rate at .5 bph. 7/12/2008 00:00 - 04:30 4.50 PULL P DECOMP Continue to POOH and L/D 4-1/2" AB Mod Buttress Tubing. 04:30 - 05:00 0.50 PULL P DECOMP Held safety meeting with the crew that just arrived on the slope Printed: 8/14/2008 8:58:25 AM • • BP EXPLORATION Page 3 of 13 ~ Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Event Name: WORKOVER Contractor Name: DOYON Rig Name: DOYON 16 Date I From - To I Hours I Task I Code I NPT Spud Date: 6/8/1977 Start: 7/8/2008 End: 7/22/2008 Rig Release: 12/24/1997 Rig Number: 16 Phase Description of Operations 7/12/2008 104:30 - 05:00 I 0.501 PULL I P 05:00 - 07:00 I 2.001 PULL I P 07:00 - 08:00 I 1.001 PULL I P 08:00 - 09:30 I 1.50 I CLEAN I P 09:30 - 19:30 10.00 CLEAN P 19:30 - 20:00 I 0.50 I CLEAN I P 20:00 - 21:00 1.00 CLEAN ~ P 21:00 - 21:30 I 0.50 I CLEAN I P 21:30 - 00:00 I 2.50 I CLEAN I P 3/2008 100:00 - 01:30 I 1.50 I CLEAN I P 01:30 - 02:00 I 0.501 CLEAN I P 02:00 - 02:30 0.50 EVAL P 02:30 - 05:30 3.00 EVAL P DECOMP today. Discuss the HIPO on Doyon 14 and how the potential for that incident had not been noticed as a potential hazard for years. Each crew member was given the assignment of searching the rig for that type of potential hazard. DECOMP Continue to POOH and L/D 4-1/2" AB Mod Buttress Tubing. Over all Tbg in good sha e, some minor internal corrosion around pin ends but out side ood. L/D 269 Jts of 4-1/2" Tbg. 1 cut point, 3 LM's, 1 SSSV, Dual 1/4" Control Line w/ 55 Stainless Steel Bands. Cut Joint Measured 12.34 ft with -4-7/8" OD on Flare. DECOMP Clean and Clear Rig Floor. L/D Tbg Handling Equipment. C/O XO on Floor Valve. Set Wear Ring. DECOMP Gather BHA Components and M/U BHA #1, Tbg Dress Off BHA. Dress Off SHoe with Extensions, Boot Basket, Scraper, Bit Sub w/ Float, Bumper Sub, Pump Out Sub and 6- 6-1/4" DC's. Total Length = 233.19 ft. There is -18 ft of swallow with the 8-1/8"x4-1/2" dress off shoe and extensions. DECOMP RIH with Tbg Dress Off BHA on 4" HT-38 drill pipe 1x1 from Pipe Shed. RIH with 343 jts. Work 9-5/8" casing scraper from 10,867 to 10,963'. DECOMP Establish milling parameters of P/U Wt- 210,000 Ibs; S/O Wt- 143,000 Ibs; Rotary Wt- 169,000 Ibs at 40 rpm with 7000 ft-Ib free torque; Off Bottom Pump Pressure- 830 psi at 6 bpm. Continue RIH and tag top of tubing stump at 11,059'. S/O 10,000 Ibs. P/U and dry tag top of tubing stub to confirm 11,059'. S/O 10,000 Ibs on tubing stub. P/U and dress off tubing stub at 60 rpm with 7500 ft-Ibs free torque, torque increased to 9,500 ft-Ibs while dressing off tubing stub. Swallow 18' of tubing stub where inside dress off mill tagged top of tubing stub at 11,059'. Dressed off tubing stub to 11,060' with 60 rpm and 10,000 ft-Ibs torque. P/U off tubing stub. S/O without rotation and tag top of tubing stub at 11,060', P/U and S/O without rotation, dress off shoe slid over tubing stub without rotation. P/U and work over tubing stub with rotation 2 more times. DECOMP Pump 20 bbl high visc sweep at 10.2 bpm with 2220 psi. Bottoms up brought back fine metal shavings, sweep brought back a slight increase of fine metal to surface. DECOMP B/O and B/D top drive. R/U to POOH. Monitor well, well stable with a slight loss. DECOMP POOH with dress off assembly standing back 4" HT-38 DP in derrick. DECOMP Continue to POOH with dress off assembly standing back 4" HT-38 DP in derrick. Average Loss Rate While POOH= 1 BPH DECOMP POOH and L/D dress off assembly. Stand back 2 stands of 6-1/4" drill collars. Small amount of wear on inside mill. Recovered 1 gallons of metal shavings and 1 stainless steel band from boot basket. DECOMP Clear and clean rig floor. R/U Dutch riser system for SWS lubricator. DECOMP MIRU SWS E-Line unit. Gather SWS tools and equipment to rig floor. PJSM with rig crew and SWS E-Line personnel. Discuss procedures for R/U USIT tools. Install SWS lubricator Printed: 8/14/2008 8:58:25 AM • • BP EXPLORATION Operations Summary Report Page 4 of 13 ~ Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 7/13/2008 ___ 02:30 - 05:30 3.00 EVAL P DECOMP with pump in sub, BOPE, and line wiper packoff. Test lubricator to 1000 psi, good test. PU/MU SWS USIT logging tools. 05:30 - 07:30 2.00 EVAL P DECOMP RIH with SWS USIT logging tool to 3000'. Log up from 3000 ft to su ace in cement and corrosion mode. Zero Tool String at Rig Floor. Found TOC in 9-5/8" x 13-3/8" annulus at 2462', same depth as lower FO Cement Stage Collar. Upper FO Cement Stage Collar at 2338'. 07:30 - 09:00 1.50 EVAL P DECOMP R/D E-Line Lubricator, BOPE, Pump-In Sub, & Sheeves. Pull Dutch Riser and UD. 09:00 - 10:00 1.00 EVAL P DECOMP Work on Roughneck and service Draw Works. Sent Log into ANC and review results with Town Engineer. 10:00 - 10:30 0.50 CASE P TIEB1 P/U 9-5/8" 47# HES Model 3L RBP w/ Overshot /Retrieving Tool, Spring Loaded Safety Assy, 4-1/2" IF x 3-1/2" XO Sub, 3-1/2" IF x HT 38 Handling Pup. Total Length = 23.20 ft ; Length to COE = 19.00 ft. 10:30 - 12:00 1.50 CASE P TIEB1 RIH w/ RBP to just above Upper FO Cmt Stage Collar (~ 2338'). Set RBP at 2327 ft center of element. 12:00 - 16:00 4.00 CASE P TIE61 Close Annular and Pressure Test 9-5/8" Casin from 2327 ft tc su ace. ose OA and Pressure Up to 1500 psi on Casing foi 15 mins. Good Pressure Test, flat line PT on casing and zero ressure seen on au eat OA. Continue in Hole. Set RBP at 2350 ft COE and Test to 1500 si for 15 mins -Good Test zero ressure at OA. Set RBP at 2455 ft COE and Test to 1500 si for 15 mins -Good Test zero pressure at OA. Set RBP at 2486 ft COE and Test to 1500 psi Good test for 10 charted minutes. Bring pressure uo to 2500 pressure back to 2500 psi with same results. Pressure bled off from 2600 psi to 1350 psi over 1 hr. 16:00 - 17:00 1.00 CASE P TIE61 POOH with RBP and reset at 2200' COE. Close OA and pressure up to 1500 psi on casing for 10 charted minutes, good test. Bring pressure up to 2500 psi for 10 charted minutes, good test. test to confirm RBP still good. 17:00 - 18:00 1.00 CASE P TIEBi Continue POOH with RBP standing back 4" HT-38 drill pipe in derrick. B/O and L/D HES RBP and running tool. 18:00 - 18:30 0.50 CASE P TIEB1 P/U closing tool for FO cement stanging collar. RIH on 24 stands of 4" HT-38 to 2289'. 18:30 - 20:00 1.50 CASE P TIEB1 Establish parameters of P/U Wt- 72,000 Ibs; S/O Wt- 75,000 lbs. P/U stand 25 and RIH. Tag FO cementer at 2347' and S/O .5000 Ibs. Sta a and S/O 35,000 Ibs on collar. M/U to top drive and S/O 44,000 Ibs on cementer. ump on cemen er. I bumping through. P/U above FO cementer and run back h closing tool. Closing tool worked through after S/O No noticeable movement in FO cementer. Continue X80' without landing on bottom cementer. Notice a e of the weight indicator at 2470' but only took 3000' through. P/U one single joint of drill pipe and RIH to ut a definite tag on lower cementer. P/U and L/D , to upper cementer, tag and S/O 10,000 Ibs on upper cementer. Work back through upper cementer. P/U stands of 4" HT-38 drill pipe from derrick and RIH to 2671'. Printed: 8/14/2008 8:58:25 AM • BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 7/13/2008 18:30 - 20:00 1.50 CASE P TIEB1 Discuss numbers with rig team, decide to POOH. 20:00 - 21:00 1.00 CASE P 21:00 - 22:30 1.50 CASE P 22:30 - 00:00 I 1.501 CASE I P 7/14/2008 100:00 - 00:30 I 0.50 I CASE I P 00:30 - 03:30 3.00 CASE P 03:30 - 04:00 0.50 CASE P 04:00 - 06:00 2.00 CASE P TIEB1 Monitor well and POOH standing back 4" HT-38 drill pipe in derrick. L/D HES FO cementer closing tool. TIEB1 P/U 9-5/8" HES RTTS and RIH on 26 stands of 4" HT-38 drill pipe from derrick to set COE at 2484'. Establish parameters of Up Wt- 76,000 Ibs; Down Wt-77,000 lbs. Set RTTS with 1 right hand turn. S/O 20,000 Ibs on RTTS. TIEB1 R/U to test casing and chart results. Line up to test casing above the RTTS. Walk pressure up to 2500 psi where pressure bleed off 575 si in 5 minutes. Continue walking pressure o 3500 psi. To maintain 3500 psi, rolled mud pump at .23 bpm. Held LLR at .23 bpm/3500 psi for 30 charted minutes. Bled pressure and line up to test 9-5/8" casino below RTTS. Test below RTTS to 3500 psi. Bumped pressure twice, held pressure for 30 charted minutes, pressure bled off 100 psi in 30 minutes. TIEB1 Continue to test below RTTS to 3500 psi for 30 charted TIEB1 TIEB1 TIEB1 06:00 - 06:30 0.50 CASE P TiEB1 06:30 - 09:30 3.00 CASE P TIEB1 09:30 - 13:30 4.00 CASE P TIEB1 13:30 - 14:00 0.50 CASE P TIEBi 14:00 - 15:00 1.00 CASE P TIEB1 15:00 - 15:30 0.50 CASE P TIEB1 15:30 - 17:00 1.50 CASE P TIEB1 17:00 - 17:30 0.50 CASE P TIE61 17:30 - 18:00 0.50 CASE P TIEB1 18:00 - 20:00 2.00 CASE P TIEB1 20:00 - 21:00 1.00 CASE P TIE61 21:00 - 22:00 I 1.00 CASE P TIE61 minutes. Pressure bleed off 100 psi in 30 minutes. Break and B/D circulating lines. Release RTTS and open by-pass valve. Continue RIH with 4" HT-38 drill pipe from derrick to 10,937'. Establish parameters of P/U Wt- 202,000 Ibs, S/O Wt- 140,000 lbs. RIH to 11,032'. P/U 10' and set HES RTTS with 2.5 right hand turns. S/O 25,000 son ace t e S COE at 11,016'. R/U to test casing and chart results. Line up to test casing above the RTTS. Walk pressure up to 3500 psi. To maintain 3500 psi, rolled mud pump at .23 bpm. Held LLR at .23 bpm/3500 psi for 30 charted minutes. Bled pressure and line up to test below RTTS. Attempt to test below RTTS to 3500 ps failedi. Bumped pressure up 3 times, pressure would not hold, pressure bled off 600 psi in 30 charted minutes, LLR at <.1 bpm. Bleed down pressure and release RTTS. Circ Btms Up at 5 bpm and 570 psi. Monitor Hole. B/O Top Drive and Blow Down. POOH and Stand Back 4" Drill Pipe (116 stds). Lav down 9 5/8" Halco RTTS Packer. Service Top Drive. Pick up 8' x 4" Drill Pipe Pup Joint, Running Tool, and 9 5/8" Halco RBP. Trip in with 9 5/8" RBP and 4" Drill Pipe from Derrick. Sit RTTS at 2520 ft center of element, 2515 ft top of plug. POOH with one stand. Pressure Test RTTS to 1500 psi for 15 minutes. PJSM w/ Rig Crew, Vac Truck Drivers, and HES. Pump 20 bbl High Visc Sweep and Displace Well with 170 bbls of 9.8 ppg Nacl Brine at 110 deg F. R/U sand hopper on drill pipe and dumped 2200 Ibs of 20/45 mesh silica sand on top of HES RBP. Pump sand clear of drill pipe at 1 bpm with 60 psi. Shut down pump and allow sand to settle. RIH and tag top of sand at POOH standing back 4" HT-38 drill pipe in derrick. UD HES Printed: 8/14/2008 8:58:25 AM • ~ BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task j Code ~ NPT ~ Phase Description of Operations 7/14/2008 21:00 - 22:00 1.00 CASE P TIE61 running tool. 22:00 - 22:30 0.50 CASE P TIEB1 P/U Baker multi string cutter BHA consisting of 9-5/8" casing cutter, x/o sub, stabilizer, and x/o sub. Duct tape and wire cutting blades in place before RIH. Total length of BHA- 9.94' 22:30 - 23:00 0.50 CASE N DFAL TIEB1 RIH with casing cutting assembly on 6 stands of 4" HT-38 drill pipe when cutters caught casing collar at 516'. Hit drill pipe with top drive. Drill pipe looks damaged. 23:00 - 00:00 1.00 CASE N DFAL TIE61 POOH and L/D stand #6, 2 joints bent. POOH standing back 4" HT-38 drill pipe in derrick to re-tape cutting blades. 7/15/2008 00:00 - 01:00 1.00 CASE P TIE61 RIH with casing cutter on 4" HT-38 drill pipe from derrick to 2400'. 01:00 - 02:00 1.00 CASE N DFAL TIEBi C/O top drive saver sub. 02:00 - 03:00 1.00 CASE P TIEB1 Slip and cut 88' of drill line. 03:00 - 03:30 0.50 CASE P TIEB1 Establish cutting parameters of P/U Wt- 70,000 Ibs; S/O Wt- 75,000 Ibs, Rotate Wt- 75,000 Ibs at 50 rpm with 2000 ft-Ibs free torque. Continue RIH to 2420'. Pump at 4.8 bpm with 500 psi to open cutter. Slow pump down to 3.2 bpm with 230 psi. RIH and locate 9-5/8" casing collar at 2442'. P/U to 2416' and slack off to cutting depth of 2420'. 03:30 - 04:00 0.50 CASE P TIEB1 PJSM with rig crew, CH2MHill, and LRHOS. Discuss casing cutting procedures and procedures for circulating out arctic pac. PT LRHOS circulating lines to 3500 psi. 04:00 - 04:30 0.50 CASE P TIEBi Shut in OA and monitor pressure. Start cutting procedures with 3000 Ibs WOB and 60 rpm with 2500 ft-Ibs torque, pump rate at 4.9 bpm with 560 psi. Pump pressure increased to 630 psi. Increase to 70 rpm with 3500 to 4500 ft-Ibs torque, increased WOB to 5000 Ibs. Continue cutting, increase pump rate to 5.1 bpm with 700 psi. Pressure dropped to 590 psi and 470 psi at 4.9 bpm, lost returns, 120 psi on OA. Finish cutting through casing at 04:26 hrs. Cut acted as if casing was in neutral weight. Cut at 2420'. 04:30 - 06:00 1.50 CASE P TIEB1 Pump 20 bbls of hot diesel with LRHOS at 1.75 bpm with 700 psi. Close annular preventer and open OA. Pump 60 bbls of hot diesel with LRHOS at 1.4 bpm and 600 psi. Pump 40 bbls Safe Surf O Pill and chase with 20 bbls High Visc Sweep at 4.7 bpm with 500 psi. Shut down pumps and shut in well. Allow to diesel and Safe Surf O to soak. 06:00 - 07:30 1.50 CASE TIEB1 Let Diesel and Safe Surf O Pill Soak for 1.5 hrs. 07:30 - 08:30 1.00 CASE P TIEBi Displace 80 bbls of Diesel and 40 Safe-O Pill, 20 bbl High Visc Sweep out of 9-5/8" x 13-3/8" annulus with 160 bbls of 110 deg F 9.8 ppg brine and another 20 bbl High Visc Sweep. Start pumping at 2 bpm and 180 psi worked up to 7 bpm and 900 psi. Initially returns were oil and diesel and after about 10 bbls some dark brown / gray t icTcer maleerial was seen at the flow back tank, lasted for about 30 bbls. The remaining returns were very thin, with light brown color and slight crude cut to it. No thick arctic pack material seen at flow back tank. 08:30 - 13:00 4.50 CASE P TIE61 Let Hot Brine Soak while doing investigation into incident with BOT Multi String Cutter hanging up and Stacking Out DP into Top Drive. Herb Williams, Mike Aivano, Mort Heavirland, Printed: 8/14/2008 8:58:25 AM I~ • • BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours I Task Code NPT Phase Description of Operations 17/15/2008 108:30 - 13:00 I 4.501 CASE I P 13:00 - 14:00 I 1.001 CASE I P 14:00 - 15:30 1.501 CASE P 15:30 - 16:30 1.00 CASE P 16:30 - 17:00 0.501 CASE P 17:00 - 17:30 0.501 CASE P 17:30 - 19:00 I 1.501 CASE I P 19:00 - 00:00 I 5.00 CASE 1 P 7/16/2008 100:00 - 01:30 I 1.50 I CASE I P 01:30 - 02:30 1.00 CASE P 02:30 - 03:30 1.00 CASE P 03:30 - 04:00 I 0.501 CASE I P 04:00 - 05:30 1.501 CASE P TIE61 Andrew Honea, and Ben Bearden. Talked with the driller on tour at time of incident as well as BOT Fishing hand to find out cause and figure out solutions and actions items. Discussed Incident with Rig Crew at 10:15 am Pre Tour Meeting on Incident as well as just after tour change with the crew on the rig to inforce "Staying in the Moment" while on tour. TIEBi Open OA and Pump 170 bbls of 9.8 ppg brine at 100 degrees. Pump Rate = 7 bpm at 1050 psi. No thick Arctic Pack seen at Flow Back Tank. Open up bag and Circ Btms Up at 7 bpm and 950 psi. Monitor well. TIE61 B/O and Blow Down Top Drive. POOH and Stand Back DP. UD Multi String Cutter. Knives on Cutter showed definite wear and looked as if they were fully extended. Did not have to jar knives free. Pull Wear Ring. TIEB1 M/U 9-5/8" ITCO Spear with Pack Off on Joint of DP. M/U Top Drive and RIH and Engage Spear in 9-5/8" Casing. TIEB1 PJSM on pulling casing and laying down casing. Discuss all possible pinch points and hazards during operations, Staying in the Moment, and Stop program if we encounter any other issues we have not addressed at the PJSM. TIEB1 BOLDS and Double Check OA Pressure at Zero. Pull Hanger free at 120,000 lbs. P/U to 150,000 lbs. Seeing Pipe Stretch but not moving freely. Continue to work up to 275,000 Ibs in _15,000 Ibs incraments. At 275,000 Ibs pipe still not pulling freely. Engage pumps and hydraulic pressure. Pipe starting to move up hole with 500 psi of pressure. Having to pull up to 225,000 Ibs to get pipe to move, very jerky and pressure dropped off quickly. Pull pipe up approximately 9 feet to circ btms up. TIEB1 Circ Btms Up at 8 bpm and 150 psi pump pressure with casing hanger -9 foot off seat. Seeing a lar a volume of solids over the shakers. Material looks to be a mix o Arctic ack with a large percentage of Contaminated Cement. After Circ Btms Up, still seeing a good volume of solids. Pump 20 bbl High Visc Sweep and pump at 8.5 bpm and 120 psi. Work Pipe up and down for about 5-6 feet. Up Wt = 155,000 Ibs and Dw Wt = 130,000 Ibs. Sweep brought back some solid cement pieces. TIEB1 POOH with 9-5/8" 47# BTC L-80 Csg. P/U Wt while Pulling Hanger to Floor = 155,000 Ibs. Casiing in generally good condition, Pipe clean and free of arctic pak. TIEB1 Continue to Pull 9 5/8" CSG f/800' to the cut jt. Average break out torque was 44,000 ft-Ibs. 58 full jts, 1-FO Collar jt, cut joint length=20.27, 10 full centralizers, a segments o centralizers. TIEBi Clear and Clean Rig floor. TIEB1 Drain BOP stack and had several pieces of the centralizers hung up in BOPS. Fish them out from surface recovered 6 bow springs. TIEBi Pressure Test Casing to 2,000 psi for 15 minutes. Rock solid TIEBi M/U Dress Off, Scraper Assembly BHA consists of: 9-5/8" dress off shoe, Extension, 9-5/8" Dress off mill, triple Printed: 8/1M2008 8:58:25 AM • • BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours j Task Code NPT Phase Description of Operations 7/16/2008 104:00 - 05:30 I 1.501 CASE I P 05:30 - 06:00 I 0.50 I CASE I P 06:00 - 08:00 I 2.00 I CASE I P 08:00 - 10:00 2.001 CASE P 10:00 - 11:00 1.00 CASE P 11:00 - 12:00 1.00 CASE P 12:00 - 14:00 2.00 CASE P 14:00 - 14:30 0.501 CASE P 14:30 - 16:30 ~ 2.00 ~ CASE ~ P 16:30 - 21:30 5.00 CASE N 21:30 - 00:00 2.50 CASE N 7/17/2008 00:00 - 04:00 4.00 CASE P 04:00 - 04:30 0.50 CASE P 04:30 - 05:00 I 0.501 CASE I P 05:00 - 05:30 0.501 CASE P 05:30 - 07:00 I 1.501 CASE I P 07:00 - 07:30 I 0.501 CEMT I P 07:30 - 08:00 0.50 CEMT P 08:00 - 09:00 1.00 CEMT P TIEB1 connection, XO, 13-3/8" CSG scraper, Bit sub, String Float, Bumper sub, XO, 6 6-1/4" Drill collars, XO. BHA length=220.40'. TIE61 RIH with Dress Off Assy on 4" drill pipe from Derrick. T, ag Ug. on Fill at 2248'. TIEB1 Wash and Ream, Clean Out Fill down to top of Casing Stub at 2420'. Dress Off Tbg Stub from 2420' to 2421'. large Volume of Solids seen coming over shakers. Circ Rate = 11 bpm at 850 psi. TIE61 Circ 20 bbl High Visc Sweep and Pump Out of the Hole at 12 bpm and 970 psi. Still seeing a good amount of solids over shakers. Mix another sweep and pump. Circulate sweep out of hole at 12 bpm . Hole cleaning up. TIE61 B/O and Blow Down Top Drive. POOH and Stand Back DP. TIEB1 Stand Back DC's and UD Dress Off BHA. TIEB1 R/U to Run Casing. Bring Centrilizers, Cementer, and Cement Head to Floor. R/U Torque Turn and Power Tongs. TIEB1 PJSM on Running Casing with Rig Crew, Baker, Doyon Casing, and HES. TIEB1 Run 9-5/8", 47#, L-80 H dril 563 Casin M/U BOT 9-5/8" Casing Patch with pup joint, HES ES Cementer, 9-5/8" 47#, L-80, BTC pin x Hyd 563 box. Have trouble with joint #1 make up. Found that the cross over joint was not the same thread. Cross over joint has TC-II Collar not a Hydril 563. TIEB1 Waiting on the proper XO to be cut at Baker Machine. TIE61 Continue to run 9-5/8", 47#, L-80, HYD 563 Casing to 1,066'. TIE61 Continue to RIH with 9-5/8",47#, L-80, HYD 563 Casing, using torque turn with Jet tube seal guard thread compound, with optimum torque of 13,200 ft-Ibs or torque. Up weight = 140,000#, Down weight = 140,000#. Layed down joint #1 and #35 due to galled pin ends. TIE61 Continue to RIH to to of 9-5/8" CSG slum at 2 42 'had to rotate to the right to get over casing stump. Slacked off to 40,000# down weight on Casing Patch and then P/U to 250,000 # up weight for pull test. TIEBi Slack off to 100,000# up weight and set CSG slips, R/U CMT Head and circulating lines. TIE61 Pressure test Casing String and Baker Patch to 2,000 psi for 30 Charted minutes. Continue to pressure upon CSG string to X900 psi to shift open ES cementer. TIEB1 Circulate well bore with 100 deg 9.8 ppg brine until return fluid was 70-80 deg, pumping at 5 bpm with 270 psi. TIEB1 PJSM with Rig Crew, SLB Cementers, HES, and Vac Truck Drivers. TIEB1 Line Up on SLB and Pressure Test Lines to 4500 psi. Come on line with cement. Pump 163 bbls of 15.8 Class G Cement with Gas Block. Pump cement at 6 bpm and -420 psi. Kick Out Plug with Dowell and Pump 5 bbls. TIEB1 Chase HES Closing Plug with 9.8 ppg Brine from Rig Pits. Catch plug at 75 bbls. Cement at surface with 153 bbls of displacement. Bump plug with 850 psi at 1 pm and 177 bbls Printed: 8/14/2008 8:58:25 AM • • BP EXPLORATION Page 9 of 13 ~ Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 7/17/2008 08:00 - 09:00 1.00 CEMT P TIEB1 of displacement. Estimate a little over 20 bbls of cement back to surface. CIP at 08:35 hrs. HES Closing Plug Latched up and Cementer Closed at 1850 psi. Continued to Pressure Up to 2500 si to insure the Cement r f II I ressure for 15 mins and chart test. Good T 09:00 - 09:30 0.50 CEMT P TIEBi Bleed Down -Plug Holding. Flush OA and Drain Stack. Blow Down and Rlg Down Lines. UD Cement Head. 09:30 - 10:30 1.00 CEMT P TIEB1 Suck Out Casing to Wellhead. N/D BOP's. Split Stack at Casing Spool. Install Emergency Slips and Slack Off Casing fully. 85,000 Ibs set in Slips. 10:30 - 11:30 1.00 CEMT P TIEB1 Rig Up Wach's Cutter. Cut Casing Joint. N/D front valve from new FMC Tbg Spool and install VR Plug and Blanking Flange. 11:30 - 13:00 1.50 CEMT P TIEBi Pull and Lay down casing joint. N/D Tubing Spool. 13:00 - 14:00 1.00 CEMT P TIE61 Install New Pack Off, RILDS. 14:00 - 15:30 1.50 CEMT P TIE61 Nipple Up New FMC Tbg Spool and Test Pack Off to 3800 psi for 30 mins. 15:30 - 17:00 1.50 CEMT P TIEB1 N/U BOPE and Riser. 17:00 - 20:30 3.50 CEMT P TIEB1 Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Chuck Scheve. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1-VBRs on 4" test joint. Test #2- Hydrill, HCR Kill, 1, 12, 13, 14 Test #3- Choke Valves 9,11, Upper IBOP, Blinds, Manual Kill. Test #4-Choke Valves #5, 8, 10, Lower IBOP. Test #5- Choke Valves 4, 6, 7, TIW Valve Test #6- Choke Valves 2, Dart Valve Test #7- Choke Valves #3 Test #8-Choke HCR Test #9- Manual Choke Test #10- VBRswith 4.5" Test Joint. Accumulater Test- 3,000 psi Starting Pressure, 1,900 psi After Actuation, First 200 psi in 19 seconds, Full Pressure in 1 Minute 15 Seconds. 5 Nitrogen Bottles at 2,100 psi. 20:30 - 21:00 0.50 CEMT P TIEBi R/D BOP test equipment and blow down surface lines. 21:00 - 21:30 0.50 CEMT P TIE61 Pull Test plug and install wear ring. 21:30 - 22:30 1.00 CASE P TIEB1 P/U M/U Drill Out Assembly, BHA as follows. 8.5" bit, 2-junk baskets, 9-/58" CSG scraper, bit sub ,bumper sub, oil jar, xo, 6-6 1/4" drill collars, xo. BHA length =226.54' 22:30 - 00:00 1.50 CASE P TIE61 RIH to 1,176' with drill pipe from derrick, wait on cement. 7/18/2008 00:00 - 00:30 0.50 CEMT P TIE61 Continue to RIH from 1,176' to 2,370', Obtain Parameters: up weight=85,000#, down weight=85,000#, rotating weight=85,000#, torque 2,000 ft-Ibs, 6 bpm, 320 psi. 00:30 •01:30 1.00 CEMT P TIEB1 Tagged up on cement stringers at 2,370', Drill down to top of lu at 2 408', pumped a Hi-Vis sweep. 01:30 - 03:00 1.50 CEMT P TIEB1 Continue to drill wiper plug and es cementer, drilled cement out from under es cementer to 2,440' and fell through. Wash and reamed to to of sand at 2,468'. Dry drilled on top o sa~Tn af- 2,468'. Casing Scraper was worked down to 2454 ft. 03:00 - 03:30 0.50 CEMT P TIEB1 Pumped Hi-Vis sweep surface to surface at 11 bpm with 1060 Printed: 8/14/2008 8:58:25 AM ~ • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 7/18/2008 03:00 - 03:30 03:30 - 05:00 5:00 - 05:30 05:30 - 08:00 0.50 1.50 .50 2.50 CEMT CEMT EMT CEMT P P P P TIEB1 TIEB1 IEBi TIE61 psi. On B/U cement and pieces of rubber observed coming over shakers. Monitor wellbore, B/D T/D and POOH from 2,468' to 226' at BHA, stand back drill collars, Clean out junk baskets. Approx 2.5 gal of cement and small alumnium pieces. M/U Rotary Shoe and RCJB to Junk Baskets. Clear and Clean rig floor. Pressure test casin to 3500 si charted. Showin small decline in pressure, -100 psi in one hour. 08:00 - 08:30 0.50 CLEAN P CLEAN wi to 468' 08:30 - 09:00 0.50 CLEAN P CLEAN P/U Wt = 85,000 Ibs S/O Wt = 85,000 Rot Wt = 85,000 lbs. 2000 ft Ibs torque of free torque. 6 bpm at 320 psi. Drop ball and Rotate and Wash from 2468' to 2477'. Junk from 2^ 468 to 2474', required up to 7000 ft -Ibs torque and up to 7000 WOB to get through. 09:00 - 10:00 1.00 CLEAN P CLEAN Circ 20 bbl high visc sweep and chase out of hole at 6 bpm and 2450 psi. Contaminated cement and sand seen at shakers. Monitor Well, B/O Top Drive and Blow Down. 10:00 - 11:00 1.00 CLEAN P CLEAN POOH and Stand Back DP 11:00 - 11:30 0.50 CLEAN P CLEAN Stand Back DC's. B/O RCJB /Boot Baskets and Clean Out. Recovered 10 # of broken up steel bow spring arms from Reverse Basket. Boot Baskets contained a few small pieces and sand. 11:30 - 13:00 1.50 CLEAN P CLEAN PT Casing again to confirm results. PT against blind rams with sensor on IA, all other possible paths double blocked. ,~T, results similar as last time. 13:00 - 14:00 1.00 CLEAN P CLEAN RIH with RCJB again on from Derrick. 14:00 - 15:30 1.50 CLEAN P CLEAN P/U Wt = 85,000 Ibs S/O Wt = 85,000 Rot Wt = 85,000 Ibs. 2000 ft Ibs torque of free torque. 6 bpm at 320 psi. Drop ball and Rotate and Wash from 2477' to 2493'. Junk seen at a few spots w i e c eaning ou , regwre up o 000 ft -Ibs torque to get through. Pumping at 6 bpm and 2550 psi. Pump 20 bbl High Visc Sweep and Chase with Seawater from pits at 6 bpm 2700 psi. 15:30 - 16:30 1.00 CLEAN P CLEAN POOH with RCJB, Stand back DP. 16:30 - 18:30 2.00 CLEAN P CLEAN Stand Back DC's, B/O RCJB. Found more Bow Spring Centrilizers, 3.5 Ibs of metal found in basket. M/U RCJB again and DC's. RIH w/RCJB for 3rd run. Still worried about Bow Spring Centrilizer Pieces. 18:30 - 19:00 0.50 CLEAN P CLEAN ump i- is sweep, and chase out of well bore at 7 bpm w/2,630 psi . 19:00 - 19:30 0.50 CLEAN P CLEAN Pump dry job and monitor well bore, B/D Top Drive. 19:30 - 20:00 0.50 CLEAN P CLEAN POOH from 2,505 to 230'. 20:00 - 20:30 0.50 CLEAN P CLEAN Stand back drill collars and clean out RCJB and junk baskets still recovering pieces of Bow Spring Centralizers 4 pieces on this run. 20:30 - 21:00 0.50 CLEAN P CLEAN Change out Shoe and RCJB added Extension for BHA #9. 21:00 - 22:30 1.50 CLEAN P CLEAN Continue to RIH from 231' to 2,417'. Drop RCJB ball and washed down with 10bbls of fluid, washed down to 2,509'. 22:30 - 23:00 0.50 CLEAN P CLEAN Pump 20 bbl Hi-Vis sweep at 8 bpm wit 2,100 psi. 23:00 - 23:30 0.50 CLEAN P CLEAN Pump Dry Job and monitor wellbore, B/D T/D. 23:30 - 00:00 0.50 CLEAN P CLEAN POOH from 2,509' to surface. 7/19/2008 00:00 - 00:30 0.50 CLEAN P CLEAN Stand back Drill Collars and B/O reverse circulating basket, NO Printed: 8/1M2008 8:58:25 AM • BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To j Hours Task j Code NPT Phase Description of Operations 7/19/2008 00:00 - 00:30 0.50 CLEAN P 00:30 - 01:00 0.50 CLEAN P 01:00 - 01:30 0.50 CLEAN P 01:30 - 02:00 0.50 ~ CLEAN P 02:00 - 02:30 0.50 CLEAN P 02:30 - 03:30 1.00 CLEAN P 03:30 - 04:00 0.50 CLEAN I P 04:00 - 04:30 0.50 CLEAN P 04:30 - 05:00 0.50 CLEAN P 05:00 - 06:30 1.50 CLEAN P 06:30 - 10:00 I 3.50 I CLEAN I P 10:00 - 11:00 I 1.001 CLEAN I P 11:00 - 12:00 1.00 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30 - 13:00 I 0.501 CLEAN I P 13:00 - 14:30 ~ 1.50 ~ CLEAN ~ P 14:30 - 17:30 I 3.00 I CLEAN I P 17:30 - 19:00 I 1.50 I CLEAN I P 19:00 - 19:30 I 0.50 I CLEAN I P 19:30 - 23:00 3.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P CLEAN recove on this run. UD RCJB assembly. CLEAN Clear and Clean rig floor. CLEAN M/U RBP Retrieval tool and RIH to 2,488'. Up weight=75,000#, down weight=75,000# CLEAN Wash down to top of RBP ~ 7 bpm with 300 psi. En a ed RBP at 2,515' with 15,000# down weight, P/U on RBP with 10,000# up weight, Then slacked off with 15,000# down weight. CLEAN Pump 20 bbl Hi-Vis Sweep at 11 bpm and 1,180 psi CLEAN Release RBP and CBU at 7 bpm with 300 psi. Monitor well, B/D T/D. CLEAN POOH from 2,515' to BHA. CLEAN UD RBP and Running tool, RBP in good condition and had rubber intact, One piece of metal junk on the top of RBP. Clear and Clean rig floor. CLEAN RIH with 2 stands of Drill Collar and Came out and UD Same. CLEAN M/U GS S ear assembly BHA consists of: Cut lip guide, xo, extension, G spear, xo, shear pin guide, 2 joints of 2-7/8" pac dp, xo, pump out sub. BHA = 76.14'. CLEAN RIH t/11,086' Breaking circulation every 30 stands, Obtain parameters up weight= 202,000#, down weight=140,000#, rotating weight=160,000# at 10 rpm, with 4,000 ft-Ibs of torque, with 2 bpm and 750 psi. CLEAN Wash dodwn and to to of tubin stub at 11,060', P/U rotate through, stop rotation and continue to RIH and tag and shear off with 5,000# down weight, continue to wash down and tag 'unk catcher at 11,108' ush down with 2-4,000# down weight to 11 114' with 5,000# down to confirm bottom. P/U to string weight. CLEAN Pump 20 bbl Hi-Vis sweep to bit at 5 bpm and 2070 psi. CLEAN Latch onto funk basket with GS spear and attempt to pull funk increments each time for a total of 90,000# over string weight, pump on junk basket with spear under tension at 3 bpm with 1,700 psi working sting from 220,000# up to 290,000#, CLEAN ,~ielease GS spear and B/O single drop 1-7/8" ball to open up circ sub, pump ball down to seat at 4 bpm with 2,000 psi, verify circ sub open by pump pressure decrease of 600 psi. CLEAN Circulate Hi-Vis sweep out of wellbore at 10 bpm with 2,080 psi. CLEAN Monitor wellbore, pump dry job, B/D top drive ,POOH from 11,000' to 76'. CLEAN B/O GS spear, one dog on spear bent in and some junk on wedged in underneath. Re-pin shear guide, rebuild pump out sub & 4-3/4"jars and DC's. CLEAN M/U new GS spear Assembly (BHA #11~ with Cut Lip Guide, Bushing, extension, GS Spear, XO Sub, Shear Pin Guide, 2 joints of PAC DP, XO Sub, Bumper Sub, Jars ,Pump Out Sub, XO Sub, and 3 4-3/4" DC's. Total Length = 187.91 ft CLEAN RIH with GS Spear Assembly on DP to 11,107' CLEAN M/U Top Drive and Establish Parameters. P/U Wt = 206,000 Ibs, S/O Wt = 136,000 Ibs Pump Rate = 2 bpm at 500 psi. Continue in the hole and tag Tbg Stub at 11060 ft. P/U -5 ft and Rotate Cut Lit over Stub. Shear Guide Free with 5K Ibs Printed: 8/14/2008 8:58:25 AM • • BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date from - To Hours .Task Code NPT Phase Description of Operations 17/19/2008 123:00 - 00:00 I 1.00 CLEAN I P 17/20/2008 00:00 - 00:30 0.501 CLEAN P 00:30 - 01:00 I 0.50 I CLEAN I P 01:00 - 04:30 3.50 CLEAN P 04:30 - 05:30 1.00 CLEAN P 05:30 - 06:00 0.50 CLEAN P 06:00 - 09:00 3.00 CLEAN P 09:00 - 10:00 1.00 CLEAN P 10:00 - 12:30 2.50 CLEAN P 12:30 - 13:00 0.50 CLEAN P 13:00 - 14:00 1.00 CLEAN P 14:00 - 21:30 7.50 CLEAN P 21:30 - 22:30 1.00 CLEAN P 22:30 - 23:00 0.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P 7/21 /2008 00:00 - 00:30 0.50 00:30 - 13:00 12.50 13:00 - 13:30 I 0.50 13:30 - 14:00 I 0.50 14:00 - 15:00 I 1.00 CLEAN and Continue in hole. B/O Top Drive and Continue in hole. Tag Up on Fish and set Down -8K Ibs at 11,114'. P/U to 260K Ibs (54K Ibs Over). CLEAN Continue to Work Pipe and Jar on Junk Catcher. Re uired 16 Jar licks at 50K Ibs over to work 'unk catcher free. Pick Up over ten feet with Junk catcher to confirm free and then set back down on bottom. B/O Top Drive and Drop Ball to Open Circ Sub. CLEAN Pump at 1.5 bpm and 300 psi. Circ Sub Opened with 2230 psi. L/D Single and POOH with 5 stands. B/O Top Drive and Blow Down. CLEAN POOH and Stand Back DP. Stand Back DC's. CLEAN B/O and L/D Junk Catcher and Hydrualic GS. Rebuild Shear Pin Guide. CLEAN M/U 2-7/8" Mule Shoe BHA. CLEAN RIH to 11,100' Obtain parameters: up weight=215,000#, down weight=140,000#, rotating weight=167,000#, pumping at 2 bpm with 300 psi. CLEAN Wash down at 2 bpm with 300 psi to 11,125'. CLEAN R/U to reverse circulate. Pump 20 bbl Hi-Vis sweep at 10 bpm with 2500 psi. Packed off after 50 bbls pumped away. Bleed off pressure attempt to reverse circulate at 3,200 psi at 1 bpm, lined up to pump long way and pumped 20 bbl Hi-Vis sweep at 10 bpm with 2,500 psi. CLEAN Monitor wellbore, pump dry job and B/D T/D. CLEAN PJSM Slip and cut drilling line, 15 wraps for 101', inspect brakes and lubricate shifting ring.grease equilizer bar for brakes. CLEAN POOH L/D DP from 11,100'to 186'. CLEAN Lay down drill collars, and 2 jts of PAC drill pipe. CLEAN Clear and clean rig floor. CLEAN Pull wear ring, R/D elevators and short bails, R/U to run 4.5",12.6#, 13cr-80, vam top tubing, R/U torque turn equipment. RUNCMP Continue to R/U 4.5" completion equipment. RUNCMP P/U M/U Unique Overshot 9-5/8" x 4-1/2", XN- Nipple with RHC, 1-full jt Tubing, X-Nipple, Baker S-3 Packer, X-Nipple, two 4-1/2" x 1-1/2" GLM's and 256 jts of 4-1/2", 12.6#, 13cr80, Vam Top Tubing. Using Compensator, orque um ongs and Jet Lube ea uard on all connections, average M/U Torque is 4,440 ft-Ibs . Layed down jt #18 and change out with joint from outside.due to poor make up, found threads gualled. P/U Wt = 162,000 Ibs; S/O Wt = 118,000 Ibs. RUNCMP M/U Joint #257 and #258. See first set of shear pins go at 5 ft in on Jt #258 (11072.7 ft) with 8,000 Ibs, second set of shear pins go at 13 ft in on Jt #258 (11080.7 ft) with 8,000 Ibs. No-Go on Tbg Stub at 16 ft in on Jt #258, Stack 15,000 Ibs to confirm No-Go. RUNCMP POOH and L/D Joints #258, #257,& #256. P/U and M/U 4-1/2", 12.6#, 13Cr, VamTop Space Out Pups; 3.80 ft, 7.82 ft, 9.84 ft, 9.87 ft. P/U and M/U Jt #256. RUNCMP P/U and M/U 4-1/2" TCII Landing Joint with Circ Head to FMC 13-5/8" x 4-1/2" Tbg Hanger. M/U Tbg Hanger to Tbg String Printed: 8/14/2008 8:58:25 AM • • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 05-08 Common Well Name: 05-08 Spud Date: 6/8/1977 Event Name: WORKOVER Start: 7/8/2008 End: 7/22/2008 Contractor Name: DOYON Rig Release: 12/24/1997 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code ; NPT ' Phase ~ Description of Operations i 7/21/2008 14:00 - 15:00 1.00 BUNCO RUNCMP and Torque Turn. Drain Stack and BOLDS. Lower Tbg and Land at 20.49 ft in Tbg Spool. FMC Wellhead Hand confirm placement on Tbg Hanger and RILDS. 15:00 - 15:30 0.50 BUNCO RUNCMP Rig Up Hoses to reverse circ in SW and SW with Corrosion Inhibitor. R/D Tbg Handling Equipment. 15:30 - 16:00 0.50 BUNCO RUNCMP PJSM w/ Vac Truck Drivers and Rig Crew. 16:00 - 21:00 5.00 BUNCO RUNCMP PT hoses 3700 psi. Circulate in 170 bbls of 120 deg F Sw followed by 590 bbls of 120 deg F Sw with Corrosion Inhibitor. Reverse in Sw at 3 bpm and 480 psi. 21:00 - 22:30 1.50 BUNCO RUNCMP Dro ball and rod Pressure u to 3 500 si on tubin to set acker and held ressure for 30 Charted minutes Bled down tubin pressure to 1,500 si and Pressured up to 3,500 psi on the Annulus and held pressure for 30 charted minutes. le down on the tubing pressure and sheared the DCR valve at 3,000 psi differential. Confirmed DCR was completely open by pumping down the tubing and then lining up on the annulus and pumping in both directions at 3 bpm with 200 psi. 22:30 - 23:30 1.00 BUNCO RUNCMP L/D Landing joint, set TWC, test TWC to 3,500 psi from above and 1,000 si from belo and held both tests for 10 charted minutes. 23:30 - 00:00 0.50 BUNCO RUNCMP B/D surface lines and drain stack. 7/22/2008 00:00 - 01:00 1.00 BUNCO RUNCMP N/D BOPE and Stand back on pedistal. 01:00 - 02:00 1.00 BUNCO RUNCMP N/U Adapter Flange 02:00 - 03:00 1.00 BUNCO RUNCMP R/U and pressure test adapter flange to 5,000 psi for 30 minutes, R/D pressure testing equipment. 03:00 - 04:00 1.00 BUNCO RUNCMP N/U Production Tree. 04:00 - 05:30 1.50 BUNCO RUNCMP Pressure test Production tree to 5,000 psi for 30 minutes 05:30 - 06:00 0.50 BUNCO RUNCMP R/U DSM Lubricator and Pressure test to 500 psi, Pull TWC and R/D DSM. 06:00 - 07:00 1.00 BUNCO RUNCMP R/U Little Red and pressure test lines to 3,500 psi. 07:00 - 09:00 2.00 BUNCO RUNCMP Lil Red reverse circulate 140-Bbls diesel freeze protect, to cover 2,038' IA x Tubing. R/D Lil Red. Let U-tube for 1-hour. 09:00 - 10:00 1.00 WHSUR P RUNCMP DSM P/U and install BPV. R/D DSM. 10:00 - 10:30 0.50 WHSUR P RUNCMP Pressure test the BPV to 1,000-psi, charted. 10:30 - 11:00 0.50 WHSUR P RUNCMP R/D and blowdown circulating lines. Remove eMra OA and IA valves. Secure the tree and cellar and Vac-out the slop tank. Release rig at 1100-hours. 11:00 - 14:00 3.00 RIGD P POST RDMO and prepare to L/D derrick. UD Derrick, remove BOP stack from cellar, install front and rear Booster wheels. 14:00 - 19:00 5.00 RIGD P POST Move rig off pad and across DS 5 access road to Spine Road. Printed: 8/14/2008 8:58:25 AM 05-08, Post Rig Workover Well Events Date Summary 7/27/2008 T/I/O=Vac/0/0. Pull 4" CIW H BPV thru tree. Post rig. 7/30/2008 WELL SHUT IN ON ARRIVAL. PULLED BALL & ROD ~ 11,022' SLM. PULLED DCK GLV FROM STA #2 C~ 3,572' MD. PULLED DGLV FROM STA# 1 C~ 6,920' MD. SET GENERIC GASLIFT DESIGN IN STA# 2 & # 1. CURRENTLY POOH W/ 4-1/2" RHC PLUG BODY FROM XN NIP C~ 11034' MD. 7/31/2008 PULLED 4-1/2" RHC PLUG BODY FROM XN-NIPPLE AT 11034' MD. MADE ONE ATTEMPT TO EQUALIZE WRP AT 11,120' MD. UNABLE TO PASS 9-5/8" x 4 -1/2" UNIQUE OVERSHOT AT 11,057' SLM (11065' MD). RAN 3.70" LIB TO 11,057' SLM.(LIB SHOWS IMPRESSION OF WHAT APPEARS TO BE TUBING STUB). RAN 4-1/2" DECENTRALIZER,3.70"LIB TO 11096' SLM.(WORK THROUGH TIGHT SPOT AT 11054' SLM). TAG WRP AT 11,110' SLM. (LIB SHOW SAME IMPRESSION AS BEFORE). MADE ONE ATTEMPT TO EQUALIZE WRP W/ 4-1/2" WRP EO-SLEEVE AT 11,110' SLM. (UNABLE TO EQUALIZE) CURRENTLY RUNNING KNUCKLE, DECENTRALIZER, 3.70" CENT, 3.5" LIB TO 11,110' SLM. 8/1/2008 RAN 4-1/2"DECENTRALIZER,3.70"CENT,3.5" LIB TO WRP AT 11,120' MD (LIB SHOWS IMPRESSION OF FILL). MADE ONE RUN WITH 10' x 3" P-BAILER TO WRP AT 11,120' MD (RECOVERED APPROX. 6 CUPS OF SLUGGITS) RAN KNUCKLE, 5' x 3" PUMP BAILER W/WRP EO. FLAPPER BOTTOM TO WRP AT 11,120' MD. BAILED 20 MIN WRP APPEARS TO HAVE EQUALIZED, BAILER STUCK ON WRP. UNABLE TO JAR OFF. DROPPED GO-DEVIL CUTTER BAR (1.75" FN 5' OAL) RECOVERED ALL WIRE. FISHED GO-DEVIL CUTTER BAR FROM 11,093' SLM. RAN KNUCKLE, ,4-1/2" DECENT.3.70" CENT.3.50" LIB TO FISH AT 11,096' SLM. (LIB SHOWS IMPRESSION OF CLEAN ROPE SOCKET). CURRENTLY ATTEMPTING TO FISH TOOL STRING C~3 11096' SLM. 8/2/2008 MADE SEVERAL ATTEMPTS TO RETRIEVE TOOL STRING ~ 11094' SLM, COULD NOT PULL TOOL STRING, (TOOL STRING LEFT IN WELL, OAL 31' LARGEST OD= 3.70" ON WRP EO FLAPPER BOTTOM). RDMO, LEFT WELL SHUT IN AND TURNED OVER TO DSO. 8/11/2008 RAN 3.6" BELL GUIDE AND 2-1/2" JDC TO FISH AT 11080' BLM (2 hrs jar time). PLANT OVERSHOT AND 4-1/2" G FISH NECK ON FISH AT 11080' BLM. 8/12/2008 MAKE MULTIPLE RUNS WITH BRAIDED LINE AND JAR ON FISH AT 11080' 8LM (12hrs total jar time). 8/14/2008 RAN 4-1/2" GS AND JARRED ON FISH AT 11080' BLM (3.5 hrs jar time). HAD SLIGHT DIFFICULTY GETTING PAST STUB AT 11060' BLM. 8/15/2008 RAN 4-1/2" GS AND ATTEMPTED TO PULL FISH AT 11080' BLM W/ OUT SUCCESS (13.5hrs jar time). LEFT WELL S/I, TURNED WELL OVER TO DSO. NOTE: FISH STILL IN HOLE AT 11080' BLM. TOOL DRAWINGS ATTACHED TO WING VLV. Page 1 of 1 'ELLHEAD = ., FMC 5M O ~ O CTUATOR y CMi OTIS ~ ~ 3. ELEV = 64' ~`~ _ DRLG DRAFT DP = ax Angle = 52 @ 6550' 3tum MD = 11300' 3tum ND = 8800' SS 9-5/8" Csg Patch wl new Csg to surface I 2424' I 13-3/8" CSG, 72#, MN-80, ID = 12.347" ~~ 2733' Minimum ID = 3.725" @11034' 4-1 /2" XN Nipple 4-1'2" TBG. 12.6#, 13cr..0152 bpf. ID = 3.958" 11065' FISH - SL TOOL STRING (08!03/08) 11094' -1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 1116T PERFORATION SUMMARY REF LOG: BHCS ON 06/26/77 ANGLE AT TOP PERF: 51 @ 11351' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE -- -- 11351 - 11385 S 11 /16/77 -- -- 11400 - 11420 S 11/16/77 -- -- 11440 - 11450 S 11/16/77 4" 4 11450 - 11460 S 11!17!88 -- -- 11482 - 11516 S 11 /06/77 4" 4 11516 - 11532 S 05/04/00 3-3/8" 6 11528 - 11534 C 05/22/03 3 3/8" 4 11568 - 11590 S 11 /26/87 4" 4 11589 - 11630 S 11/17/88 3 3/8" 4 11610 - 11640 C 05/13/00 SA~ NOTES: *""CHROME TBG*** 2124' ~~ 4-1 /2" HES X NIP. ID = 3.813" I GAS LIFT MANDRELS ST MD ND DEV TYPE Valve LATCH PORT DA' 2 3572 3554 20 MMG DOME RK 16 07/3C 1 6920 6038 51 MMG SO RK 20 07/3C 10927' ~ 9-5/8" X 4-1/2" BAKER S-3 PKR 10896' 4-1/2" HES X NIP, ID = 3.813" 10962' 4-1/2" HES X NIP, ID = 3.813" 11034' 4-1/2" HES XN NIP, ID = 3.725" 11065' 9-5/8" x 4-1/2" Unique Overshot 11109' 9-5/8" X 4-1/2" BAKER S-3 PKR 11120' 4-1/2" WRP PLUG (2/26/06) 11143' 4-1/2" HES X NIP, ID = 3.813" 11I 167' I-j4-1/2" TUBING TAIL 11156' ELMD TT LOG NOT AVAILABLE PBTD 11662' 9-5/8" CSG, 47#, MN-80, ID = 8.681" 11837' TD 11860' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff D7/04/77 ORIGINAL COMPLETION WELL: 05-08 12/24/97 LAST WORKOVER PERMff No: 1770240 D7/22/08 D16 RWO API No: 50-029-20248-00 D8/05/08 JCM/PJC FISH/GLV C/O (07/30!08) SEC 6, T10N, R15E, 4192.52' FEL & 1743.92' F~ BP Exploration (Alaska) 07/16/08 a ~~r~~1~G1-~~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~rs~~~~ ~! U~ .G G L U ~ D NO.4783 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n~fn RI Cnlnr CO YYCII 01-t4 Z-05 Z-24 uVV n 12017504 12017503 12017503 ~ ~ ~ PRODUCTION PROFILE PRODUCTION PROFILE , . PRODUCTION PROFILE _ - 07/14/08 07/11/08 07/12/08 1 1 1 1 1 05-08 N-12 N-12 11999026 12057614 12057614 USIT CEMENT EVALUATION j - a USIT CEMENT & CORROSION _. (p USIT COMPOSITE '~ - L ~ 07/13/08 06/28/08 06/28/08 1 1 1 1 1 1 WB-04 12021165 MEM SBHPS ~ - 06/12/08 1 1 L3-OS 11982436 RST ~ -~ 06/01/08 1 1 J-17C 12066523 MCNL ~ 05/23/08 1 1 PLtASt AI:RNUWLCUUt rSCl.CIr'1 dY OlulYllv\Y /11\v nclvnl~maa v.~~ vv, ~.-..... .... BP Exploration (Alaska) Inc. Petrotechnicai Data Center LR2-1 - 900 E. Benson Blvd. i:_, _, ,, Anchorage, Alaska 99508 Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Suite ' 0 Anchorage, AK 9 3-28 ATTN: Beth Received by: --- • • ~~~~ r ~ SARAH PAL/N, GOVERNOR COI~TSER~'j'Ip ~-75I~ 333 W. 7th AVENUE, SUITE 100 -7 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 t ~} ,~ ~ ~~ 4 t~ Re: Prudhoe Bay FYeld, Prudhoe Bay Oil Pool, PBU 05-08 Sundry Number: 308-231 ~~1 ,~UL $ Ztl~B Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd .day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair s DATED this I day of July, 2008 Encl. ,~~ ~~~~ a ,~~, ~r/L ~, S' aT ~j- ~1 `,~~ STATE OF ALASKA ~°~~ ~~,(~~ ~' ALA~OIL AND GAS CONSERVATION COMMT,lr'ION /`~~~'3~~~( ~ '~ ~O APPLICATION FOR SUNDRY APPROVAL .~....F ~ 4. ,,~ ,~• 20 AAC 25.280 A _ _ , 1. T e of Re uest: ""' '~' "~'~" YP q ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®Alter Casing ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -® Development ^ Exploratory 177-024 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20248-00-00' 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 05-08 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028329 - 64', Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11860' - 9227 - 11662' 9097 11120' - None Casin Len th Size MD TVD Burst Colla se Structural Conductor 109' 20" 109' 109' 1530 520 Surface 2733' 13-3/8" 2733' 2733' 5380 2670 Intermediate Production 11837' 9-5/8" 11837' 9212' 6870 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 11528' - 11640' 9010' - 9083' 4-1/2", 12.6# L-80 11167' Packers and SSSV Type: 9-5/8" x 4-1l2" Baker'S-5' packer Packers and SSSV MD (ft): 11109' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: July 4, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verba! Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5471 Printed Nam avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature ~ Phone 564-5743 Date ~ Z & ~,,~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval Notify Commission so that a representative may witness ^ Plug Integrity ~.80P Test ^ Mechanical Integrity Test ^ Location Clearance j ~-S ,,, I Other: ~~ ~~ ~ ~ \ ~ ~ ~ 'a'C~ Subsequent Form Required: "j~s~"'~ APPROVED BY ~ j f X ~ ` v A roved COMMISSIONER THE COMMISSION Date , Form 10-403 I~vised~06/24Q6 n' /~ Submit In Duplicate • by cr,,~,y 05-08 Expense Rig Workover • Scope of Work: Pull 4-~h" completion, cut and pull 9-5/" casing, run and cement 9 5/8" casing to surface, run 4-~h" 13Cr-80 tubing with Baker S-3 packer set at 10,950' MD. MASP: 2400 psi Well Type: Ivishak Producer Estimated Start Date: July 4, 2008 Production Engineer: James Dean Intervention Engineer: Howard West Pre-rip prep work: S 1 Drift for 4.5" jet cutter. Dump bail 10' of sluggits on WRP. Set 4-1/2" junk catcher on slu its/V1IRP.DONE 06!22/08 E 2 Power Jet cut 4-'/z" L-80 tubing at 11,075' MD, in the top third of the 1S full joint above the Baker acker. Reference tubin tall dated 12/14/97. DONE 06/24/08 F 3 Circulate well with seawater and diesel thru the cut. CMIT TxIAxOA to 2000 psi DONE 06/25/08 W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU Doyon 16. ND tree. NU and test BOPE pipe rams to 3500 psi. Test annular preventer to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Retrieve 4-1h" tubing string down to the tubing cut. 3. Run USIT log to determine top of cement in the 9-5/8" casing. 4. Set and test 9-5/a" RBP approximately 100' below estimated TOC. Note: The VBRs in the BOPs will NOT be changed over to 9 5/" pipe rams as the barriers to the reservoir will be the tested 9-5/8" RBP and WRP in the 4 ~h" tubing. 5. Cut and pull 9 5/" above TOC. 6. Run and fully cement 9-s/" casing to surface. 7. Drillout 9 5/8" shoe track. 8. Retrieve 9-5/8" RBP. 9. Run 4-~/z" 13Cr-80 tubing with Baker S-3 packer set at 10,950' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. = CNV 4-1. WELLHEAD = FMC SM ACTUATOR = CNV OTIS KB. ELEV = 64' BF. ELEV = ? KOP = ? Max Angle = 52 @ 6550' Datum MD = 11300' Datum TV D = 8800' SS 13-3/8" CSG, 72#, MN-80, ID = 12.347" 2733' os-os I I 14-1/2" CAMCO BAL-O SSSV NIP, ID=3.812 GAS LIFT MANDRELS Minimum ID = 3.812" @ 2219' 4-1 /2" CAMCO BAL-O SSSV NIPPLE 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 11 1116T PERFORATION SUMMARY REF LOG: BHCS ON 06/26/77 ANGLEATTOPPERF: 51 @ 11351' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE -- -- 11351 - 11385 S 11/16/77 -- -- 11400 - 11420 S 11/16/77 -- -- 11440 - 11450 S 11/16/77 4" 4 11450 - 11460 S 11/17/88 -- -- 11482 - 11516 S 11/06/77 4" 4 11516 - 11532 S 05/04/00 3-3/8" 6 11528 - 11534 C 05/22/03 3 3/8" 4 11568 - 11590 S 11 /26/87 4" 4 11589 - 11630 S 11/17/88 3 3/8" 4 11610 - 11640 C 05/13/00 PBTD 11662' 9-5/8" CSG, 47#, MN-80, ID = 8.681" 11837' 11860' S NOTES: ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4031 3975 28 MMG DMY RK 0 09/16/05 2 7744 6578 49 MMG DMY RK 0 09/16/05 3 10228 8183 49 MMG DMY RK 0 09/16/05 11109, 1~ 9-5/8" X 4-1/2" BAKER S-5 PKR 11120' 4-1/2" WRP PLUG (2/26/06) 11143' 4-1/2" HES X NIP, ID = 3.813" 11~ 16T I-14-1/2" TUBII~ TAIL I 11156' ELMD TT LOG NOT AVAILABLE DATE REV BY COMMENTS DATE REV BY COMMENTS 07/04/77 ORIGINAL COMPLETION 02/26/06 RCT/PJC SET WRP PLUG @ 11120' 12/24/97 LAST WORKOVER 05/30/06 DTM WELLHEAD CORRECTION 05/22/03 BJM/TLH ADD PERF 06/22/06 COM/PJC WELLHEAD CORRECTION 08/17/03 CMO/TLP PERF ANGLE CORRECTION 09/22/05 KSB/TLH GLV C/O 02/26/06 RCT/PJC PULL PX PLUG @ 11143' PRUDHOE BAY UNff WELL: 05-08 PERMff No: 1770240 API No: 50-029-20248-00 SEC 6, T10N, R15E, 4192.52' FEL & 1743.92' FNL BP Exploration (Alaska) TREE=. C;NV4-1/16.. / WELLHEAD = FMC 5M 8 ~ 05 O ACTUATOR = CM/ OTIS R,o l ti KB. ELEV = 64' p e on BF. ELEV = ? KOP= _? Max Angle = 52 @ 6550' Datum MD = 11300' Datum TVD = 8800' SS 13-3/8" CSG, 72#, MN-80, ID = 12.347" 2733' Minimum ID = 3.812" @ 2219' 4-1/2" CAMCO BAL-O SSSV NIPPLE 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 11167' PERFORATION SUMMARY REF LOG: BRCS ON 06/26/77 ANGLE AT TOP PERF: 51 @ 11351' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE -- -- 11351 - 11385 S 11/16/77 -- -- 11400 - 11420 S 11/16!77 -- -- 11440 - 11450 S 11/16/77 4" 4 11450 - 11460 S 11/17/88 -- -- 11482 - 11516 S 11/06/77 4" 4 11516 - 11532 S 05/04/00 3-318" 6 11528 - 11534 C 05/22/03 3 3/8" 4 11568 - 11590 S 11/26/87 4" 4 11589 - 11630 S 11/17/88 3 3/8" 4 11610 - 11640 C 05/13/00 PBTD 9-5/8" CSG, 47#, MN-80, ID = 8.681" ( 11662' I I 11837' I S NOTES: 2100' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE LATCH PORT DATE 1 TBD 1 1/2" MMG 2 TBD 1 1/2" MMG 3 TBD 1 1/2" MMG 4 TBD 1 1/2" MMG 4-1/2" HES X NIP, ID = 3.813" 9-5/8" X 4-1/2" BAKER S-3 PKR 4-1/2" HES X NIP, ID = 3.813" I~ 4-1 /2" HES XN NIP, ID = 3.725" 11109' 9-5/8" X 4-1/2" BAKER S-3 PKR 11120' 4-1/2" WRPPLUG (2/26/06) 11143' 4-1/2" HES X NIP, ID = 3.813" 11167' 4-1/2" TUBING TAIL 11156' ELMDTTLOGNOTAVAILABLE DATE REV BY COMMENTS DATE REV BY COMMEMS 07/04/77 OWGINAL COMPLETION 02/26/06 RCT/PJC SETWRPPLUG @ 11120' 12/24/97 LAST WORKOVER 05/30/06 DTM WELLHEADCORR[B/TION 05/22/03 BJM/TLH ADD PERF 06/22/06 COIWPJC WELLHEAD CORRECTION 08/17/03 CMO/TLP PERF ANGLE CORRECTION 09/22/05 KSB/TLH GLV GO 02/26/06 RCT/PJC PULL PX PLUG @ 11143' PRUDHOE BAY UNIT WELL: 05-08 PERMfT No: 1770240 API No: 50-029-20248-00 SC-C 6, T10N, R15E, 4192.52' FEL & 1743.92' FNL BP 6rploration (Alaska) . . WELL LOG TRANSMITTAL "'!1' ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage. Alaska 99501 RE: Cased Hole/Open Hole/Mechanical logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) EDE Disk 2) 3) 4) 5) 6) 7) o.S. 05 - 08 leak Detection - WLD 15-Dec~6 sCANNED APR 0 3 2007 197 -of}'-I ¡j F-/6dÛ Signed: I / (! j~ t/~·- (ì 1/1 (~jtl' ,A ~ /11 o.{( (/1 (¡ P (,1 Date : Print Name: 'c~r~1f~~ìcn PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYI.OG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _Copy _00 ]DSANC-2OxxIZ _ W ord\Dislribution\TransmittaJ _ Sheets\Transmit_ OrigínaI.doc · STATE OF ALASKA . ALAWA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development M 16. Well Status after proposed work: Oil M! Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .. 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 64 KB 8. Property Designation: ADL-028329 11. Present Well Condition Summary: Total Depth measured 11860 . true vertical 9227.05 Effective Depth measured 11662 true vertical 9097.15 Casing Conductor Surface Production Length 80 2707 11814 Size 20" 94# H-40 13-3/8" 72# MN-80 9-5/8" 47# MN-80 Perforation depth: Measured depth: 11528 - 11534 True Vertical depth: 9009.68 - 9013.57 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Contact Sharmaine Vestal Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development M ' Stratigraphic Stimulate D Other D Waiver D Time Extension D Re-enter Suspended WellD 5. Permit to Drill Number: 177-0240 , 6. API Number: 50-029-20248-00-00 9. Well Name and Number: 0· D D Exploratory Service 05-08 . 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) 11120 None feet feet MD 29 - 109 26 - 2733 23 - 11837 TVD 29 - 109 26 - 2732.96 23 - 9211.96 Collapse 520 2670 4760 Burst 1530 5380 6870 11610-11640 9063.07 - 9082.71 <...::..C··' .>iNI.;"IE! f PU, 1\J ,,-" r\¡¡ -l')¡-- 00."'" ~ ,'! ('.": ? n, n r ~) ,_\; ,..ìJ 4-1/2" 12/6# L-80 30 - 11167 4-1/2" Baker S-5 Packer 11109 RBDMS BFL MAY 2 4 2006 Tubing pressure o o Service GINJ D WINJ WDSPL Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 5/22/2006 Submit Ori~nal OnlY,./ ,/ ~ð &.¿.,.·o",. e e 05-08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SUMMA~Y",>I 2/25/2006 ***WELL S/I UPON ARRIVAL*** PULLED 4 1/2 PX-PLUG FROM 11,130' (SLM) · *** CONTINUE TO 02/26/06 **** 2/26/2006 *** CONTINUE FROM 02/25/06 **** SET 41/2 WRP @ 11,104 (SLM) 11,120' MD. SITP 450 PSI WELL LEFT S/I FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL 05-08 (PTD #1770240) Classified as Problem Well (, e ~t!¿f Z{ti l/)(p Subject: 05-08 (PTD #177(240) Classificd as Problcm Well From: "Anders, Joe L" <andcrs22@HP.com> Date: Tim, 09 Fcb 2006 08: 1 1:00 -0900 To: "GPB, rSliSIP/STP Area Mgr" <GPHFSITL(q).BP.com>, "Rossbcrg, R Steven" <Stcven.Rossbcrg@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWe1l0perationsSupcrvisor@ßP.cotn>, "GPB, Wells Opt Eng" <G P B W ellsOptEng@BP.com>·, j imJcgg@admin.statc.ak.us, winton__ aubert@adll1in.state.ak.us, "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@}BP.coll1>, "Kurz, John" <john.kurz@BP.coll1>, "OPB, FS 1 DS Ops Lead" <GPBFSIDSOpsLead@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr(iþBP.con1>, "Dean, James A" <Jamcs.Dean@:ßP.com>, "Engel, Harry R" <Harry.Engel@BP.com> CC: "llughcs, Andrea (VECO)" <hugha4@BP.eom>, "NSU, ADW Well rntcgrity Engineer" <I'\SLJADWWellIntcgrityEnginccr(q)BP.com>, "MCCOLLUM, CODY 0 (VECO)" <Cody. MeCo II um@BP.com> All, Well 05-08 (PTD #1770240) has sustained casing pressure on the IA and has been classified as a Problem well. IA and OA pressures were 2030 & 680 psi on 2/08/06. The IA has repressured after several recent bleeds. We are currently evaluating secure options, including setting a plug in the packer bore. Attached is a well bore schematic. Please call if you have any questions. «05-08.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.eom " .~ ··f1.í..JtM-·¡ \2'...... \i" ,- . 7): Content-Description: OS-08.pdf Content-Type: application/octet-stream Content-Encoding: base64 ScP ~lf' ùtt- ZØ30 fS. 6tofs; /Q- ' b 0 lOps; 5'3\lfSi 2'1. s'~ (ðC. f<r Co LfI~ :- 12.G:,~ J <-4~ J-A. 1 of 1 2/9/2006 9:34 AM TREE = ? WELLHEAD = ? ACTUA TOR = CIW OTIS KB. ELEV = 64' BF. ELEV = ? KOP = ? Max Angle = 52 @ 6550' Datum MD = Datum ND = 8800' SS . 05-08 ¡-;aNDTES: . 2219' -14-1/2" CAMCO BAL-O SSSV NIP, 10=3.812 113-3/8" CSG, 72#, MN-80, 10 = 12.347" I Minimum ID = 3.812" @ 2219' 4-1/2" CAMCO BAL-O SSSV NIPPLE GAS LIFT MANDR8..S ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 4031 3975 28 MMG Df\!1Y RK 0 09/16/05 2 7744 6578 49 MMG DMY RK 0 09/16/05 3 10228 8183 49 MMG DMY RK 0 09/16/05 11109' -1 9-5/8" X 4-1/2" BA KER S-5 PKR I -14-1/2" HES X NIP, 10 = 3.813" I -14-1/2" PX PLUG (11/19/05) I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 11167' 11167' -14-1/2" TUBING TAIL I 11156' H ELMD TT LOG NOT A V AILABLE 4" 3-3/8" 33i8" 4" 3 3i8" ÆRFORATION SUMMARY REF LOG: BHCS ON 06/26/77 ANGLEATTOPÆRF: 51 @ 1nS1' Note: Refer to Production DB for historical perf data SPF INTERV AL Opn/Sqz DA TE 11351 -11385 S 11/16/77 11400 - 11420 S 11/16/77 11440-11450 S 11/16/77 11450-11460 S 11/17/88 11482 - 11516 S 11/06/77 11516 - 11532 S 05/04/00 11528 - 11534 C OS/22/03 11568 - 11590 S 11/26/87 11589 - 11630 S 11/17/88 11610-11640 C 05/13/00 4 4" 4 6 4 4 4 IPBTD I 19-5/8" CSG, 47#, MN-80, ID = 8.681" ~ DATE 07/04/77 12/24/97 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER :. ,., '1-.,. --:-----:-' -,-- "" DA TE REV BY COMMENTS 09/22/05 KSBITLH GL V C/O 09/24/05 EZLlTLH WA IVER SFrY NOTE DELETED ----.:-'- ,._m: i '! . . ,.- - -..-....- ,... - -- - --,- ---- 1 . "f: --.-: ----! '. - ;-.- I-:,n. - . ---- -- , PRUDHOE BA Y UNfT WELL: 05-08 ÆRMfT No: 11'1770240 API No: 50-029-20248-00 SEC 6, T10N, RiSE, 4192.52' FEL & 1743.92' FNL _',.____--.-.,.,-. ". ., ---.--, BP Exploration (Alaska) .. STATE OF ALASKA . ALA'" OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS o D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 64 KB 8. Property Designation: ADL-028329 11. Present Well Condition Summary: Total Depth measured 11860 true vertical 9227.05 Effective Depth measured 11662 true vertical 8778.21 Casing Conductor Surface Production Length 80 2707 11814 Size 20" 94# H-40 13-3/8" 72# MN-80 9-5/8" 47# MN-80 Perforation depth: Measured depth: True Vertical depth: Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Sharmaine Vestal Printed Name Sharmaine Vestal ?iu Signat~ Form 10-404 Revised 04/2004 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R1 Stratigraphic D feet feet feet feet MD 29 - 109 26 - 2733 23 - 11837 4-1/2" 12.6# 4-1/2" Baker S-5 Packer Stimulate D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Numþer: ..(.r~'·.·:::~. ' Exploratory Service RECEIVFD NOV 2 S 2005 . l,;ommissioil ARGhorage 6. rhber: 50-029-20248-00-00 9. Well Name and Number: 05-08 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) TVD 29 - 109 26 - 2732.96 23 - 9211.96 L-80 11150TT None Burst 1530 5380 6870 Collapse 520 2670 4760 20 - 11167 11109 $GANNEt) DEG Ü B 2ûD5 Title Data Mgmt Engr Tubing pressure Service WDSPL D Date 11/21/2005 ~. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory D Development R1 16. Well Status after proposed work: Oil R1 Gas WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Phone 564-4424 Submit Original Only e e 05-08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDA TE I SUMMARY 10/9/2005 *** CONTINUE FROM 10/08/05 *** CALIPER FROM 11,170' (SLM) TO SURFACE. SET PX PLUG BODY @ 11121' SLM. SET PX PRONG @ 11113' SLM (OAL= 96" 1.75" FN.) TESTED PLUG, GOOD TEST. ***LEFT WELL SHUT IN*** 10/10/2005 T/I/0=980/2240/1810. Temp=SI. Bleed WHP's <500 (Well Secure Project). T FL @ 10534' (below station #3) (>160 bbls). IA FL @ 9840' (above station #3) (>525 bbls). OA FL @ 45' «3 bbls). Bled WHP's to <500 psi in 5 hours, 20 minutes. Final FL's=T FL @ 10534' (unchanged). IA FL @ 9840' (unchanged). OA FL @ 35' (2 bbls). **Note** Natural Producer. Final T /1/0=210/270/320. 10/11/2005 T/I/0=260/270/360, Temp=SI. IA FL (Well Secure Project). IA FL @ 9840' (525 bbls), OGLV @ 10228' STA#3. IA FL remained unchanged from 10-10- 05. TBGP increased 50 psi, lAP remained unchanged, OAP increased 40 psi from 10-10-05. 10/23/2005 T/I/O = 650/520/310. Temp = SI. IA FL @ 9740' (between sta #2 & #3) Well Secure Project day 14. IA FL rose 100' since 10-11. 11/6/2005 T/I/0=1750/1760/1210. Temp=SI. Monitor WHP's & bleed (for secure). OA FL @ 366'(22 BBLS). Bled for 1 hour. OA FL @ 72' «5 BBL). Bled gas no ::fluid returned. Final WHP's 1750/1760/590. .u J 11/7/2005iT/I/0=1740/1710/1160, Temp=SI. Bleed WHP's < 300 psi. (monitor BUR). TBGP decreased 10 psi, lAP decreased 50 psi, OAP increased 570 psi from 11-6-05. Initial TBG FL @ 9537' (145 bbls), IA FL @ 7555' (404 bbls), above STA#2 7744' (Dome), OGLV @ 10228', OA FL @ 342' (20 bbls). Bled TBGP to production from 1740 psi to 290 psi in 4 hrs. Bled lAP to production from 1710 psi to 310 psi in 5.5 hrs. Bled OAP to production from 1160 psi to 310 psi in 2 hrs. TBG & IA FL's remained unchanged, OA FL inflowed 102' to 240'. Monitor pressures for 1 hr, TBGP & lAP remained unchanged, OAP increased _..100 psLt9u~10psi. Will need to freeze protect flow line. FWHP= 290/310/410. 11/8/2005iT/I/0=700/470/420. Temp=SI. Monitor WHP's Post Bleed (L TSI). TP increased 410 psi, lAP increased 160 psi, OAP increased 10 psi overnight. 11/9/2005 T/I/0=990/780/41 0, Temp=SI. WHP's post-bleed (eval secure). TBGP increased 290 psi, lAP increased 310 psi & OAP decreased 10 psi since yesterday. 11/10/2005 TIO = 1240/1100/470. Temp = SI. WHPS post bleed (eval secure). TBGP increased 250 psi, lAP increased 320 psi, OAP increased 60 psi, overnight. No AIL. Flow line psi = 1240 psi (same as TBGP) SI grove valve. Grove valve stem began hissing and gurgling slightly after being shut, unable to correct it byuseof cYc;ling'rl()tified DHD foremarl,DSO and Wells SU2port... 11/14/2005 T/I/0=1820/1750/1200. Temp=SI. Bleed WHP's & Flowline to 0 psi. (Well Secure). TP increased 580 psi in 4 days. lAP increased 650 psi in 4 days. OAP increased 730 psi in 4 days. Natural flow well No AL line. TBG FL @ 7744' sta#2 (118 bbl). IA FL @ 9314' between sta#2 & sta#3 (499 bbl). OA FL e e @ 348' (21 bbl). Bled OAP from 1200 psi to 290 psi in 3 hours 20 minutes. Bled TP from 1820 psi to 350 psi in 45 minutes. Bled lAP from 1750 psi to 450 psi in 4 hours 15 minutes. TP increased 10 psi tp 360 psi during lAP bleed. TBG FL now @ 7167' between sta#1 & sta#2 (109 bbl). IA FL now @ 9282' between sta#2 & sta#3 (497 bbl). No change in OA FL. T, IA & OA bleeds were all gas. Final WHP's=360/450/290 11/15/2005T/I/0=SSV/620/290. Temp=SI. Bleed WHP's & Flowline. (Well Secure). Flow line @ 0 psi for Blind installation, did not open SSV incase Wing valve leaks and repressure flow line. lAP increased 170 psi overnight. No change in OAP overnight. IA FL @ 9194' between sta#2 & sta#3 (492 bbl). OA FL @ .468' (28 bbl). Bled lAP from 620 psi to 160 psi in 5 hours 15 minutes. No change in IA FL during bleed. Bled OAP fro 290 psi to 20 psi in 5 hours 15 minutes. No change in OA FL during bleed. Well support crew installing blind in production riser. Final WHP's=SSV/160/20. 11/16/2005T/1/0= 1050/720/40. Temp= SI. MonitorWHP's (For Well Secure). Production S-riser blinded behind the Wing valve. Tbg pressure increased 690 psi since 11-14-05. lAP increased 560 psi and OAP increased 20 psi overnight. 11/16/2005 TI0=1050/860/60 F-PROTECT F-LlNE SECURE WELL UNABLE TO GET ·A PSI TEST CASCO VALVE NOT HOLDING FWHP=1050/860/60 11/17/2005 Freeze Protect Flow Line (Blind @ well head pump through casasco valve) - Pumped 5 bbls methanol, 25 bbls crude to freeze protect flowline 11/19/2005 ***WELL SI ON ARRIVAL*** (secure well) PULLED PX-PRONG @ 11,129' SLM & PX-PLUG BODY @ 11,133' SLM SET PX-PLUG BODY @ 11,136' SLM & PX-PRONG @ 11,131' SLM. GOOD TEST ***CONTINUE ON 11-20-05 WSR*** 11/20/2005 ***CONTINUE WSR FROM 11-19-05*** (secure well) BLEED DOWN IAlOA PRESSURES TO 1120/550. ***LEFT WELL SI*** FLUIDS PUMPED BBLS 1 I ::::L 1 01/23/04 Schlumberger NO. 3098 Alaska Data & Consulting Services Company: ~tate of Alaska 3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ( Well Job # Log Description Date Blueline Prints CD PSI-05 \ 40009587 OH EDIT LWD ARC & ADN (PDC1 09/25/03 1 t!:) ::.s q ~ PSI-05 \. 40009587 MD VISION RESISTIVITY 09/25/03 1 PSI-05 '\. 40009587 TVD VISION RESISTIVITY 09/25103 1 PSI-05 ')--6)rr~ '-J~q 40009587 MD VISION DEN/NEUTRON 09/25/03 1 PSI-05 / '-" 1'--' I 40009587 TVD VISION DEN/NEUTRON 09/25/03 1 PSI-05 / 10703940 RST-SIGMA 10/25/03 1 1 )~ ~c¡ ~~. PSI-05 J 10679041 RST-SIGMA 12/20/03 1 1 ìi-J--..l...q D-18A l:::::J.r \ " \ê'J..~ 10564487 RST-SIGMA 06/19/03 1 1 r:2 ~X')</ 05-08 r '.:j'~ --r)~~ L..j 10674406 RST-S1GMA 12/31/03 1 1 I{~\~;;:ç~ 02-04A C l ()- \ c::., -C;;V 10728382 MCNL 12/08/03 1 1 L:::) .~ q r- E-08A f'Jrf!:}~:{J:~~ 10728384 PRODUCTION PROFILE 01/01104 1 -\ - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotechnical Data Center LR2-1 3940 Arctic Blvd, Suite 300 900 E. Benson Blvd. Anchorage, AK 99503-5711 Anchorage, Alaska 99508 ATTN: Beth Date Delivered Brl\: Á tV'- ~.}) (J">Q ~" Received by RECEIVED ~L~ì"! ~) C 2004 (,..;:(r-'/Ari~.lj..I\i.IiIï.;;,;.'¡r..' rtfCff) f..I.:¡ ¡¡'þ C)..r]o~ A!~~aOiI&GasCons.Commision t09~å-~Ð~,¡~t\.;'\,,: ì þ';'JJ IIÞ clJ é- '/1>' Anmorage ............ ----"" C ",.::') _3~ ,N'\ ,':::'\.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanonr"~ Suspend[-'] Operation Shutdown[~] PerforateB Vadancer-] Annuar Disposal[-] After CasinQr-~ Repair Well[~ PluQ Perforationsr"l Stimulater"1 Time Extensionr-1 Otherr-] Change Approved Program~--] Pull Tubing[~ Perforate New PoolE] Re-enter Suspended WellE] ADD PERFS 2. Operator ,4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement [ Exploratory[~ 177-024 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic r-~ Service E] 50-029-20248-00-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 05-08 8. Property Designation: 10. Field/Pool(s): ADL 028329 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 11860 feet true vertical 9227 feet Plugs (measured) Tagged TD @ 11662' (05/13/2000). Effective Depth measured 11662 feet Junk (measured) true vertical 9097 feet Casi n g Length Size M D TV D B u ret Col lapse Conductor 109' 20" 141' 141' 40K 520 Surface 2701' 13-3/8" 2733' 2733' 80K 2670 Production 9180' 9-5/8" 11837' 9212' 80K 4760 Perforation depth: Measured depth: Open Perle 11528'-11534', 11610'-11640'. Sqzd Perfs 11351 '-11385', 11400'-11420', 11440'-11460', 11482'-11528'. Sqzd Perfs (continued) 11568'-11610'. True vertical depth: Open Perle 9010'-9014', 9063'-9083'. Sqzd Perfs 8896'-8918', 8927'-8940', 8953'-8966', 8980'-9~--~9~,~~'.¢.~ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 11167'. JUN Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BKR S-5 PKR @ 11109'. J~SI~ 0i~ ~ ~i'~I~ 4-1/2" CAMCO BAL-O SSSV Nipple @ 2219'. 12, Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubin~ Pressure Prior to well operation: 516 19718 95 734 Subsequent to operation: 543 14221 35 902 14. Attachments: 15. Well Class after proposed work: Exploratoryr--I Development~ Service[--~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: Oil[] Gas[--~ WAGr'-~ GIN Jr"] WINJ['-] WDSPLr"] Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnbr"~'"'''~ """"'"' I N/A Printed Name DeWavne R. Schnorr ,~ Title Techical Assistant Signature ,,~..e..,,~b~, .~:~,.~Z~3.~,.~ Phone 907/564-5174 Date June 05, 2003 Form 10-404 Revised 2,2~~j~F.~[~ ',j [j L1 05-08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/19/2003 PERFORATING: DRIFT/TAG 05/22/2003 PERFORATING: PERFORATING 06/01/2003 TESTEVENT--- BOPD: 355, BWPD: 11, MCFPD: 14,651, AL Rate: 0 EVENT SUMMARY 05/19/O3 WELL SI UPON ARRIVAL -- DRIFT & TAG W/3 3/8" D-GUN, TEL & S-BLR - TAG TD @ 11641' ELM - (1'OF RATHOLE, 107' BELOW TARGET @ 11534') NO SAMPLE. ***WELL LEFT SHUT IN*** O5/22/O3 PERFORATE 11528-11534 FT MD WITH 3 3/8" HSD / 3406 POWERJET, HMX @ 6 SPF. TIED IN TO BORAX/RST 8/9/99 - ON DEPTH WITH BHCS 6/26/77. GUN = 6 FEET OF 3 3/8" HSD LOADED IN 10 FOOT STOCK @ 6 SPF WITH 3406 POWERJETS. SPECIFICATIONS IN 4.5" CASING: PENETRATION = 38.6"/ ENTRANCE HOLE = .45" / EXPLOSIVE LOAD = 22.7G. TAG TD @ 11,618' MD. *********LEFT WING OPEN PER OPERATOR REQUEST - OPERATOR WILL OPEN AT CHOKE LATER********** 06/01/03 TESTEVENT --- BOPD: 355, BWPD: 11, MCFPD: 14,651, AL Rate: 0 FLUIDS PUMPED BBLS 1 DIESEL FOR SURFACE PRESSURE TEST 1 TOTAL RE-PERFS 05/22/2003 THE FOLLOWING INTERVAL WAS PERFORATED WITH 3-3/8" HMX POWERJET 3406 @ 6 SPF, 60 DEGREE PHASING, AND RANDOM ORIENTATION. 11528'-11534' Page I 05-08_pop_12-4-02 .txt subject: Returning PBU wells 05-08 and A-22 to production oate: Thu, 50ec 2002 13:21:08 -0600 From: "NSU, ADW well Integrity Engineer" <NSUADWWel 1 Integ ri tyEngi neet@BP, corn> To: Tom_Maunder@admi n. state, ak. us, Bob_F1 eckenstei n@admi n. state, us, Ji m_Regg~admi n. state, ak. us cc: "NSU, ADW well Operations Su.pervisor" <NSUADWWel 10perati onsSupervl sor@BP, corn>, "Rossberg, R Steven" <RossbeRS@BP. com> Gentlemen, The following "A" category well has been returned to production: DS 05-08 (on line 12/04/02 @ 11:00). Attached please find the test records that demonstrate the two competent barriers required to produce this well. In addition, well A-22 was returned to production 12/03/02 at 13:00. with its recent workover, A-22 is no longer designated as a category "A" well. During the workover, the new tubing string was tested to 3500 psi and the inner annulus was tested to 3000 psi. Both tests passed. Dave Reem for Joe Anders 659-5102 Mobil: 943-1154 Pager: 659-5100, x1154 Name: 05-08 MIT 09-19-02.xls 05-08 MIT 09-19-02.xls Type: Microsoft Excel worksheet (application/vnd.ms-excel) Encoding: base64 Name: 05-08 TIFL ll-16-02.xls 05-08 TIFL ll-16-02.xls Type: Microsoft Excel worksheet (application/vnd.ms-excel) Encoding: base64 Name: BP Well 05-08 MIT 11-24-02.xls BP well 05-08 MIT 11-24-02.xls Type: Microsoft Excel worksheet (appl i cati on/vnd, ms-excel ) Encoding: base64 Page 1 WELLHEAD PACKOFF TESTING FORM WELL: DATE' TESTED BY: DS: 05-08 1112412002 FMC TEST FOR: TYPE & GEN FSO # 32619 FMC I Well Status: TBG' CONTROL: INITIAL PRESSURE DATA TYPE: 2380 IA: 900 2380 BALANCE' 2380 OA: 1100 Tubinq Hanger Test PASS FAIL Pressured To: 5000 Press. @ 15 min: 5000 Press. @ 30 min: Test Port Press. @: 200 Bled to 0 Psi YES I NO Were Lockdown Screws Tightened ? YES / NO Torqued to Comments: Alinment pin is OUT. 5000 fi/lbs Inner Casing Hanger Test PASS FAIL PLASTIC PACK Pressured To: 3000 Test Port Press. @' 150 Were Lockdown Screws Tightened ? Comments: Press. @ 15 min' 3750 Press. @ 30 min' Bled to0Psi YESINO YES / NO Torqued to 3725 ft/Ibs We!~: DATE: TESTED BY: 5-08 11116~02 BP TIFL: PASS Well Status: FLOWING TBG: 2360 Control: INITIAL PRESSURE DATA SHUT IN GAS LIFTED: IA: 1870 OA: 1180 Balance: NO OGLV DEPTH: INITIAL FLUID LEVEL: 6025' BLED FROM 1870 psi To POST BLEED PRESSURES: WELL BACK TO PRODUCTION: 650 TBG: TIFL SUMMARY LIVE GLV'S AT: POST BLEED FLUID LEVEL: 6025' psi in 2 HRS and 20 MINS 2330 IA: 650 OA: 980 NO FLUID LEVEL DATA TIME TBG I.~A O~A FLUID LEVEL COMMENTS 15:50 2360 1870 1180 6025' Start bleed 16:50 2330 1040 1000 Incon 17:50 2330 700 980 6025' 18:10 2330 650 980 6025' SI bleed P,//D GOOD TEST OBSERVATIONS I COMMENTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak. us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / 05 09/19/02 Dave Wendt Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. P.T.D. 1770240I IType test M Test psil 21871 I. Casing 1200 1200 1200 1200 P/FI P Notes: MIT-OA [09/19/02] O. Casing 0 3000 2900 2880 WellI I Typelnj. I N/A I MDFFVD~ I ITubing IntervalI P.T.D. I Type test M Test psi ~ Casing P/F Notes: O. Casing Well lI Type Inj. MDFFVDI Interval J P.T.D. I I Type testI I Test psiI I I Tubing Casing P/F I Notes: Well! Type Inj. I MD/TVDI Tubing ' I I Testpsil ' Typetestl II I II'nter a' P,T.D, Casing P/F Notes: WellI Type Inj. MD/TVD~ Tubing Type test I TestpsJl I I ]JJl'nte~a'l P.T.D.I Cas ng P/Fi Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) bllT Repod Form Revised: 06119/02 05-08 MIT 09-19-02.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X (Cmt Sqz f! WSO) 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2851' FNL, 5044' FEL, Sec. 32, T11N, R15E, UM At top of productive interval 1398' FNL, 3427' FEL, Sec.6, T10N, R15E, UM At effective depth At total depth 1744' FNL, 4193' FEL, Sec. 6, T10N, R15E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic_ Service__ (asp's 697316, 5948597) (asp's 693770, 5944677) (asp's 693013, 5944309) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 05-08 9. Permit number / approval number 177-024 10. APl number 50-029-20248 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 109' 20" Surface 2669' 13-3/8" Production 1 1773' 9-5/8" 11860 feet Plugs (measured) 9227 feet 11662 feet Junk (measured) 9097 feet Cemented 224 Sx AS 5000 Sx AS 1200 Sx Class G & 300 Sx AS PBTD tagged (5/13/2000) @ 11662' MD. ORIGINAL Measured Depth 109' 2733' 11837' True vertical Depth 109' 2733' 9212' Perforation depth: measured 11610'- 11640'. true vertical 9063' - 9080'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 11167' MD. Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" BAKER S-5 PACKER @ 11109' MD. 4-1/2" CAMCO BAL-O SSSV @ 2219' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 1237 Subsequent to operation 95 Representative Daily Avera.qe Production or Injection Data Gas-Mci Water-Bbl 34935 103 3270 8 Casing Pressure Tubing Pressure 1994 380 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~./~, '~ ~, Title PAl Wellwork Design & Optimization Supervisor Erin Oba Date - 5 - Prepared by Paul Rauf 2¢$-4990 ,_.~,'T Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE O5-O8 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZE FOR GSO & PERFORATING OPERATIONS Date Event Summary 2/21/2000: 3/05/2000: 5/04/2000: 5/05/2000: 5/11/2000: 5/13/2000: 5/28/2000: RIH & tagged PBTD @ 11650' MD. MITIA to 2500 psi - inconclusive - lost 200 psi in 30 min (press not stabalized). An Acid Wash & Cement Squeeze for GSO were performed as follows: MIRU CTU. PT'd equip to 4000 psi. Killed well w/Crude & 1% SLK 160° KCL Water. RIH w/CT & tagged PBTD @ 11650' MD. Total of 91 bbls of SLK Water pumped. Pumped 48 bbls of 12% HCL - 10% Xylene - 3% Acetic Acid @ 2.5 to 1.0 bpm across perfs, followed by 1% KCL Water overflush stage. Pumped 82 bbls of Latex Acid Resistive Cement to squeeze off all the open perforations listed below: 11450' - 11460' MD (Zone 2) 11516' - 11532' MD (Zone 2) 11589' - 11630' MD (Zone 2) Placed 10 bbls of LARC behind pipe with a max squeeze press attained of 3500 psi. Contaminated Cement w/Biozan & cleaned out to 11660'. Layed in 20 bbls of TEA across squeezed perfs. 1:1 rts during cleanout. FP'd well. POOH w/CT. Left 500 psi on wellhead. RD. WOC. RIH & tagged PBTD @ 11650' MD. PT'd cement plug to 1175 psi - passed. MIRU ELU. PT'd equip to 3000 psi. RIH w/perforation guns & tagged PBTD @ 11662' MD. Ran GR/CCL log f/11620' - 10140'. Shot 30' of perforations as follows: Reperforated: 11610' - 11630' MD (Zone 2A) Reference Log: BHCS 6/26/1977. Add perforated: 11630' - 11640' MD (Zone 2A) Used 3-3/8" carriers & all shots @ 4 SPF, underbalanced press, random orientation, & 60°/120° phasing. POOH w/guns. ASF. RD ELU. MITOA to 2000 psi - passed for WC. Placed well BOL & obtained a representative well test. Currently, well is shut in, awaiting a video log to locate tubing leak. Well has a waiver to produce w/tubing leak. A new GLV design is also in progress. Page 1 ---- STATE OF ALASKA - ALASKA ~.._ AND GAS CONSERVATION COM~v~iSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [--1 Pull Tubing 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2428' NSL, 234' EWL, SEC. 32, T11 N, R15E, UM At top of productive interval 1398' SNL, 1595' EWL, SEC. 06, T10N, R15E, UM At effective depth 1791' SNL, 1319' EWL, SEC. 06, T10N, R15E, UM At total depth 1841' SNL, 987' EWL, SEC. 06, T11N, R15E, UM [] Stimulate [] Plugging [] Perforate []Alter Casing [] Repair Well I--]Other 5. Type of well: [] Development [] Exploratory [] Stratigraphic [--] Service 6. Datum Elevation (DF or KB) 64' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 05-08 9. Permit Number / Approval No. 77-24 10. APl Number 50-029-20248 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11860 true vertical 9237 Effective depth: measured 11750 true vertical 9165 Casing Length Structural Conductor 80' Surface 2710' Intermediate Production 9839' Liner feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 20" 224 sx Arctic Set 13-3/8" 5000 sx Arctic Set 9-5/8" 1200 sx Class 'G', 300 sx Arctic Set MD TVD 109' 109' 2733' 2733' 11837' 9222' Perforation depth: measured 11450'-11460', 11516'-11532', 11589'-11630' true vertical 8969'-8976', 9011'-9022', 9059'-9086' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, BTC-Mod to 11167' RECEIVED Alaska 0il & uas Cons. Commission Anchorago Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker packer at 11109',; 4-1/2" BaI-O SSSV nipple at 2219' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil I~ Gas F-] Suspended Service 17. I hereby certif,~at~the(,~,, -'~ foregoing/i~ true and correct to the best of my knowledge Signed Jame~:~ J. CP_¢~ Title Engineering. Supervisor v - ~/ Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicat~ Facility PB DS 05 Progress Report Well 05-08 Rig Page Date l 13 January 98 Date/Time 11 Dec 97 12 Dec 97 13 Dec 97 14 Dec 97 15 Dec 97 21:00-01:00 01:00-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-11:30 11:30-13:30 13:30-18:00 18:00-18:30 18:30-19:00 19:00-02:30 02:30-03:00 03:00-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-11:15 11:15-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-01:00 01:00-01:45 01:45-02:00 02:00-03:00 03:00-04:00 04:00-04:30 04:30-04:45 04:45-06:00 06:00-06:30 06:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-21:00 21:00-21:45 21:45-23:45 23:45-00:45 00:45-02:00 02:00-05:45 05:45-06:00 06:00-06:30 06:30-07:00 07:00-12:00 12:00-13:00 13:00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-19:45 19:45-00:00 Duration 4 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3 hr 2hr 4-1/2 hr 1/2 hr 1/2 hr 7-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 4-1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 5 hr 1/2 hr 6-1/2 hr 3/4 hr 1/4 hr lhr 1 hr 1/2 hr 1/4 hr 1-1/4 hr 1/2 hr llhr 1/2 hr 1/2 hr 1/2 hr 2hr 3/4 hr 2hr lhr 1-1/4 hr 3-3/4 hr 1/4 hr 1/2 hr 1/2 hr 5hr lhr 4hr lhr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 4-1/4 hr Activity Rig moved 100.00 % Installed Fluid system Fill pits with Seawater Held safety meeting Removed Internal BOPs Tested High pressure lines Circulated at 11260.00 ft Removed Surface tree Installed BOP stack Held safety meeting Installed BOP stack Tested BOP stack Made up BHA no. 1 Fished at 25.00 ft Circulated at 11260.00 ft Pulled BHA Held safety meeting Retrieved Tubing Held drill (Kick while tripping) Retrieved Tubing Rigged up Lines / Cables Retrieved Tubing Held safety meeting Retrieved Tubing Removed Tubing handling equipment Installed Wear bushing Made up BHA no. 2 Made up BHA no. 2 R.I.H. to 900.00 ft Held drill (Kick while tripping) R.I.H. to 2800.00 ft Held safety meeting R.I.H. to 10500.00 ft Serviced Block line Held safety meeting Serviced Block line R.I.H. to 11259.00 ft Fished at 11259.00 ft Circulated at 11225.00 ft Pulled out of hole to 9889.00 ft Circulated at 9889.00 ft Pulled out of hole to 300.00 ft Pulled BHA Held safety meeting Pulled BHA Made up BHA no. 3 Made up BHA no. 3 R.I.H. to 11259.00 ft Fished at 11259.00 ft Held safety meeting Circulated at 11259.00 ft Pulled out of hole to 10000.00 ft Held drill (Kick while tripping) Pulled out of hole to 300.00 ft Facility PB DS 05 Progress Report Well 05-08 Rig Page Date 2 13 January 98 Date/Time 16 Dec 97 17 Dec 97 18 Dec 97 19 Dec 97 00:00-00:30 00:30-02:00 02:00-03:00 03:00-03:45 03:45-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:30 09:30-15:00 15:00-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-22:30 22:30-23:15 23:15-23:30 23:30-01:30 01:30-02:00 02:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-10:30 10:30-11:30 11:30-16:00 16:00-18:00 18:00-18:30 18:30-19:30 19:30-22:00 22:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-11:30 11:30-13:00 13:00-15:00 15:00-15:15 15:15-17:00 17:00-18:00 18:00-18:30 18:30-21:15 21:15-23:30 23:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-11:00 11:00-14:30 14:30-15:30 Duration 1/2 hr 1-1/2 hr lhr 3/4 hr 2-1/4 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 5-1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr 2-1/2 hr lhr 1/2 hr 3/4 hr 1/4 hr 2hr 1/2 hr 4hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 1 hr 4-1/2 hr 2 hr 1/2 hr lhr 2-1/2 hr 6-1/2 hr lhr 1/2 hr 1/2 hr 4hr 1/2 hr 1/2hr 1-1/2 hr 2 hr 1/4 hr 1-3/4 hr 1 hr 1/2 hr 2-3/4 hr 2-1/4 hr 5-1/2 hr lhr 1/2 hr 1/2 hr 4hr 3-1/2 hr lhr Activity Pulled BHA Made up BHA no. 4 Serviced Drillstring handling equipment Made up BHA no. 4 R.I.H. to 6585.00 ft Held safety meeting R.I.H. to 11259.00 ft Fished at 11259.00 ft Circulated at 11287.00 ft Pulled out of hole to 300.00 ft Pulled BHA Made up BHA no. 5 R.I.H. to 3700.00 ft Held safety meeting R.I.H. to 11226.00 ft Serviced Block line Fished at 11287.00 ft Circulated at 11542.00 ft Pulled out of hole to 10478.00 ft Circulated at 10478.00 ft Flow check Pulled out of hole to 3000.00 ft Held safety meeting Pulled out of hole to 300.00 ft Pulled BHA Laid down fish Made up BHA no. 6 R.I.H. to 11542.00 ft Milled Permanent packer at 11542.00 ft Held safety meeting Milled Permanent packer at 11542.00 ft Circulated at 11600.00 ft Pulled out of hole to 7846.00 ft Milled Permanent packer at 7846.00 ft Pulled out of hole to 7500.00 ft Held safety meeting Pulled out of hole to 300.00 ft Pulled BHA Laid down fish Made up BHA no. 7 R.I.H. to 6543.00 ft Held drill (Kick while tripping) R.I.H. to 11608.00 ft Washed to 11685.00 ft Held safety meeting Circulated at 11685.00 ft Reverse circulated at 11660.00 ft Pulled out of hole to 500.00 ft Pulled BHA Held safety meeting Made up BHA no. 8 R.I.H. to 11160.00 ft Tested Casing - Via annulus Pulled out of hole to 9020.00 ft Progress Report Facility PB DS 05 Well 05-08 Page 3 Rig Date 13 January 98 Date/Time 15:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-23:30 23:30-00:30 20 Dec 97 00:30-02:30 02:30-03:30 03:30-03:45 03:45-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-14:30 14:30-15:00 15:00-16:30 16:30-16:45 16:45-18:00 18:00-18:30 18:30-03:00 21 Dec 97 03:00-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-14:00 14:00-15:30 15:30-18:00 18:00-18:30 18:30-20:00 20:00-02:30 22 Dec 97 02:30-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-15:30 15:30-18:00 18:00-18:30 18:30-01:00 23 Dec 97 01:00-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-12:30 12:30-15:30 15:30-18:00 18:00-18:30 18:30-21:00 21:00-00:30 24 Dec 97 00:30-01:30 01:30-04:30 04:30-06:00 06:00-06:30 Duration 1/2 hr lhr lhr 1/2 hr 5 hr lhr 2hr 1 hr 1/4 hr 3/4 hr 1-1/2 hr 1/2 hr 2hr lhr 5hr 1/2 hr 1-1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 8-1/2 hr lhr 2hr 1/2 hr 1-1/2 hr 2hr 4hr 1-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 6-1/2 hr 2-1/2 hr lhr 1/2 hr 4-1/2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 6-1/2 hr 4hr lhr 1/2 hr 2hr 4hr 3hr 2-1/2 hr 1/2 hr 2-1/2 hr 3-1/2 hr lhr 3hr 1-1/2 hr 1/2 hr Activity Tested Casing - Via annulus Pulled out of hole to 7203.00 ft Tested Casing - Via annulus Held safety meeting R.I.H. to 11176.00 ft Tested Casing - Via annulus Circulated at 11176.00 ft Laid down 9900.00 ft of 5in OD drill pipe Held drill (Kick while tripping) Serviced Block line Laid down 1400.00 ft of 5in OD drill pipe Held safety meeting Laid down 2000.00 ft of 5in OD drill pipe Rigged down Kelly/top drive hose Laid down 6000.00 ft of 5in OD drill pipe Pulled BHA Removed Wear bushing Held safety meeting Ran Tubing to 400.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 8900.00 ft (4-1/2in OD) Installed SCSSSV Ran Tubing to 10000.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 11167.00 ft (4-1/2in OD) Installed Tubing hanger Reverse circulated at 11167.00 ft Set packer at 11109.00 ft with 3500.0 psi Tested Permanent packer Held safety meeting Tested Permanent packer Conducted slickline operations on Slickline equipment - Tool run Tested Permanent packer Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Conducted slickline operations on Slickline equipment - Setting run Tested Permanent packer Conducted slickline operations on Slickline equipment - Setting run Held safety meeting Conducted slickline operations on Slickline equipment - Setting run Tested Permanent packer Tested Tubing - Via string Held safety meeting Tested Tubing - Via string Conducted slickline operations on Slickline equipment - Tool run Tested Tubing - Via string Tested Casing - Via annulus Held safety meeting Tested Casing - Via annulus Conducted slickline operations on Slickline equipment - Tool run Installed BOP test plug assembly Rigged down BOP stack Installed Surface tree Held safety meeting Facility PB DS 05 Progress Report Well 05-08 Rig Page Date 4 13 January 98 Date/Time 06:30-11:00 11:00-13:30 13:30-14:00 Duration 4-1/2 hr 2-1/2 hr 1/2 hr Activity Installed Surface tree Freeze protect well - 150.000 bbl of Diesel Installed Surface tree STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing ~ Alter casing ~ Repair well Perforate Other X.~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4o Location of well at surface 2428' FSL, 234' FWL, Sec 32, T11N, R15E, UM. At top of productive interval 1398' FNL, 1595' FWL, Sec 6, T10N, R15E, UM. At effective depth 1791' FNL, 1319' FWL, Sec 6, T10N, R15E, UM. At total depth 1841' FNL, 987' FWL, Sec 6, T11 N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service X,, 6. Datum of elevation(DF or KB) 64' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 5-O8 9. Permit number/approval number 77-24 10. APl number 50 - 029-20248 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 1860 feet Plugs(measured) 9237 feet Effective depth: measured true vertical Casing Length Conductor 80' Surface 2710' Production 9839' 11750 feet 9165 feet Junk(measured) Size Cemented 20" 224 Sx AS 13-3/8" 5000 Sx AS 9-5/8" 1200 Sx G & 300 Sx AS Measured depth 109' 2733' 11837' True vertical depth 109' 2733' 9222' RECEIVED Perforation depth: measured 11450- 11460'; 11516- 11532'; 11589- 11630' true vertical 8969 - 8976'; 9011 - 9022'; 9059 - 9086' MAY 1 5 1996 Almmka 011 & Gas Cons, Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2" Tbg @ 29' MD; 4-1/2", 12.6#, L-80, Tbg @ 11572' MD. Packers and SSSV (type and measured depth) BOT HB Packer @ 11300' MD & Baker DB Packer @ 11542' MD; 4-1/2" C~rnc. n Ral-O RRRV ~. 21.q1' MI'3 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 2259 37389 0 2391 35015 0 Tubing Pressure 1129 1092 15o Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended Service 17o I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢,~, '~, ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 5-8 TUBING PATCH iNSTALLATION DESCRIPTION OF WORK COMPLETED 3/1 8/96' RIH w/video camera & found a small tubing leak at 6053' MD. 4/1 5/96' RIH & set an AVA DWP 4.5" OD x 3.725" ID tubing patch across the tubing leak (above) at 6047 - 6062' MD (seal to seal). PT patch OK. Rigged down. Returned the well to production & obtained a valid production test. RECEIVE1) U/~¥ 1 5 199G AlaSka 011 & Gas Cons. commission Anchorage ARCO Alaska, Inc. Date' Apr 14, 1994 P.O. Box 100360, .horage, AK Transmittal #: 94034 99510,4~ ~' Subject: ARCO Cased Hole Finals From/Location: Telephone: To/Location: John. E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Log Date i Tool Type i Run, (M-D-Y) ! i Scale 04-02-94 i,/ PerfRecord i 1 5" 03-25-94 i TDT-P 03-28-94 !/ TDT-P 03-27-94 t,~ Perf Record 03-22-94 t~ Leak Detection 03-19 03-29 .~ 03-29 03-27-94 03-31 03-27-94 03-29-94 i /04-43 qq-'l~!~ 04-43 i X,04-43 04-44 06-19 07-08. 07-23 03-22-94 03-18-94 i 1 5" i 1 5" i 1 5" ~ 2" .,' 1 i 1 5" i 1 5" ! 1 5" ,. : 5 ' : 1 1 5" Bridge Plug Leak Detection !/ Bridge Plug i./' Bridge Plug i,/ TDT-P , ¢' USIT 03-13-94 iv' USIT Contractor 1,/ Perf Record 04-03-94 i-' Perf Record Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 03-29-94 i/ CNTG ~ 1 5" Sch 03-10-94 ' ~ 1 5" Sch 1 5" 1 5" i 1 5" 1 5" ! 1 5" Sch Sch 04-45 03-29-94 !¢' USIT Cement 05-08 03-14-94 iv Prod Profile Sch 03-18-94 Sch Sch 03-21-94 !'/ Bridge Plug 03-30-94 i,,' Prod Profile ! 1, 1"&5" 03-17-94 i~' Prod Profile i 1, 5" 03-29-94 !/ Prod Log ! 1, 1"&5" 04-01-94 !,,' Perf Record i 1, 5" 03-16-94 i/' Prod Log ! 1, 5" 03-22-94 i ," Perf Record i 1, 5" ;' 03-16-94 ! ," Patch setting, i 1 , 5" 03-29-94 1,/ Perf Record ! 1, 5" 03-18-94 i- Prod Profile i 1, 1"&5" 09-01 09-02 70-~)c~ 09-03 ']'"/-~Di 09-19 ~%-Z~.' 09-27 ~;- (~Oi 11-04 ;lo~q ! 11-17 f~).-ZO{~ 11-24A ~ 7..- 5L~ 12-06A ~?--Oq ! 13-20 Leak Detection i 1, 1"&5" i 1,5" Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 14-03 14-23 14-28 !%14-28 14-35 16-04A 16-18 16-28 18-08 Sch 03-15-94 03-28-94 .- CNL Sch 03-19-94 ./ Prod Profile i 1, 1"&5" Sch · 03-15-94 ,/Leak Detection Sch 03-28-94 03-21-94 03-1 7-94 · Patch Setting i 1, 5" Bridge Plu~] i 1, 5" CNL { 1, 5" ,,-- Perf Record i 1.5" Leak Detection i 1, 2"&5" !v- Perf Record i 1, 5" iv TDT-P j 1, 5" 03-15-94 03-14-94 03-14-94 03-20-94 Sch ~ Sch Sch Sch Sch Sch Sch Number of Records: 38 ARCO Alaska. Inc. Is a Subsidiary of AtlanflcRIchfleldCompany ARCO Alaska, In(' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 10, 1990 Mr. John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Dear John: Please cancel the following 14 Forms 403 for which no Forms 404 were written. Per the drill-site engineers, this work has not been done and is no longer planned. D.S. Ap.Dr. # Date Signed 1987 3-4 7-51 1/26/87 4-6 7-263 4/20/87 4-10 7-188 3/20/87 4-10 7-238 4/8/87 4-14 7-264 4/20/87 5-8 7-624 9/23/87 9-16 7-291 4/27/87 14-13 7-399 6/18/87 14-30 7-1[]0 2/13/87 16-24 7-117 2/26/87 1988 3-9 8~826 11/2/88 3-13 8-854 11/17/88 6-13 8-316 4/28/88 9-34 8-864 11/21/88 Please call me at 263-4310 if you have any questionscon~.,.r,~'~ ~',~ng these S,~nd,~,,,." S. T. H,offecke, Reco~'ds Pr(~''~' :essor STH/ab/034 J. L. Glaeser - ATO 1528 ~ RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany APR 1 II 1 90 .() ~'::; ]" E ' 2---23-9('} i;::E!::i'::- F.:E N Cr',_. Al:,'r"O, :,_. C A;k:'E--r'-.,... HOI...E i::' ]: i".!Ai._,!i:, ~." A L. L. Y H 01;:' F' i:.:: C i< E R A T'O- i 529 MAR - 6 1990 Alaska Oil & Gas Cons. Co~Ss~O~ Anchorage AF'F'ROVED .~_._ T'RAN.S':~ 9.::} (:.~9 'i D :i: 3' T R ]: B U T ]: 0 N '-,,-'"' C: F: N T I;..' A t_ F :[ L_ E Z ~-'"' f":_ l-'i t:: ...... 'v' I:;: ri N ~' EXTEN£,'ION ....... EX'F, LnRATION ,-,z, ON iff A i;..' A T H 0 N :~ M 0 B :[ L P H :i: I.. L.. I F' 3' F'B WELL F']:LE,?~' R & D BF'X STATE OF- AI_A$1<A TEXACO THE CFi~;'REC'I'ED AF'I~ FOR 5-6 I£' ~'-;:; .... '";:'~':~-"~'":;iTS 'i-HF.: POi-'p"r"TED.., ',.. ,E,., AF'I~ FOR 5-t.".::;, I&" 5(:)-,:':)::79-2~263,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~i~ GAS [~ SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-24 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 029-20248 4. Location of well at surface 9. Unit or Lease Name 2428' FSL, 234' FWL, 5ec.32, T11N, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1398' FNL, 1595' FWL, Sec.6, TION, R15E, UN 5-8 At Total Depth 11. Field and Pool 1841' FNL, 987' FWL, Sec.6, TION, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 64' RKBI ADL 28329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offshore 116. No. of Completions 06/08/77 06/29/77 07/04/77* N/AI 1 feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11860'MD~9237'TV~ 11750'MD~ 9165'T q~'ESJ~ NO []I 2191' feet MDI 1900' (approx.) 22. Type Electric or Other Logs Run D I L/SP/BHCS/GR, FDC/CNL/GR/CAL, GR/CNL/CCL; CCL/GR. Hultishot 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" q~.O~ H-~ .~,,rq !~lq' 32" 224 Sx Arcti~ 1%-~/~" 79_fl~ MN-Rtl ~,,rf 97~%, !7-!/2' 5000 sx Arcti~ 9-5/8' ~7~0~ MN-R0 S,_,r~ 11837' !2-!/~.' !200 sx Class G & 300 sx AS t -95 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf, 90° phasing 5-1/2" 11571~ 11~00' & 115~-;2' 11450 ' -11460 ' MD/8969 ' -8976 'TVD 1151 6'-11532'ND/9011 ' -9022 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ....... v..... -~ , ,~^_~:~ ~c~,_~,:_=n, "~"~ G & "" bbl-l'"' IV, , ~ I ,.~..~ I I I I~.'V ~.. I lC.10 0 , JU ~ I~L 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) i Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS'OILRATIO I ...... ' _11,,~' 1521 10/23/ :~, ,. ~3 TEST PERIOD e ;,nn 60c' 'OIL GRAVI -APl (corr) Flow Tubing Casing Pressure CALCULATED,1~ OIL-BBL GAS-MCF WATER-BBL Press. 1 7: :9 1 ~50 24-HOUR RATE "~' 2~.02 3652 ) 27.0 28. CORE DATA .....'"t iVED Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core c~s~ None J ':~ ~'~-~-~ 0il & Gas Cons. C0mmissi0[~ Anchorage * NOTE: Workovers performed 3/24/78 & 9/6/83. Perforate and reperforated 11/5/77, 1/21/79, 9/29/84 & 11/26/87. CTU, squeeze of perfs performed 11/6/87. Workover, squeeze and perforation performed 11/20/88. Form 10-407 Submit in duplicate Rev. 7~1-80 CONTINUED ON REVERSE SIDE WC5/054.1 GEOLOGIC MARKERS FORMATION TESTS · NAME InclUde interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochit 10883' 8614 ' None Base Sadl erochi . 11747' 9163' ;, 31. LI~n(~F ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ..... Title Engineer Date ~) INSTRUCTIONS General' This form is designed for submitting a Complete and correct well completion report and log on all types oif 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 STATE OF ALASKA AL, .~KA OIL AND GAS CONSERVATION COMMIb -~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P.0. Box 100360¢ Anchora~e~ AK 99510-0360 4. Location of well at surface 2428' FSL, 234' FWL, Sec. 32, T11N, R15E, UM At top of productive interval 1398' FNL, 1595' FWL, Sec. 6, TION, R15E, UM At effective depth 1791' FNL, 1319' FWL, Sec. 6, TION, R15E, UM At total depth 1841' FNL;, 987' FWL;, Sec. 6~ TION, R15E~ UM 12. Present well condition summary Total depth: measured 11860 ' MD feet true vertical 9237 ' TVD feet Effective depth' measured 11750' MD feet true vertical 916..5 ' TVD feet Perforate __ Pull tubing% OtherxN-- We rkover 5. Type of Well: Development Exploratory Stratigraphic Service Plugs(measured) None 6. Datum elevation (DF or KB) RKR ;~b. ~ 7. Unit or Property name Prudhoe Bay Unit 8. Well number 5-8 9. Permit number/approval number 7 7- 2/~_/R-77¢) 10. APl number 50-- 029-20248 feet 11. Field/Pool Prudhoe Ba~, Field Junk(measured) Fish ~ 11,691' Casing Length Structural Conductor 80 ' Surface 2710 ' Intermediate Production 11816' Liner Perforation depth: measured Size , Cemented 20" 224 sx AS 13-3/8" 5000 sx AS 9-5/8" 1200 sx Class G & 300 sx AS 11450'-11460'MD, 11516'-11532'MD Measured depth True vertical depth 1 09 ' MD 109 ' TVD 2733' MD 2733' TVD 11837 ' MD 9222 ' TVD true vertical ' 8969'-8976'TVD, 9011 '-9022'TVD Tubing (size, grade, and measured depth) 4-1/2". L-80, tubing w/tail ~ 11572' Packers and SSSV (type and measured depth) Camco "Ral-0" ,S$$V _¢ 2191'.: Raker "HR" ,~ "DR" nl~r-_~ ~ 11~00' & llSb.?'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Performations f/11524'-11534' Treatment description including volumes used and final pressure 275 sx Class G & 36 bbls HCL 14. N/A Representative Daily Average Production or Injection Data Oit-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run,,__ Daily Report of Well Operations ",., , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Form 10-404 Rev 06/15/88 / * Workover Well History 5W03/071.1 16. 'Status of well classification as: Oil ~ Gas __ Suspended __ Regional Drilling Engineer Service Date '/"Z ~/~'(~ , SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well HistOry - Initial Report - Daily Instructions: Prepare and submit the "initial Rel)ort" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only, District ICounty, parish or borough Field .,5,,1~C0 .~,~.,~.~._o.~,...~. I~;C,J .... ~' ~'~ Lease o r~ ~ ........ I PP.U~HOE ~AY ' ~L: 2~329 Auth. or W.O. ~o. ~Title I A-.. 70 WC~KC'~ Well no. DC.,='$ Operator AP. CO Spudded or W.O, begun IOate Date and depth' as of 8:00 a.m, 11/09/88 ( TD:l1860 PB:l1750 SUPV:GG/RB 11/10/88 ( TD:11860 PB:11750 SUPV:ZR 11/11/88 ( TD:l1860 PB:11750 SUPV:ZR 11/12/88 ( TD:11860 PB:11750 SUPV:ZR 11/13/88 ( TD:11860 PB:11750 SUPV:ZR 11/14/88 ( TD:11860 PB:11750 SUPV:ZR 11/15/88 ( TD:l1860 PB:11750 SUPV:ZR 11/16/88 ( TD:11860 PB:11750 Compieterecordforeachdayreponed API: 59-029-2024g I I /no/oo tARCO W I p,~ogA~°sqP~°w.o. KILLING WELL MW: 8.5 SEAWATER ACCEPT RIG AT 1530 HRS 11/08/88. MU AND TEST KILL AND CHOKE LINES. ATTEMPT TO PULL PBV. BULL HEAD TBG AND ANNULUS W/ SEAWATER TO KILL WELL. DAILY:S51,064 CUM:$51,064 ETD:S51,064 EFC:$943,000 TESTING PACKOFFS MW: 8.5 SEAWATER KILLED WELL, ND TREE, NU BOPE & TEST, TEST 13-3/8" PACKOFF. DAILY:S27,250 CUM:$78,314 ETD:S78,314 EFC:$94'3,000 RIH W/ OVERSHOT MW: 8.5 SEAWATER POOH & LD TBG HGR, 5-1/2" TBG, & SEAL ASSEMBLY, RIH W/ OVERSHOT TO FISH PBR BARREL. DAILY:S32,006 CUM:$110,320 ETD:S110,320 EFC:$943,000 RIH W/ 8-1/2" MILL MW: 8.5 SEAWATER RIH W/ OVERSHOT, RETRIEVE PBR, PACKER, & TAILPIPE, RIH W/ 8-1/2" MILL TO CLEAN OUT FILL. DAILY:S27,250 CUM:$137,570 ETD:S137,570 EFC:$943,000 RIH W/ RTTS MW: 8.5 SEAWATER CLEANED OUT FILL TO 11692', CBU & POOH, RIH W/ RTTS & CLOSING FINGERS TO 2580' TESTED CASING TO 2500 PSI, CONTINUE RIH W/ RTTS. DAILY:S37,209 CUM:$174,779 ETD:S174,779 EFC:$943,000 SQUEEZING CEMENT MW: 8.5 SEAWATER RIH W/ RTTS TO 11300', TEST 9-5/8" CASING TO 2500 PSI, POOH, RIH W/ 2-7/8" TUBING STINGER TO 11689', PUMPED 36 BBLS OF 15% HC1, FLUSH AWAY, SPOT 275 SX CLASS G @ 15.8 PPG, POOH 15 STANDS, BEGIN SQUEEZING CEMENT. DAILY:S36,698 CUM:$211,477 ETD:S211,477 EFC:$943,000 DRILLING OUT CMT MW: 8.5 SEAWATER SQUEEZE 8.75 BBLS CMT INTO FORMATION,..POOH & LD 2-7/8" TUBING STINGER, CHANGE OUT 9-5/8" PACKOFF & TEST PACKOFF TO 3500 PSI, RIH W/ 8-1/2" BIT TO CLEAN OUT CEMENT. DAILY:S65,674 CUM:$277,151 ETD:S277,151 EFC:$943,000 DRLG CEMENT MW: 8.5 SEAWATER DRILLED CEMENT FROM 11,111' TO 11,265', TESTED 9-5/8" CASING TO 1000 PSI FOR 15 MINUTES - OK. CONTINUED DRILLING CEMENT SUPV: ~R/RO I TO 11,513'. The above 'i.~correct / AIL · ~ 32- 775 CUM: $309f 926 ETD:~309f 926 EEC :~943t 000 ~ / ;' ~,D Y.~ , I ForUm preparation a~ distribution/ - ' see Procedures Manual, Section Drilling, Pages 86 and 87. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentialty. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until finaJ completion· Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following se[ting of oil strin~ until completioe. District Field PRUDHOE BAY Date and depth as of 8:~ a.m. 11/17/88 ( TD:11860 PB:l1750 SUPV:RB 0 ARCO ALASKA INC. ICount~hSLO~g Complete recc~.'[t(~"[~tayJ~i[~ d%illing or workover in progress 11/18/88 ( 10 TD:l1860 PB:l1750 SUPV:RB O 11/19/88 ( 11 TD:l1860 PB:11750 SUPV:RB 0 11/20/88 ( 12 TD:l1860 PB:l1750 SUPV:RB O FuuH W/ BiT t-~: 9.5 SEAWATER DRILL OUT CEMENT F/ 11513'-11642', TEST SQUEEZE TO 1000 PSI, DRILL CEMENT TO 11691', PUMP SWEEP, DISPLACE HOLE W/ TREATED SEAWATER, POOH W/ BIT. DAILY:S31,652 CUM:$341,578 ETD:S341,578 EFC:$943,000 IWell no. RIH W/ DP MW: 8.5 SEAWATER POH W/ 3-1/2" DP. RU DA AND PERF W/ 4" GUNS 4 SPF AT 11589'-630', 11516'-32', 11450'-60'. RAN TANDEM 8.5" GR TO 11600'. MU AND RAN BAKER "DB" PKR AND TAIL ASSEMBLY ON WIRELINE AND SET PKR AT 11542'. RD DA. RIH W/ 3-1/2" DP. DAILY:S77,247 CUM:$418,825 ETD:S418,825 EFC:$943,000 RIH W/ 4-1/2" TBG MW: 8.5 SEAWATER RIH W/ DP, POOH LDDP, RIH W/ 4-1/2" COMPLETION ASSEMBLY. DAILY:S36,436 CUM:$455,261 ETD:S455,261 EFC:$943,000 TESTING ANNULUS MW: 8.5 SEAWATER RIH W/ TBG, STING IN SEAL ASSEMBLY, SPACE OUT, LAND TBG, SET PACKER, SHEAR PBR FREEZE PROTECT W/ DIESEL, TEST ANNULUS TO 3000 PSI. (CAMCO 'BAL-O' SSSV @ 2191', BAKER 'HB' & 'DB' PKRS @ 11300' & 11542', & TT @ 11572'.) DAILY:S27,250 CUM:$482,511 ETD:S482,511 EFC:$943,000 The above is cor~ct j / SignaturV /,,~/ / /_ / JDate / / Title / seOer ~,Or~mce%ruerPe%r~li~ua~'~edcit~b~,on -- '/~ I I, - .--/ Drilling, Pages 86 and 87 AR3B-459-2-B I Number all dally well history Iorms consecutively las they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code District ~State ' ARCO ALASKA INC. I AK County or Parish NORTH SLOPE Lease or Unit PRUDHOE BAY ADL: 28329 DS 5-8 T t e WORKOVER Auth. or W.O. no, AS2670 Well no. API: 50-029-20248 Operator A.R.Co. W.I. ARCO 21.0000 Spudded or W.O. be~n Date ACCEPT 11/08/88 Iotal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well Prior status if a W.O. our 1530 ERS [:)ate and depth as of 8:00 a.m. 11/21/88 TD:l1860 PB:11750 SUPV:RB Complete record for each day reported WESTWARD RIG 1 RIG RELEASED MW: 8.5 SEAWATER TEST ANNULUS, INSTALL TEST PLUG & TEST TREE, TEST PLUG STUCK, FISH TEST PLUG, FREEZE PROTECT TUBING, SET B?V, RELEASE RIG @ 2400 HRS 11/20/88. DAILY:S325,617 CUM:$808,128 ETD:S808,128 EFC:$943,000 Cid TD I New TD Released rig Date Classifications (oil, gas, etc.) Producing method Potential test data PB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day ,.. , Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity /(llowable Effective date corrected Theaboveiscor~,ct / / / sFe°; f~;o~ e~ruerPe~r al~ia°nnu aaln, ds ed ic~l r~ nb u~/0°,n' ~ ~ -- Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. DIvlNon of AtlantlcRIchfteldCampany ADDENDUM WELL: 11/07/88 5-8 RU DA, tst lubr to 3500 psi. RIH w/jet cutter, cut tbg @ 10,454' POOH, RD WL , · Dr~~illing $u DEC 1 9 i988 Alaska Oil & Gas Co'q:,;. Commissiori A~chorage ! D~te ARCO ALASKA, INC. F'.O. BOX ANCHORAGE, ALASKA 99~,~ DATE: tl-28-88 REFERENCE' ARCO CASED HOLE'FINAL3 l-2S 't0-St588 COLLAR 5-8 .ti-t7-88 COLLAR 5-8 tt-t7-88 COLLAR/PERF F'WDWt-t tt-5,6--.88 TEMP F'LEA3E SIGN AND RETURN THE ATTACHED COPY A~-;' RECEIPT OF HAVE A NICE DA1" 19~8 AT0- i '52,6.` T,",^i,a,'" "R" ' /~ * r', M.'~ a- ~-,_~o7 t AF'PROVED D I :'..7 T R :£ B U'f' I 0 N · ,,-CENT!:;..'A~:_ FILE.";' ¢,- CHEVRON D & M " ~ EX'f'EN,~" :[ ON EXPLORATION ~ EXXON MARATHON 41o · ,,- MOBIL PI-.tl LL l P£' PB WELt.. 'F'II_LE.'-]' 1:;.'. t':~ D <:' ": "1'~. .?TATE OF' ALA~*KA TEXACO RUN i , RUN i, RUN t , RtJN' i , D A'/"A. A'i'I_A~. ATLAS.' CAMCO .... STATE OF ALASKA A D-,,.,KA OIL AND GAS CONSERVATION COMMISoION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ / Operation shutdown __ Re-enter suspended well__ · Alter casing ~ Repair well v' Pluggi0g __ Time extension __ Stimulate ~ Change approved program __ -- Pull tubing -,/- Variance __ .~/¢_~Perforate v/ Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ A i~ C n fl I ~. I~ ~; I n n _ Exploratory ~ R K R R 4 * 3. Address Stratigraphic ~ 7. Unit or Property name P. 0. Box 100360, Anchorage~ AK 99510 .0360 Service__ Prudhoe Bay Unit feet 4. Location of well at surface 2428' FSL, 234' At top of productive interval 1398' FNL, 1595' At effective depth 1791 ' FNL, 1319' At total depth 1841 ' FNL, 987' FWL, Sec.32, T11N, R15E, UM FWL, Sec.6, TION, R15E, UM FWL, Sec.6, TION, R15E, UM FWL, Sec.6, TION, R15E, UM 12. Present well condition summary Total depth: measured true vertical I 1 860 ' M D feet Plugs (measured) 9237'TVD feet 8. Well number 5-8 9. Permit number 77-24 10. APt number 50-- O29-20248 11. Field/Pool Prudhoe Bay Fi eld 11645' (after CTU squeeze) Effective depth: measured true vertical 11 750 ' HD feet Junk (measured) 91 65 'TVD feet Fish @ 11,740' Casing Length Structural Conductor 8 0 ' Surface 2 71 0 ' Intermediate Production 1 1 81 6 ' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured depth 20" 224 sx AS 13-3/8" 5000 sx AS True vertical depth 1 09 'MD 1 09 ' TVD 2733 'MD 2733 'TVD 9-5/8" 1200 sx Class G 11837'MD 11351'-11385', 11400'-11420', 11440'-11459' 11482'-11530', 11550'-11580', 11590'-11620' 8904'-8926', 8935'-8948', 8961'-8974' 8988'-9019', 9032'-9051', 9057'-9077' 5-1/2" L-80 tubing w/tail @ 10553' , , Packers and SSSV (type and measured depth) Brown RHR pkr ~ 10460' Camco SSSV ~ 2227' 9222 'TVD 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: I October 10. 198~ 16. If proposal was verbally approved Oil __v'/ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct t° the best of my knowledge. Signed <~/~/)/,,.,' ~./,/).bk., Title A.~.~t3c. iate F'noineer Date 10-7-~ ~ FOR COMMISSION USEONLY - Conditions of approval: Notify Commission so representative may witness ( J c ) s A / 0 0 5 5 I Approva No. Plug integrity __ BOP Test __ Location clearance __ / . /~ I Mechanical Integrity Test_ Subsequent form required 10-~;/~:: 7 .~pproved Copy ORIGINAL SlGNEB BY Returned Approved by order of the Commissioner~ ,LONN.tE C. SMITH / ~ ¢//~-~ ~,,~ ...... · ~_j_ ~ ...... ] __ ~missioner Form 10-403 Rev06/15/88 Fo~ No. / 0~ L~0[~ Dated 1 /~~ Date SUBMIT IN TRIPLICATE DS 5-8 (PRODUCER) WORKOVER PROCEDURE SUMMARY Objective The objectives of this workover are to pull the existing 5-1/2" tubing and leaking retrievable packer completion assembly, cement squeeze all existing perforations, clean out the well to PBTD, reperforate productive intervals, and replace a leaking 9-5/8" wellhead pack-off. A 4-1/2" straddle packer completion assembly will be installed and will incorporate a single, 3/8" OD corrosion inhibition treater string. 1. RU electric line. RIH w/4.50" OD gauge ring and junk basket to +10500'. POOH. RIH w/4.378" jet cutter and cut tubing at +10~455' in pup joint above packer. POOH. RD EL. 2. MIRU WWI. ND tree, NU BOPE and test. Circulate crude out of tubing and annul us and kill well wi th seawater. 3. MU spear for 5-1/2" 17# tubing on 3-1/2" DP and engage first full joint of tubing below tubing hanger. POOH. LD hanger, tubing, and PBR. 4. MU 5-1/2" tubing overshot on 3-1/2" DP and RIH. Engage cut joint of 5-1/2" at +10455' MD. Rotate DP to the right to release BOT 'RHR' packer. POOH, LD pkr and completion assembly. e RIH w/8-1/2" cement mill and clean out 9-5/8" casing to 11705'MD. Circulate bottom up. POOH. 6. MU 2-7/8" cement stinger on 3-1/2" DP and RIH to 11705' MD. Mix and spot 275 sx Class 'G' cement and additives. POOH to ±100' above TOC'.~ Close annular preventer, squeeze ±20 bbls cement into perforation at 11351' - 11632' MD. 7. POOH. LD 2-7/8 tailpipe. 8. MU FMC pack-off retrieving tool and RIH. Engage 9-5/8" mandrel pack-off and pull same. Run and test new 9-5/8" Gen I pack-off. 9. MU 8-1/2" cement mill on 3-1/2" DP and RIH. 10. Clean out 9-5/8" casing to ±11300' MD. Test 9-5/8" casing to 2500 psi. 11. Clean out 9-5/8" casing to 11650' MD. 11351'-11632' MD to 1000 psi. Test squeezed perfs 12. Clean out 9-5/8" casing to 11705' MD (PBTD). POOH. 13. MU 8-1/2" bit and 9-5/8" casing scraper and RIH to PBTD. Circulate and displace hole with inhibited seawater. POOH, LD DP. DCS/012.2 DS 5-8 (PRODUCER) WORKOVER PROCEDURE SUMMARY (Cont'd) 14. RU electric line. RIH w/5" OD casing guns and perforate 11450'-11460' MD, 11516'-11531'MD, and 11589'-11630' MD, 4 spf, 90° phase. POOH. 15. MU 9-5/8'l permanent isolation packer with pumpout plug in tailpipe on electric line and RIH. Set packer at +11540' MD with tailpipe at _+11565' MD. POOH, RD electric line. 16. MU 4-1/2" blast joints, two GLM's, and seal assembly below a 9-5/8" x 4-1/2" retrievable packer and RIH with 4-1/2" production tubing equipped with a 3/8" corrosion inhibition treater string and two GLM's. 17. Land seal assembly in isolation packer. Space out and land tubing hanger. Pressure tubing to set upper packer. Pressure test tubing to 3000 psi and annulus to 2500 psi. 18. PU tubing to shear PBR seals. Re-land tubing and install BPV. 19. ND BOP's, NU tree and test to 5000 psi. Retest tubing and annulus to 3000 psi and 2500 psi, respectively. 20. Pressure tubing to shear pump-out plug in lower packer tailpipe. 21. Release rig, turn well over to Production. Anticipated BHP = 3700 psi @ 8800' TVD (8.1 ppg EMW) Workover Fluid = 8.5 ppg seawater DCS/012.4 ANNULAR PREVENTER 6 PIPE I AHS BLIND RAMS 4 TUBIN6 HEAD 2 1. 13-3/8" CASING HEAD 2, 9-5/8" CASING HEAD 3. 5000 PSI TUBING HEAD 4, 1;5-5/8" - 5000 PSI BLIND RAMS 5. 1:3-5/8"-5000 PSI PIPE RAMS 6. 1;5-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 .CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS ;3000 PSI WITH 1500 PSI DOWNSTREAH OF THE REGULATOR. ;5. OBSERVE TIME, THEN CLOSE ALL UNITS SIHULTANEOUSLY AND RECORD THE TIME AND PRESSURE REHAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TI~$T 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, ;5. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE HANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSi. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAHS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. §. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED HANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAH OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN PIPE RAHS. BACKOFF RUNNING dT AND PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAHS AND RECOVER TEST PLUG. HAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSi WITH KOOMEY PUMP. 1;5. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. d6 NOVEMBER 21, 1986 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, A~aska 99510-0360 Telephone 907 263 4248 Donald F~ Scheve Operations Engineering Manager September 30, 1988 C. V. "Chat" Chatteron Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak., 99501 Subject: DS#5-8 Permit No. 77-24 Dear Mr. Chatteron: Attached is the Application for Sundry Approval to continue production from Well 5-8 until a workover in November 1988 can repair a packer failure. Very truly yours, D.F. Scheve attachment cc: Standard Alaska Production Co. L.L. Gantt, ATO 1520 T.V. Marshall, ATO 1570 T.A. Billingsley/M.A. Lucich, PRB 24 T.G. Zibell/L.J. Sennett, PRB 24 PRB Files (5-8) Oper. Eng. Files (5-8) ARCO Alaska, Inc, is s Subsidiary of AtlanticRichfieldCompany ^R3B --6132-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon -- Suspend ~ Operation Shutdown ~ Re-enter suspended well E] Alter casing iL Time extension _2 Change approved program ~ Plu'gging ~ Stimulate ~ Pull tubing '-- Amend order Lq Perforate ' OtherX] 2. Name of Operator Arco Alaska, Inc. 3. Address P.O.Box 100360 Anchorage, Ak., 99510 4. Location of well at surface 2428' N and 234' E of SW cr of Sec 32, TIIN, R15E, UM At top of productive interval 1398' S and 1595' E of NW cr of Sec 6, TION, R15E, UM At effective depth At total depth 1841' S and 987' E of NW cr of Sec 6, TION, R15E, UM 5. Datum elevation (DF or KB) 64' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 5-8 8. Permit number 77-24 9. APInumber 50--02~-20248 10. Pool Prudhoe Bay Oil Pool feet 11. Present well condition summary Total depth: measured 11860' true vertical 9237' Effective depth: measured 11750' true vertical 9165' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length 109' 2733' feet Plugs (measured) feet 11837' feet Junk (measured) feet none Top of dummy gun - 11740' Size Cemented Measured depth ~ue Verticaldepth 20" 224 Sx 109' 109' 13-3/8" 5000 Sx 2733' 2733' 9-5/8" 1200 Sx 11524 - 11534, 11568 - 11630 11837' 9222' true vertical 9017 - 9086 (.2 intervals) ~bing(size, grade and measured depth) 5-1/2", L-80, 17#, 10542' Packers and SSSV(type and measured depth) BOT RHR packer at 10460, Camco Bal-0 SSSV at 2227' 12.Attachments Description summary of proposal Y~X Detailed operations program [_-J BOP sketch 13. Estimated date for commencing operation Continue producing well until workover in November 1988. 14. If proposal was verbally approved Name of approver Mike Minder Date approved 9-29-88 15. I hereby/~ertify tha/t, Tth,e, foregoing is true and correct to the best of my knowledge Signed ,~'/,~~/'~,~_~ Title Operations En~ineerin~ Manager Commission Use Only Date Conditions of approval Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance ORIGINAL SIGNED BY Approved Copy Returned / ¢ %t/ ~_ ~-~ -- -- [ ApprovalNo. by order of ,.~,~ the commission Date Approved by LONNIE O. SMITH Commissioner _ .. PRODUCTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC DATE' TIME- /~Sbo hrz.~ NOTIFIED BY: JO~n'~ ~'er~c~ AOGCC CONTACT: Mike Minder REASON' Production Well '~'-"~ Annular Communication Per Alaska Administration Code Title 20 - Chapter 25 Sundry Notice Req'd at this time? YES ),/ PRODUCTION SUPPORT SUPERINTENDEN! NO Original to,M.A. Lucich/T.A., Biilingsly - PRB 24 xc: Production Support Superintendent (P.Pierce/E.W. Skaalure) - PRB 20 Sr. Wireline Supervisor (K.M. Kennedy/W.S. Wilder) - PRB 20 Field Area Operations Engineer (L. J. Sen, nett/T. G. Zibell)/ PRB 24 DS Supervisor - FS # / ...... w'/1?.v.¢~,~//Cz,, e z4 FS Superintendent- FS # ~ ,, _ / '"~ DS Engineer - ATO /5'-.,4"~' /~, $. A'eg'~,J ~ Revised 9-29-88 I-i,'.':", "." I= .~.":', i'-J T {": !::' f..., ,...-:., y ,~ I~ O F:' - t- ~ .... i:~ t:- i'9 t'q ~= ~ ...... ? .... 'TT ~ Alaska Oil & 6as Cons. Commission · r r'~ ..'-. :: I '.''~ '"' ;'"' I::: 7-[ 9,':' g ' ~ ¢". I.'t J*'..". ,::'.', P !::' [:;: ri ',,/f:' i"). f"., i' 5.' 'T' i-;: T i;:: ~ i T !' f",, ig ARCO AI..A,~'KA. I~N~ ANCHORAGE, AI..A371(A DATE' REFEF.'FNCE' AR'CF] CA.~ED HOI F FTNAI H A V E A N 3-% 9-.'27-RR COl. I... A F,' ,/F:' E B' F Fl F-;.' A T T f'!N F;.'I IN 3-8 I I -?-~7 fir1!. I.. AR'/F'FR'Ff'IRATTON RI. N :'~-i % I 1 o R7 CI51 ^-'/ _ .. -.: - ..l...~R F'FR'ICfqR'ATT[]N Fl'lIN 4-?. C-., 1 ~-g-I 9-R7,. Cl]l.. I...AR/'F'FR'FQI:,'AT T Oi',J 171 IN 5-R t O-.".~'i -,°,'7 I]I'll...I...AF,'/F'FF,'FI]R'AT'( lIN Fi'I IN ,.z,. _,.=, 9-,'2.8-8'7 COl I. AR' ./F'[-:-F:FFIF,'AT '[ i]N I;:1 IN .5 - ~.3 '~ 6) - '1 - ,q.., '7, C fi I .. I... A Et/' F' F' R' F' Iq F;,' A T '[ fi N F;:I I i~ 6-'~ 3 f 0-'~ -,q'? F'..FII. I...AF,.',.'F'FRI=nR'ATT ~]N R'I IN .5--~ ,-" 9-~4-~? COl.! .AF,'/"F't-]F;.'FF!Fi'AT 7[ i']i9 E't.lig 6-,9.,'2.. 'i (-)-1 -87 COl I..AR,,'F'FF,.'FF1RATTON RIIN 6 - ] 2 ~ (.) - ..'? ~, -- P,'7, C7, [tl I.. A R' / I::' Fi] F:,i F 0 F? A T T. 0 N r.;,,, t I i,~ .6- ,?. ~ ,i,A, - .,:") ,.~_ o w.., ,., , COl. [ AF,.'/F'FRFFIRATTIqN. I;,'11 N 9-~ ~ ®-R'-~'7 C..DI. !.. AR'/F'F-.PF F1F,'A T I ['IN r-;:l F'I...FA,?TE &'TI.;N AND t:;,'~l~;i~,~'Thl I:"¥ FII: DATA _ ]' F'~ t t t t 1. 1 F'F(],G Y BFNJNFTT A'T r] 1 ..... 9 'T F.'A N .? ~ R ,q .i A P, ~ A F' F' F,.'O V F. 0 ~) ............. ~ 17.~TR'T RI IT T F]N CENTRAl... F T I..E.? [.'. H .F.- ",/P.' 0 N D ~ M EXTEN,~T ON EXF'[ OPATTFtN EXXON MARATHON MOBIl_. -~ F' H '[I I.. T F' }7 F'R LJFI. I F".rl F,? Ii' &. O '"' ,% A F' f7 ~ STATF rIF AI.A,?KA -~ T F' ',( A Fi r] 99% i DATF' Z-~Q-8~ ARCO CA2ED 14gI.F FTNAI F'I FA?.F ? H A V F A N P. gl I.AR COl I AR/F'FRFORATTON P.,Fll.. I.. Al-7/F'FRF/!RAT T C~I.. I.AR/F'~RF~RATTON CO!..I AR,/F'FPFQRATTQW CO/ I. COl .! Chi .t... AR/F'ERFnRAT ~ ON Cgl..t. AR/F'F~'FORAT T r]f.; nh/. I. AR/F'ERFO~'AT T ON call R~I t..AR/F'FRFORA'T]'ON C[]I_I AR/PERF'[/RAT T FIN F' F f: F; Y T~ I::' H N E' T T A'T~I- t., ~79 'D '[ ,? 'T R T RI IT T Fl N R'I Ikl RI. IN F,'I IN RI IN R'I IN F;.'I IN RI IN I~.'i IN F.'I IN RI.IN 171 IN I-7! ~N RI I/,J T) A T A. C F H T 1~.' Al... !::' T I.. tE ,? C la E- V R' ('/N O ,~ EWTEN,?TON EXF'I OR'ATTFIN MARATHON Mf]glI '"'-.-F' H '[ I.. I.. '[ F' .~ '~ F'R kiel I. FTI. F,',7 R .,. T) ~ .?APP. "'"'~" ~TATF FII:: Al A.?KP, ~ TFXAP. F/ ARCO Alaska, In¢~ ' Prudhoe Bay Engineering Post Office Box 100360 Anchorage~ Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 21, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 5-8 Permit No. 77-24 (22-6-10-15) Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DMF/jp Attachment cc: Standard Alaska Production Company Pi(DS 5-8)W1-3 RECEIVED SEP 2 2 .Alaska 0il & Gas Cons. Commission Anchorage WELLS/127 ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE Of ALASKA ALA,..,~ OIL AND GAS CONSERVATION CCI, . .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension E] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order Perforate ,,~ Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2428' N & 234' E of SW Cr. of Sec. 32, TllN, R15E, UM At top of productive interval 1398' S & 1595' E of NW Cr. Sec. 6, T10N, R15E, UM At effective depth At total depth 1841' S & 987' E of NW Ct. Sec. 6, T10N, RI5E, UM 5. Datum elevation (DF or KB) 64 ' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 5-8 8. Permit number 77-24 (22-6-10-15) 9. APl number 50-- 029-20248 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11860 feet Plugs (measured) 9237 feet Effective depth: measured 11750 feet Junk (measured) true vertical 9165 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 20" 224 Sx AS 109' 109' Surface 13-3/8" 5000 Sx AS 2733' 2732' Production 9-5/8" 1200 Sx 'G' 11837' 9221' Perforation depth: measured 11351-11385'; 11400-11420'; 11440-11459'; 11482-11530'; 11550-11580'; 11590-11620' true vertical 8904-8926'; 8935-8948'; 8961-8974'; 8988-9019'; 9032-9051'; 9057-c~'~[/*~iv~''u Tubing (size, grade and measured depth) 5~" , , 2 , 17# L-80 PC tubing @ 10553' MD SF~~ 2 2 ~l~Jb/ Packers and SSSV (type and measured depth) .BOT RHR packer @ 10460' MD; Camco Bal-0 SSSV @ 2227' MD ~,o~noil&Gas(:;0,s. C0mmisslo[~ 12.Attachments Description summary of proposal J~ Detailed operations'~r'~r--am ~l~g~Elketch~(] 13. Estimated date for commencing operation October 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby./~tify that,7~e f.~~ correct to the best of my knowledge Signed 4~c/¢"~~___~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness I ~pprovaINo. [] Plug integrity I-q BOP Test [] Location clearance Approve~ Imum, e.g~ :t.: :; :~:~ ~: ~: ;~: Commissioner Approved by by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate WELLS/127 D. M. Fife. ATO-1510, 263-4278 DS 5-8 Coiled Tubing Unit Cement Squeeze Workover AFE #797022 Property Code - 2120828 Procedure 1. Fluid pack the 9-5/8" annulus. 2. RIH with coiled tubing and clean out fill to 11700' MD. 3. Shoot squeeze perfs from 11620-11630 MD. (Ref.: BHCS 7-4-77). Flow and test the well. 4. RIH with coiled tubing. Wash perforations with half strength mud acid. Flow well to produce out all the acid. 5. RIH with coiled tubing and fluid pack the wellbore with filtered seawater. 6. Pump 60 bbls of cement followed by 2 bbls of water and 130 bbls of contaminant. Hold 5100 psi squeeze pressure for 60 minutes. 7. Jet or reverse out the contaminated cement. Displace out the water and load the wellbore with diesel. 8. Perforate as follows: 11510-11534 (Ref.: BHCS 7-4-77) 11568-11630 9. Test the well. 6 5 4 3 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYORAULIC SLIPS 4. 5000 PSI 4 1/6" SHE&R RAMS ,5. .5000 PSI 4 1/6" BLIND RAMS 6. 5DO0 PSI 4 1/16" STUFFING BOX I' 1 I i iii i ii CO]LED TUBING: UNIT BOP EOUIPHENT J i i i m 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 WIRELINE BOP EOUIPMENT ARCO ALaska, Inc· P.O. Box t00360 Anchorage, Alaska 99~0 DATE: June 4, ~987 REFERENCE: ARCO Magnetic Tapes w/[is¢itug 2-3 5-44-87 MagTape ~72325 CH CNL Run Sub. Sch 4-3J 5-J6-87 Magtape ~72320 CH CNL Run 2 £ch 5-8 5-4t-87 MagTape ~7~4~ ~ CH CNL Run 6 Sch 6-20 5-4~-87 Magtape ~72~ CH CNL Run 2 $ch JJ-4 5-46-8? MagTape ~7~2~ CH CNL Run 2. $ch F'£ea~e ~ign and reCur~ the attached copy as receipt of data. Received By HAVE A NICE DAY! Ro~amne F'eek ATO-4529F TRAN£ ~8~84 A~ p roved DISTRIBUTION Central Fi [es $ Phi ~tips Chevron PB We[[ Fi [es D & I~ R & I) P~McF'heeTer~ ~ Soh i o ~ ~a~e of Alaska Ex xon ~ ~ara~hon Texaco Mob i [ ARCO Alaska, Inc F'.O, Box 10.0360 Anchorage, ALaska 995~0 DATE: May REFERENCE: t 987 2-3 5-"t 4-87 2-7 5-t4-87 4-~1 5-t6-87 5-8 5- t t -87 7-t t 5-t 4-87 t t --4 5-t 6-87 t5--4 5-t 7---87 t 5-6 5--t 7-8'7 ARCO Cased Hote F ina L CFi CNL CH CNL CFi CNL CH CNL CH CNL CH CNL CFi CNL CH CNL 5 ' 5' Run 2, 5' Run Run i :3, 5' Run 2, Run 2, 5' Run 3, 5' Sc h S c h Sch Sc h Sc h Sc h $ch Sc h I::' [ease ~' i gn and rear urn · ~he a$'tac:hed copy as receip'~ of da'fa, Rec:eived By_.. FIAVE A NICE DAY! Ro~mnne Peek A1'0-~529 /-'"- ~ Alaska Oil & Gas Co (~ ,,a. uommissJon Anchorage I'RANS ¢872725 Approved .. DISTRIBUTION "" Cen*raL Fi Les · "' Chevron T I) & M Ex,en$ ion Exp lorat' ion 'IF .m Exxon Mara 'thon · " Mob i [ T F'h,i [ [ i ps F'B Well Fi les R & D Soh i o '"- S'ta'te of Ataska Te×aco ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date' July 8, 1985 Reference- ARCO Pressure Surveys 5-8 Static Gradient 5-31-85 5-11 Static Gradient 5-31-85 /~15-16 PBU 5- 31-85 //t6-6 PBU 6-16-85 ~16-11 PFO 6-8-85 17-5 PBU 5-29/30-85 .; / Please sign as receipt of data. Otis Otis Camco Otis Camco Camco Received by Pam Lambert ATO 1429C Trans 19 3 Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 D&te' July 8, 1985 R6ference: ARCO CH Finals j2-18 CNL CCL 5-12-85 Run I 5" GO 5- 31-85 5" Otis 5-11 CCL 5- 31-85 5" Otis 14-5 CNL 5-11-85 i 5" GO Please sign as receipt of data. Received by Pam Lambert ATO 1429C Alaska 0il & Gas Cons.Commmsior~' AImhorage Trans 195 Chevron D& M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date' February 22, 1985 Reference' ARCO CH Finals ~l ,. .5-4 F,?ilog Run i 5" 11-14-84 DA ~ Sp~n~e~ I 5'~ 1-28-85 GO /5-8 Fluid Density 1 5" 1-28-85 ' GO ~ 7 - 5__ ~_C~R ........ ~ 5" 1 - 21 - ~ ~A /13-1 CNL 4 5" 8-31-84 Sch Pl~ease sign and return the attached copy as receipt of data. Received by Pam Lambert ATO 1429C Trans#~'~3qi Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil : Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alask, ,, Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 1, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-8 DS 5-8 DS 17-10 Permit No. 75-26 Permit No. 77-24 Permit No. 81-97 Dear Mr. Chatterton: Attached are "Subsequent" Sundry Notices for work proposed on the above-mentioned wells, as well as Completion Reports. very truly yours, D. F. Scheve ! DFS/JB/mjb Attachments cc: Sohio Alaska Petroleum Company File PI(DS 1-8)W1-3 File Pi(DS 5-8)Wl-3 File Pi(DS 17-10)Wl-3 RECEIVED NOV 0 51 4 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA --,, ALAS~ ...~ AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~ OTHER [] Water Injector 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 2428'N & 234'E of SW cr of Sec 32, TllN, R15E, UM (Producing Interval) 1398'S & 1595'E of NW cr Sec 6, T10N, R15E, UM (Total Depth) 1841'S & 987'E of NW cr Sec 6, T10N, R15E, UM 7. Permit No. 77-24 8. APl Number 5O-- 029-20248 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number U.S. 5-8 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKB t ADL 28329 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Chang~ Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 wi(h a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 9/29/84. RU perforating unit, pressure tested equipment. RIH with gun ~1, shot interval 11600' - 11620' MD (4 spf). Shut-in well, POOH, all shots fired. RIH with gun #2, shot interval 11570' - 11580' MD (4 spf); shut-in well, .POOH, all shots fired. RIH with gun #3. Gun misfired, shut-in well, POOH. RIH with gun #4, shot interval 11590' - 11600' MD, 4 SPF; shut-in well, POOH, all shots fired. RIH with gun #5, shot interval 11550' - 11570' MD, 4 SPF; shut in well, POOH, all shots fired. Ran SSSV, secured well, RD. Ref: BHCS 7/2/77 RECEIVED NOV 0 ]98 . Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby,Aertify that the foregoing is true and correct to the best of my knowledge. Signed ,~~'~ Y~ Title Regional Eng~m~er /he space below for Commissio6' use Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ---"-' STATE OF ALASKA .......... ~ '~ ALASF, ,~ AND GAS CONSERVATION ~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~.._,, GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2~ Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-24 ,. 3. Address 8. APl Number ?.0. Box 100360, Anchorage, Alaska 99510 50- 029-20248 4. Location of well at surface 9. Unit or Lease Name 2428' N & 234'E of SW cr of Sec. 32, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1398'S & 1595'E of NW cr of Sec 6 TION, R15E, UM DS 5-8 At Total Depth 11. Field and Pool 1841'S & 987'E of NW cr of Sec. 6, T10N, R15E, UM Prudhoe Bay Field , ~. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKB ADL 28329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. N~. of Completions 6/8/77 6/29/77 7/4/77 '- feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11860' MD 9237' TVD 11750' MD 9165' TVD YES~ NO[] 2226 feet MD 1900' (Approx.) -. 22. Type Electric or Other Logs Run DIL/SP/BHCS/OR, FDC/CNL/OR/CAL, GR/CNL/CCL, CCL/GR '~23. CASING, LINER AND CEMENTING RECORD .... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,,, 20" 94# H-40 Surf. 109' 32" Cmtd w/224 sxs Arctic et cmt 13-3/8" 72~ MN-80 Surf. 2733' 17~" Cmtd w/5000 sxs Arctic Set cmt 9-5/8" 47# MN-80 & Surf. 11837' 12¼" Cmtd w/1200 sxs "G" cm! L-95 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11482- 11530' MD 5~" 10542' 10449' 11440 - 11459' MD 8899-9076' TVD 11400 - 11420' MD 26. ACID, FRACTURE, cEMENT SQuEEzE, ETC. 11351 - 11385' MD w/4 shots per ft. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED *11550- 11570' MD *11570 - 11580' MD * Added on 9/29/84 *11590- 11600' MD Ref: BHCS 7-2-77 *11600 - 11620' MD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 1-20-78I Flowing 1' DateofTest Hours Tested PROD. UCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10-23/84 4.0 TEST PERIOD I~ 400 609 0 14 1521 Flow Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1729 1450 '24-HOUR RATE I~! 2402 3653 0 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Nov 0 Alaska Oil & Gas Cons. Commission Ar~chorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30.. ' ' : GEOI"0GI'c MARKERS '- ' ' · ' FORMAT-ION T'ESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10883' MD 8614' TVD Base Sadlerochit 11747' MD 9163' TVD 31. LIST OF ATTACHMENTS -- 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~Z~ .... Title Regional Engineer 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". ~.~I-,,L,L A ~..'.~::-.:ka, Inc ,. P,. 0., Box '10(:,',S60 /-. ..... r-~ ~'~,.. h o y' a ,:.:j e, A La.~ka 995~ ~ D A T E ' 0 (:: i: c..', I", e r .a t '.;' 8 4 R Iii] F' Ii'.':. F;,' E N C liE. · A R C 0 C: a :!!: e (.t Hot. e F'inal.:~!: ':"' -'-'::' ~ ':':;' .... 2':::' ':::' -.:'.'- C o I. I. a 'r ,." P ~::, y' f I... ,':; D ,. ,~.i!., _.:.--. ,. .... · .... ,. ............ D., ,? ,. 7.-. 7.'; :ii!: .... i S.... ii!: 4 C o m I:' I. e t.- i o n R e (:: ,.':.', y' d D ?:,' '?....,-I- '- o, ..... i 'i ..... ':' ,. , ,_ .... ~.:.. 4 C Iii] "l' t.. o ,'.:i.. ,-"' C: a I. i p e r L. ~",.. g 0.: ;!i:.,t 6..--B 9.--28.---84 D i fferen'~' i .:'~ I. Tempera '~' u'r'e )} ,. ~.;' ,. i 6"" S 9 28 .....': D f 'f" e 'r' + i a I. '¥'e u.'r .... .. (::, 4 i ('}) 't"t . i'l'l I:;' e '1" .~;i t.' e ¥) ;:..i: i '? .... t ,':','x 9 .... 2 '-'"- "-- !ii: 4 ~"'.' ;", I. I. a '~" / F:' e 'r' 'I"' t... "; ;:i .. o-. ;. ..'.J : ....... .. ........... ii: i g 'r'~ .:'.:~ y'~ d 'r' ,:..:-:, t: ~.~ y y': 'l: h e ...?l i...t: .::] c: h ,:.{..', d (:: o t::' Y .~:~ :ii: y' e ,.':: ,':-.', i I::' t: I.-IAVE A NIC:lii: DAY! Alaska Oil & Gas Cons. Commission i..':i e t. t. y H,::: F:'.:':~ y' L ...'..': n,::t ATO .... t429F:' ]" R A N ;ii: ,. :II: S 80 I::' II R ~..t 'n 2 ...> ;?; c h F:..' u n i 5" [;i]' R u n 'i :.:.:,':" [; 0 i) I ,:; '1" I:;.'. I B U"F ]: 0 N I::' i I. e !!; ARCO Alaska, Ir Prudhoe b~.~ Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer August 17, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 5-8 DS 17-3 Permit No. 77-24 Permit No. 80-77 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/mjb Attachments cc: Sohio Petroleum File Pi(DS 5-8)W1-3 File PI(DS 17-3)W1-3 ARCO Alaska, inc. Is a Subsidiary of AflanflcRIchfleldCompany ...~- STATE OF ALASKA ..... --- ALASt .,,~. AND GAS CONSERVATION .AISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L L ::1~ OTHER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of We~l (Surface) 2428'N & 234' E of SW cr of Sec. 32, TllN, R15E, UM (Producing Interval) 1398'S & 1595'E of NW cr Sec 6, T10N, R15E, UM (Total Depth) 1841'S & 987'E of NW cr Sec 6, T10N, R15E, UM Elevation in feet (indicate KB, DF, etc.) 64' RKB 6. Lease Designation and Serial No. ADL 28329 7. Permit No. 77-24 8. APl Number 5O-- 029-20248 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 5-8 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stim ulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 5-8 at selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up .operation. Proposed Perforation Intervals: 11550' - 11580' MD (30') 11590' - 11620' MD (30') Ref: BHCS 7/2/77 Subseqt~ent Work Reporter] ' RECEIVED AU(: 2 i Alaska 0il & Gas Coils. Commission Anchorage 14. I herebyA'~rtify that t[~ foregoing is true and correct to the best of my knowledge. Signed ....... Title Reg±onal Engineer The space below for Commission use Conditions of Approval, if any: IlfliGiN^L StG~IED Ii1' LOlttll[ IL SI~llTIt Approved by_ COMMISSIONER Approved Copy Returned , .... ..... By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 14, 1984 Reference: ARCO Cased Hole Finals f D.S. 1-21 5-4-84 ,-D.S. 1-25 5-26-84 ~-D.S. 2-17 3-28-84 ~D.s. 3-13 5-21-84 ,-D. S. 3-27 5-18-84 ,~D.So 4-1 5-6-84 ~D.S. 4-4 5-14-84 ~D.S. 5-8 ~-5-84 ~D.S. 6-4 5-30-84 ~-DcS. 7-20 4-18-84 ~D.S. 12-16 5-20-84 ~D.S. 9-4 5-7-84 ~D.S. 7-25 4-22-84 ,-D.S. 7-22 4-20-84 ,~D.S. 12-18 6-1-84 ,~D.S. 12-23 5-19-84 ~D.S. 14-2 5-3-84 ~-D. S. 14-25 5-18-84 ,~D.S. 14-32 5-20-84 ~,D.S. 14-34 6-5-84 ~,D.S. 17-1 5-24-84 Epilog Spinner Log Spinner Log/Basket Flowmeter CFS/Spinner ACBL/VDL/Signature/GR Epilog CH CNL Epilog CP1/TDT-M w/listing Spinner PLS Epilog Spinner Spinner CPL/TDT,M w/listing ACBL/VDL/Signature/GR Epilog CFS/Spinner CFS/Spinner CPL/TDT-M w/listing Collar/Peri Log ' P~lease sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Run 2 5" DA Run 1 5" Camco Run 2 5" Camco Run 1 5" GO Run 1 5" DA Run 2 5" DA Run 1 5" GO Run 1 5" DA 5" Sch Run 1 5" Camco Run 1 5" DA Run 1 5" DA Run 1 5" Camco Run 1 5" Camco 5" Sch Run 1 5" DA Run 3 5" DA Run 1 5" GO Run 1 5" GO 5" Sch Run 1 5" GO Kelly McFar land ATO-1429F Trans. # 242 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 6, 1984 Reference: ARCO Cased Hole Finals P.S. 1-26~ 5-17-84 P.S. 2-17 ...... ' 5-12-84 P.S. 4-1 5-6-84 P.S. 5-8-- 5-5-84 P.S. 6-18~ 5-22-84 P.S. 9-4 f.~ 5-7-84 P.S. 9-6~ 5-7-84 P.S. 12-17~ 5-14-84 P.S. 12-23.~' 5-16-84 P.S. 13-34 5-17-84 P.S. 13-98' /5-16-84 P.S. 16-13j- 5-20-84 P.S. 17-7/~' 5-25-84 P.S. 17-10 ~"~5-18-84 P.S. 17-10 '~ 5-18-84 P.S. 18-3-~ 5-14-84 Collar/Perf Log Run 1 5" 'GO Collar Log to set Casing Patch Run 1 5" GO CN/MSN/GR CN/MSN/GR CPL/TDT-M w/listing CN/MSN/GR CH CNL CPL/TDT-m w/listing Run 2 5" DA Run 1 5" DA 5" Sch Run 1 5" DA Run 1 5" GO 5" Sch X-Y Caliper Log w/Borehole Volume Run 1 5" GO CPL/TDT-M w/listing CH DIL Collar/Perf Log Collar/Perf Log CET Log CCL/Perf Record Temperature Log 5" Sch Run 12 5" Sch Run 1 5" GO Run 1 5" GO Run 1 5" Sch Run 1 5" Sch Run 1 5" GO aseand return the attached of data. sign copy as receipt Be PATRIOTIC[ - Hang out your flag on the 14th. Kelly McFarland ATO-1429F Trans. #231 DISTRIBUTION 'Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 16, 1984 Re ference: ARCO Magnetic Tapes w/listings ~:..i,~./ .... -' -z+-2 O- S 4~M.--An. swer~ 9T5 9 Sch D.S. 1-9 ? .... 4-20-84 TDT-M #69158 Sch ~Z 9:~ :-:4-::2~ ~&~:-~od~~nma~' Average" ~resenta~ zon Answe~ #69161 Run' 2' Sch /D.S, 12-9~ 4-22-84 _TDT/5 passes of TDT-M #69160 Run 2 Sch ~' .-_'E-~: ....... :..~-~~~E Averag~:~roduct Answer #69163 Run 2 Sch ~.~2~~~2-~:~T~T~5~.~~ ~~-M #69162 Run 2 ~ ~:,:::;::,: 5-5:8~ 3 Rass~s CN/M~N w/CN Average #1964 DA ' / ~,~ 7, i~zi ., ~~ - ~pa~ge~'- CN/MS'~~N-Average--~1963 .... DA ~'. ~ ~ 4 ~2~., ~5- 3 ~8 ~' ~ ~~~ej~=~. w'~ve r a g e # 1 ~ DA D. S~ 5; 1 i:8~ CH CN~2~ 1 ?-~~ " Please si8n and return ~he attached copy as receip~ o[ data. Kelly McFar land ATO-1429F Trans. #173 Chevron D&M Have a Nice Day! DISTRIBUTION ,q/as/fa 0il Mob il . ~G.~S Cons. Corn~iss/o/~ Mobil E & P ~nuhorage Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Phillips Prudhoe Bay Well Files R&D Carolyn Smith C~b~ Sohio State of Alaska C~. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 8, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: DS 5-8 Dear Mr. Chatterton: Enclosed is a Subsequent Sundry Report you 'have any questions, please call me Sincerely, Associate Engineer JG:tw GRU5/L61 Enclosure for the subject at 263-4944. wel 1. If ARCO Alaska, inc. is a Subsidiary of AHanticRichfieldCompany .... STATE OF ALASKA .... ALASKA. - AND GAS CONSERVATION CL MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL I~X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 2428' FSL, 234' FWL, Sec.32, T11N, R15E, UN TD: 1841' FNL, 987' FWL, Sec.6, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 64 ' RKB 6. Lease Designation and Serial No. ADL 28329 7. Permit No. 77-24 8. APl Number 50-- 029-20248 9. Unit or Lease Name Prudhoe Ba~/ Unit 10. Well Number 5-8 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] [] Change Plans [] Repairs Made '~ Other [] [] Other [] Pulling Tubing ~ Repair Well Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) -~. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accept rig ~ 0430 hfs, 08/21/83. Pull BPV. Displ well to NaC1. Reinstall BPV. Set plug in tailpipe + test. ND tree. NU BOPE. Perf tbg. Pull tbg. Mill pkr. Test csg - ok. Run 5-1/2" compl assy w/tailpipe ~ 10,542' + pkr @ 10,449'. ND BOPE. NU tree + test. Displ tbg to diesel. Set pkr. Secure well. RR ~ 2400 hfs on 09/06/83. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Area Drilling Engineer Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 DRN/SN5 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO AlaSka, Inc. Post Office Anchorage. .xa 99510 Telephone 907 277 5637 November 30, 1983 Reference: Arco Cased Hole Finals D.S, 3-22 8-30-83 D.S. 5-7 ;~' 9-12-83 D.S. 5-14 ''/ 9-23-83 D.S. 5-14 '-'~ 9~22-83 D.S. 14-32~-~ 8-29-83 D.S. 14-32 8-30-83 D.S. 13-98';,-11-9-83 D.S. 14-24 ~, 8-27-83 D.S. 5-2' 8-17-83 D.S. 3-7 8-17-83 D.S. 5-8 TM 8-25-83 D.S. 5-8 '~ 9-3-83 CBL/VD GR Production Packer/Collar Log GR CBL/VD CCL & Perf Record Run 1 5" Sch Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" Sch Squeeze Run on 5" Sch CPL/CNT-A (Therman) & CNT-G (Thermal & Epithermal) 5" Sch CET EPL CCL & Perf Log Collar Log for Casing Cutter GR/CCL Correlation Leg Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch. Run 1 5" Sch Run 1 5" Sch ign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F fChev=on Trans.~# 649 D & M Da!la~ Drillin9 GeUuy Marathon DISTRIBUTION North Geolo~ · Phillips Prudhoe(B~/~. ' Caroline Smith Sohio State of Alaska "--' STATE OF ALASKA WELL COMPLE' OR RECOMPLETIt,,.. AEPORT AND LOG 1. Status of Well Classification of Service Well OILXi~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2/+28' N + 234' E of SW cr of 5ec.32, T11N, R15E, UM At Top Producing Interval 1398' S + 1595' E of NW cr of Sec. 6, T10N, R15E, UN At Total Depth 1841' S + 987' E of NW cr of Sec. 6, T10N, R15E, UN ,5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 64' RKB IADL 28329 12. Date Spudded 13. Date T.D. Reached 14, Date Comp., Susp. or Aband. 06/08/77 06/29/77 07/04/77 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+ FVD) 19. Directional Survey 11860'HD,9237' TVD 11750'HD,9165'TVD YES ~] NO [] 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, 6R/CNL/CCL, CrL/GR 7. Permit Number 77-24 8. APl Number 50- 029-20248 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 5-8 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 15. Water Depth, if offshoreN/A feet MSL 116' N°i°f C°mpleti°ns 20. Depth where SSSV set I 21. Thickness of Permafrost ipple ~ 2226 feet MD I 1900' (APPROX) 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 20" 13-3/8" WT. PER FT. 94.0# 72.0# GRADE H-40 MN-80 - SETTING DEPTH MD TOP BOTTOM Surf Surf 109' 2733' HOLE SIZE 32" 17-1/2" CEMENTING RECORD Cmtd w/224 sxs Arctic Sei Cmtd w/5000 sxs Arctic AMOUNT PULLED cmt ;t cmt 9-5/8" 47.0# MN-80 & Surf 11837' 12-1/4" Cmtd w/1200 sxs "G" cmt L-95 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 10542 ' 10449' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 3ottom and 24. Perforations open to Production (MD+TVD of Top and interval, size and number) 11,482' - 11,530' 11,440' - 11,459' 11,400' - 11,420' 11,351' - 11,385' w/4 shots per ft. (Reperf'd same intervals w/4 spf on 01/21/79) 27. PRODUCTION TEST Date First Production ' Method of Operation (Flowing, gas lift, etc.) F1 owi ng 01/;~0/78 Date of Test Hours Tested 02/04/78 2.0 Flow Tubing Press. 1524 1PRODUCTION FORIOILIBBL ITEST PERIOD ~I~ 449 Casing Pressure ICALCULATED , OIL-BBL '' )24-HOUR RATE I~ 5388 GAS-MCF 354.6 GAS-MCF 4255 28. CORE DATA WATER-BBL 2.8 WATER-BBL 34 I CHOKE SIZE IGAS'OIL RATIO 48/64 1 790 OIL GRAVITY-APl (corr) 27.0 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 DRN/WC15 ~::~,~, -/_1 _~CI CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30.' GEOLOGIC MARKERS :~:I:-~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochit 10883' 8614' NONE Base Sadlerochit 11747' 9163' 31. LIST OF ATTACHMENTS Workove.r Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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". WORKOVER HISTORY DS 5-8 Move rig over well on 08/21/83. Accept rig @ 0430 hrs, 08/21/83. Test lub. Pull BPV Displ well to NaC1. Reinstall BPV. Set plug in tailpipe + test. ND tree. NU BOPE. Perf tbg. Pull tbg. Mill pkr. Test csg. Run 5-1/2" compl assy. ND BOPE. NU tree + test. Displ well to diesel. Set pkr. Secure well. RR @ 2400 hrs, 09/06/83. DRN/WH4 ARCO Alaska, Inc, ~ Post Office ~,× 1100360 Anchorage, Alaska 99510 Telephone 907 276 112115 August 18, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 5-8 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to repair the 5-1/2" completion assembly on this well. Since we expect to start this work on August 20, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4965. Sincerely, M. A. Major Area Drilling Engineer MAM/GRU4L22: tw Enclosures ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~vlMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL 7. Permit No. 77-24 1. 2. Name of Operator ARCO Alaska, Inc, 3. Address P, 0, Box 360, Anchorage, AK 99,510 50- 029-20248 4. Location of Well Surface: 2428' N & 234' E of SW CR, Sec. 32, T11N, R15E, UH TD: 1841' S & 987' E of NW CR, Sec. 6, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 12. 6. Lease Designation and Serial No. ADL 28329 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 5-8 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~0( Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well []~0~ Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes a workover to replace 5-1/2" tubing in this well due to tubing/casing communica- tion. The 5-1/2" tubing will be pulled and the packer retrieved. The 9-5/8" casing will be tested and repaired as necessary. The well will be recompleted with new 5-1/2" plastic-coated tubing and the necessary provisions for subsurface safety equipment. Upon tubing replacement, we propose to mechanically restrict gas from the potentially high GOR perforations (upper perforations), consequently allowing more drawdown from the lower perforations. Prior to running the completion, the blank separating the two lower sets of perforations will be tested with a test packer to confirm the ability to isolate the upper perforations from the lower perforations. The perforations fr/11,351'-11,385, 11,400'-11,420 and 11,440'-11,459' will be straddled using packers but will remain in controlled communication with the tubing via gas lift mandrels with variable orifice circulating valves. Additional perforations from 11,552'-11,630' will be added after rig release. A 13-5/8", 5000 psi, RSRRA BOP stack will be used on well work performed by the workover rig. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator, tested to working pressure will be used on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start Date: August 20, 1983 14. , hereby certify that the ~oregoing is The space below for Commission use Conditions of Approval, if any: Approved by. ~:e~urned COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 6RU4/SN12 ARCO Oil and Gas~C~.mpany North Alas strict Post Office vox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 15, 1980 Reference: ARCO Cased Hole Finals D.S. 5-8 9/11/80 Flow Survey Run 1 5" D.S. 5-8 9/18/80 Caliper Log Run 1 5" D.S. 5-8 ' 9/5/80 Flow Survey Run 1 5" COMM . RES ENG ---T-,STAT TEC__ --I-_~STAT T£~C V/~ease sign and return the attached copy as receipt of data. Mary Kellis North Engineering TRANSMITTAL #704 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AtJanticRichfieldCompany August 8, 1980 Reference' ARCO Cased Hole Logs D.S. 3-15 4/18/80 Collar/Gyro Run ! ~.s. 3-15 4/18/~o C~L Sun 1 D~f~6 6/29/80 Caliper Run 1 D.S. 12-2 7/6/80 Spinner D.S. 14-7 6/11/80 Density 2 a 5" (s~-m~e los) 5" 5" 5" /.2~1 14-7 6/11/80 Spinner ~Please sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #526 North Geology Exxon R [~ ]) Nlobil ~h-illing Getty En~. Hanager Phillii)s D ~ H Sohio Geology ~.la:rat]~on State oE ~aska ~,F~CO C,d and Oas Company ~.., ~ :..)~,~,s,oll ol Allar',[:C R~chtl,.-IdC:),'npan~, AFICO Oil and Januar}, lg, 1980 Reference' Enclosed are Hagnetic Tapes for the following ARCO wells' ~~.,, 9/20/79 ~'-D.S.._5_i~2 6/11/79 ~~-2 10/29/79 D.S. 12-4 10/8/79 Tape #57007 Tape #57002 Tape #60012 Tape #60030 Please sig~ and return the attached copy as receipt of data. I COM~ i co~M ~cOMM , i P,F.S [:NO ,"'.1' '_ :E~ ........ .. . t 4 ' " ' - k i I STAT T~_.I CONFER: FIEF: K. J. Sahlstrom North Engineering TRANS3IITYAL # 023 DISTRIiBUTIOX North Geology Pr il ting State oF Alaska ,-,,ci~,t~P,'~ '.tcing Division North AILm!-; n Post Of Sce Sox 3~0 Anchorsge, Ala~ka ~25i0 Telephone 907 277 July 51, ].'{_)79 Reference' Encl6sed are Cased Hole Logs £or tho £o]lowing ARCO wells' p.s. lz-i 7/il/7g I).S. 2-12 7/5/79 p.s. 7-iz; 5/21/79 P.S. 14-2 7/4/79 D.S. 9-7 6/5/79 D.S. 3-7 6/21/7~ p.s. 14-2 7/4/79 D.S. 5-15 6/22/79 D.S. 5-6 6/20/79 ]D.S. 1-16 6/12/79 D.S. 1-10 6/17/79 6/16/79 Colnpensatcd Neut:rttn - (;.I~. Com?ensated Netltron 'Fluid ])enstty Loc Spinner Survey Fluid Density Log l~m 2 l~u'ri Z Differential Te;nporatue I,og Nun 4 Continuous Flow Survey Run 1 .Compensated Neutron Log Run 2 " " " Jhlrl 2 " " " }%1~ ]. ' ' " " NUll ~ o Thenaal I)ecay T:hue RLm 2, Please sign and return the attaclled copy as rece.ipt o.£ data. Vet/ truiy yours, Pdlonda Bellinger North Engineerin~ Ii .~" 5" 5" 5" 5" 5" 5" 5" 5" 5" TI{&NSbliTTAI, # 243 DISTRTt;{fi'ION 'North Geology l)r] 11inq Eng. ?.!anaser R I) Coo logy State o.[ Alaska ]~v(XOi l ix bb :i 1 Cet: ty Soh io ~larat. lton Ph 'i 'l ] 'in<' ALASKA OIL AND GAS CONSERVATION COMMISSION July 20, 1979 / ! ~' $' NA,~MONO, GOVERNOR / / / / 300t PORCUPINE DRIVE.ANCHORAGE, ALASKA 99501 ARCO Oil and' Gas Company Attn: Rosie Hamlin North Alaska District P.O. Box 360 Anchorage, Alaska 99510 Rosie: The following material from Prudhoe Bay drill sites was received July 19, 1979 with no accompanying· transmittal: ~'(u'<.,~ ''It'° , ..,~'.B~~ Buildup & Flow Profil~rveys · ,~,,,~..~ 'y.~'.,./ ,~-~; ,~-7; V Comps. ret Processed Loq (Schlumberger Cyberlook) 14-5 Very truly yours, William Van Alen Petroleum Geologist North Ala,s~l~Distri cl Pos " ~' ~ t O,~]~,, 300 Anchc Alaska 93510 Telephone 907 2775~3~' July 13, 1979 Reference' Enclosed are final pTfints for the following ARCO cased-ho].e wells ;:~,'-.,., D.S,--,1.-13 ..... ~2~1 Spacing Thermal Neutron Decay, Time .--1/23/.7'9 '~ ~~D.S. 7-12 '~L ~-:~f-~j~--~~ 4/22/79 .... 5 [(~'~ NGI- 10/ ~asing Co.11a'~ Log(~~~') 2/1/79 5" ~D:-S-;-1-4:4-~/~°-~'8-nsi~Sd-N~GtrS~'-~ .................... - - ' 1/20/79 D.S..14-5 ~coustic Cement Bond Log ~L 2/20/79 D.S. 14-2 ~er~oration Collar Log ~/9/79 D.S. 1-18 ~ Tie In Log For ~wer Baker Packer 5/2/78 5" Run 1 D.S. 5~8 /~luid Density ' Z/1Z/79 5" Run 1 '~ ...... D~.~Sp~e.r~e' Flo~eter .......... 1-19/ 21~ 79 ~. 5" ...... 2/10/79 5" _ D.S 14-2 /~~~C~46~ 4/19/79 S" Please si~ and return the attached copy as receipt of data. Veo~ truly yours, R. A. Bellinger TFLANSHITTAL # 215 DISTRIB[~'ION North Geology Ih-il].ing Eng. Manager R&~ Geology State of Alaska I) & M Mobil Get'ty Sohio Marathon Phillips Chevron l~Ior~h Alaska Dis[rict Post O,qice F Ancho~a~e,~ .,~Ka 9'3510 Telephone 907 277,5637 March 22, 1979 Reference: Enclosed are the following pressure sm~eys' / ' DS 7-6 Static 2/28/79 DS 14-2''/'' Static 3/10/79 DS 14-1~ S~atic 3/7/79 ,~,~.,~,~.~"" Static 3/13/79 ~DS 5~.,~., Transient 1/19/79 Please sign and return the copy as receipt of data. Sincerely, V.G. Re,hers North Engineering TRANSi~,'!ITTAL # 113 DISTRIBUTION North Geology Drilling Eng. Manager R&D Geology State of Alaska D&M Exxon Sohio Mobil Mara th on Phillips Chevron Getty AflanticRichfieldCompany North Arnerj~' '~roducing Division North Alas .~trict Post Office Box 360 Anchorage, Alaska 99510 Teiephone 907 277 5637 January 31, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 5-8, Permit No. 77-24 Dear Sir' Enclosed please find our Sundry Notice of Subsequent Report and Completion Report detailing the work done on the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV' cs Enclosures Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate Form 3~ 0-403 REV. 1-10-~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for ~uch proposals.) O,L ~ GAs r-I WELL I.~.1 WELL L--J OTHER 2. N~,I~ OF OPERATOR_ Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 2428'N & 234'E of SW cr Sec. 32, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 64' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20248 6, LEASE DESIGNATION ANO SERIAL NO. ADL 28329 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 5-8 (22-6-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T1 ON, RISE, UN 12. PERMIT NO. 77-24 )ort, or Other Data NOTICE OF INTENTION TO; SUBSEQUENT REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) Perforate (Other) (NOTE~ Report results of multiple completion on Well Comlgletlon or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent d~tes, including estimated date of starting any proposed work. Began rigging up perf equip @ 0200 hrs 1/17/79. Tstd BOP. Pulled ball valve. Reperf'd intervals 11,482-11,508', 11,440-11,459', 11,400-11,420' & 11,351-11,385' w/4 shots/ft. All perf'd depths referenced to GR/CNL/CCL dated 7/2/77. Flowed well. Ran spinner survey. Ran & tstd SSSV. RU & tstd tree. Released well to Production Dept @ 0800 hrs 1/21/79. 16.SIGNEDI hereby certify~ ,~i~that t~~correct T,TLE District Drlnq. Enqineer OATE .~~a4Z~ Z./P;;~ ¢ · (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY-- T IT LE DATE See Instructions On Reverse Side F(~r:u P- 7 SUBMIT STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ,, ATE * , oeo other in- st ructions on reverse side; WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* w ELL W ELL DR Y Other b. TYPE OF COMPLETION: .~Ew ~ woR,, [ DEE,-[]--] PL~ []] D,~. F--] Reperforated WELL L ~ OVER EX BACK nEsvg. Other . ~__ 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF:OPERA'ToR P.O. Box 360; Anchorage, Alaska 99510 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 2428'N & 234'E of SW cr Sec. 32, TllN, R15E, UM At top prod. interval reported below 1398'S & 1595'E of NW cr Sec. 6, TION, R15E, UM At total depth 1841'S & 987'E of NW cr Sec. 6, T1ON, R15E, UM 5. AP1 NU/V[EE~CAL CODE 50-029-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 28329 7. IF INDIA_N, AJ-J~O'I~ffEE OR TRIBE NAME 8. UNIT,FA/LM OR L~F, ASE NAME Prudhoe Bay Unit 9. WELL NO. DS 5-8 (22-6-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Ba Fi eld _ Prudhoe 0i¥ Pool ,, 18. TOTAL DEPTH, MD & TVD[19. PLUG, BA, CK MD & TVDp. IF 1VfULTIPLE CONLPL., ] 21. ll,860'MD, 9237'TVD [ll,750'MD 9165'TVD~ ~ow~. ] ~OT^,~TOOLS Single All 22.PRODUCING INT'EEqVAL(S), O.F THIs COMPLETION--TOP, BOTTOM, NAME (MD AND TVD)* Top Sad]erochit 10,883'MD 8614'TVD Base Sadlerochit ll,747'MD 9163'TVD I ll. SEC., T., R., M., (BOTTOM HOLE OI3JEC'TIVE ) Sec. 6, I1 ON, R15E, UM ] ~. P~IT NO. 77- 24 13, DATE [ ELEVATIONS (DF, RKB, RT, GR, ETC)*{17. EL~v. CASINGHEAD 6/8/77 [ 6/29/77~ [ 7/4/77 11/1..9/77 64' RKB INTERVALS DRILLED BY CABI,E TOO 1,,~ 23. WAS DIRECTIONAL ! SUHVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/BHC/GR, FDC/CNL/GR/CAL, GR/CNL/CCL lllllllll I CASING RECORD (Report all strings set in well) 94# '! !-1-40 I 10~' 32" I 224sx Arcticset cmt _. 9-5/8" 47# BU~t. l[ L-95[N-80&! 11,83~'i [ 12-.1/4", 1200sx Class cml C~SI~NG SIZE 20" 13-3/8" I, AMOUNT PULLED LINER iq~COI~D · SIZl!J '[ TOP (A~[D) '[ IBOTTOM (~O) SACKS C~T* [ i i 28. PERORATIONS OP~ TO PRODU~ON (Interval size and number) ll ,482-ll ,530' ;/ ?::' 11,440-11,459' 11,400-11,420' 11,351-11,385' w/4: hots per ft. (Reperf'd same interva~ s w/4 shots/ft 1/21/7 ,, ,.. , ~. PRODU~ION 27. TUBING RECO P.D SCREEN (MD) SIZE 5-l/2" 10,602' 10~471 29. · ACID, SHOT, FZ~A,C~i'URE. C~F~XTz6~QFJZ,~,,.~EFC.[~' DEPTH SET (MD) [ PACKER SET (MD) DATE FIRST P~ODUCTION 1/20/78 DATE OF TEST, lI-{OU~S TESTED 'ICI-IO_'{E SIZE [PROD'N FOR 2/4/78 , 2.0 48/64 ~s.r~? I t 31. D'ISPOSITION OF GAS (Sold, used for ~uel, vented, etc.) Reinjected [PI~ODUCTION ME'iHO'I) (Flowh~g, gas lif~, pumping--size and type of pump) Flowing OIL---BBL. I 449 GAS--I~ICF. 4255 [VcELL STATUS (Producing or / .... ~-'=) Producing GAS--5/iCF. WATEri---BBL. [ GAS-OIL ~,~TIO 354.6 I 2.8 I 790 WASBBL. ~ OIL GRAVITY-~I (CO~.) I 34 I 27.0 TE~T WITNESSED BY Production Operations 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-a~allable records ~I~N~D ~.~~. ff~~t~ District Drilling Engineer ......... TITLE DATE *(See Instructions and Spaces [or AdditiOnal Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct' well completion report end log On. all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this forn~ and in any att,3chr~enls Items 20, and 22:: If this well is completed for separate, production from more than one interval zone (multiple com'pletion), so state ~n item 20, and in item '22 show the p~c:]ucir'~.'.t interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv~l ret~orted in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce~, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above.). 34. SUMMARY OF~ P*OIt. M'ATION T~S'I','-; IN('£,LII)IN(; INT~71LVAL'"~S'FED, I'ItE~S'UffE DATA ~"~COVERI~S' OF 01'L GAS, 35. G~GIC MARK~ WATer AND. MUD V~. ~one lop Sadleroch~t ' 10883' 8614' Base Sadlerochit 11747' 9163' . 3~. ~OI1E D~TA. ~'I'I'~CII II~IE~' ~~I~O~S O~~' ~[IOLOG~. PO~ITY. ~R~R~2 ~P~" ~i~ .. }~. ~ D~D SHOWS O~ OIL G~S O~ WAT~I. ' ~one AtlanticRichtieid ~--oF,';pany T~iephor~e 907' 277 ES37 December 29, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 300! Porcupine Drive Anchorage, Alaska 99501 Subj ect.~~Permi t No. DS~~ermi t No 74-62 77-24 Dear S i r .' Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:cs Enclosure Form ].~0-4,03 REV. 1-10-73 Submit "Intentions" In Triplicate "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) . , ,5. APl NUMERICAL CODE 50-029-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 28329 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ~' o,L I~ GAS F-1 WELL ~l.X.~.J WELL g-J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360, Anchorage, Alaska 995]0 DS 5-8 (22-6-10-]5) 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL At su trace 2428'N & 234'E of SW cr Sec. 32, Tll'N, RI5E, UM 13o ELEVATIONS (Show whether DF, RT, GR, etc.) 64' RKB Check Appropriate Box To Indicate Nature of Notice, 14. Prudhoe Bay Field-Prudhoe 0il Pool '11. SEC.,T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R15E, UM 12. PERMIT NO. 77-24 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT ORACIDIZE REPAIR WELL (Other) Perforate PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state alt pertlnsnt details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to reperforate existing perforated intervals within the Sadlerochit. These intervals will be reported on a subsequent report. A 5000 psi WP wireline lubricator tested to working pressure will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. The downhole safety valve will be pulled and then reinstalled and tested upon conclusion of the job. The well will be flowed to the Flow Station. Estimated start date' 1/5/78 16. I hereby certify that the foregoing is true and correct TITLE District Drilling EngineeroATE_F1Pnnmher..-27, !978 (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: See Instructions On Reverse Side North Aiask, ~tdct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 1, 1978 State of Alaska Attn: Mr. Hoyle Hamilton 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: In regards to your request for delinquent reservoir surveilance data, our records indicate the following: - Wells #3-3, 3~4, 3-6, 4-1, 4-6~4-9, 5-15, 5-16, and 9-4~ per your dates, indicate that they are Initial Static Surveys where they were shut-in for less than 12 hours and no stabilized flow rates are available. - Copies of surveys for D.S. #9-6 and #1-6 have been sent on i1-28-78~n~ should reach your attention shortly. D.Sf?~5-8.1~as sent out earlier this year and a copy will b~'~'"with this letter for your information. If further information is needed, please do not hesitate to request it from us. ral'JR HKVP Atiantic, RichfieldCompany North Americ?-a.,Producing Division North Alask ~rict Post Office B~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 2, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Procupine Drive Anchorage, Alaska 99501 Subject: ~Permit No. 77-13 ~ermit No 77-24 ~-~-Permit No 77-34 DS 5-11 Permit No. 77-30 DS 5-15 Permit No. 77-35 DS 5-16 Permit No. 77-43 Dear Sir: Enclosed please find a Completion Report for the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Supervisor /gk Attachments }' :~rm P 7 STATE OF ALASKA SUBMIT IN OIL AND GAS CONSERVATION COMMITTEE ~ II III I WELL cOMPLETION OR REcOMPLETION REPORT AND LOG* i ~""'la. TYPE OF WELL: on, [-~ UAS ~ WELL [_~ WELL ~ DRYt_J Other b. TYPE OF COMPLETION: NF, W ~ WORK F--] DEEP- ~ t>i'fiFG [] DIFF. ~ Perfor_r_a_tad W F,L I, ~ OVER [-.-J EN ~ BACK RESVR. Other ATE* 2, NAME OF OPERATOR Atlantic Richfield Company 3, ADDRESS OF OPERATOR 4. LOC,,,'rm~' ow .:,~ ( 1o rt location clearl~"anc~ in accordan¢~ with-a~F-STaYe requircm~nta)* 5. API NUi~LBI{ICAL CODE 50-029-20248 6. LEASE DESIGNATION ~D SEKLAL NO. ADL 28329 7, iF iND1A2q, Ai, LOTTEE OIt TiilBE NAAIig 8. UNIT.FAiUVI OR L 'lzb'kSE NAME Prudhoe Bay Unit 9. WELL NO. DS 5-8 (22-6-10-15) 10,,4FIELJ-~,~qD POQ~ OR vruanoe ~av ~%Td Prudhoe Oil Pool 11. SEC., T., t1., M,, (BOTTOM Iq[OL~ OtM Ec~rlvE) At surface 2428'N & 234'E of SW cr Sec. 32, At top prod. interval reported below 1398'S & 1595'E of NW cr Sec 6, At total depth ' 1841'S a 987'E of NW cr Sec. 6, TllN, R15E, UM T10N, R15E, UM T10N, R15E, UM Sec. 6, T10N, R15E, UM 12. PER~,IIT NO, 77-24 /8/77 [ 6/29/77 ] 7/4/77 '.~1/19-77)(/6 64' RKS ,~ 16, TOTAL DEl>TH. NiD & TVD[[9. PLUG, B~C:K MD & TVD~0. I~ ~LT~L~ CO~L., [ 21. INTERVALS I)RII,I,ED BY [ [ ~OW ~Y* { ROTARY TOOLS ----~ CABI,E TOOI.M ll,860'MD, 9237':TV~ll,750'MD, 9165'.~VD Single [ All ~. PRODUCIN~ [N~VAL(S), OF ~IS CO,MP~TIO~--TO,P, BOSOM, NA~E (MD AND ~)~ , SUI:VEY MADE Top Sadlerochit :10~883'~D, 8614'TVD ~ Yes Base Sadleroch!g. 11,747'~D, 9163'TVD .~ 24. TX~E ELECTRIC AND OTtt~ LOGS RUN DIL/SP/BHC/GR,, CP~SI24G SIZE !23. ~VAS DIRECTIONAL _ ~ GR/CNL/CCL FDC ,CNL/GR/Cal, . . CASING RECORD (Report all strings set in w~ll) HOLE SIZE ,[ CE2ILNTING ~ECOI~ 'i£t?.'rOUNT PULLED . 32"... ,t2248x Arcticset cmt. [ 17-1/2[ 5000sx Arcticse~ emil ,. IWEIGHT, LB, FT. ~ Gt%~D~I I DigPTH SET (MD) 94i ! .-4'n ! 1 nq, 72# BUtt[ M.N.-Sq 27~" 20" - i3'3/8"" _, 9-5/8" [ 47~ Butt[N-80~ 1]..8R7' [ IL-951 , , ' I -,--, ............... I ....... -~.~.' " ' ~'~i~ ~co~ .... ].~,. .. ~-u~o ~,~:~, .... 511,510 '-11,530 ' (il, 351'-11,365 ' / D5~I'Ii INT~V.~ (MD1 ~ A?,I:oUNF AND kIND OF' MA'iE3',iAL USED 11,482'-11,490' ~ ~v N/A 11,440'-11,459' ~/~>~ '11,400'-11,420' 4 shots per foot , /il, 365 '-11,385 ' ~ '" ~ A~;( ~7:'- ~l'~ ....... ~0. e~o~c~o~ ~UI:~ P~:'~3~%OD~CTZON [ P~ODUC~ION M~ZHOD (Flowh~, ~ l~i~, pump~ng~size and type of pump~ ~ 1/20/78 .... :~ [ PZowKng 2/4/78 449 354.6 2.8 ~%524 [ 4255 I 34 ,~1. DISP081TION OF '790 IOIL GRAVITY-API (CORR.) 27.0 · Reinjected 32. LIST OF ATTACHMENTS I TES'I' \V ITNEg,~ED BY Production Operations 33. I hereby certify that the for_egoing and attached information is complete and correct as determ'ine~ from all-available 'ret'ur,Ix __ ' ' ' ' ' Sm,E ;' TITLE Dlstrlct Drlg~¢g~er re, WE .... Z~~X -- I I I I I I I *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete anci correct well completion report end log on all types of lan:is and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in cther spaces on this form and in any attachr'nems. Items 20, and 22:: If this well is completed for separatc, prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc. Jucir~.9 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the acktitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this welt should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). , , , , 34, SUMM'AR¥ OI;' B"ORMATION 'I'If2.~'I'S IN('LUI)IN(; INTERVAL TF~S~FEI'), F'HE.~SIJIIE DATA. A.N~'I:LI~COVEI{IES OF ()IL, GAS, 35. G ]~OL,OG I C' M A R K~%S WAT~.iR AND MUD · ili "Ti I' i' i ii i .'an. cOitE DATA. ^'I-I'^CIi B~iEF 'D~rt,~/T'i~IkSN$ :'Op LiTiIOLOC¥. PO'~O'.e;iTY, FrtACTUlZtF. S.-At~P~NYP .~'~S ,._. A~NI~ 'l~l~'~.~"<Cq"Igl) StlOWS oF OIL. GAS Oil WATER. Alaska 1)i 'J' R A N ,% ~.I I T T A J, State of Alaska FTOill ' t.e- Ii, 197,P Well Nama'. 'an-.-;,,i t. tcd t~crcwith are the following for the .subject well' ~:~ No. $cal~ · . Xerox Sep-.ia 'BL Line Acid or Fracture ~¥eatment Log - NIP Bm. lc up [ Flow Profile Sun'ey };orchole Geom'et~3r Log Carbon Ox)%en Log Casing Collar Log ..... Cement Bond Log Compensated Neutron Log - Cased Ilole --. Core Pmalysis - Interval Core No. Core Description (~.IC) - Interval ....... Co-re Description (Cony.) - C.ore No. ..... Directional Sux~r.ey- Gyro - Single Shot . ~Mltishot _ . . 'Engineering Producti. on' Log Fluid Analysis .Fluid Density .... *_~**__ Additional GOR' reports . l,ocation Plat ........ Monthly Wcll Test Data Nud Log Perforating Record. State Reservoir PreSsure Report Surveillance Reports Temperature Transient Pressure Surveys ........ TVD I,ogs - ~el Induction I,aterolog - Compensated Formation Density Log - Compensated Neutron-Fm~nation Density Log. - Boreho]e Compensated Sonic Log - Porosity 1.og ,:;ase Ret:t,rn P, eceJ.pt To' Ms. R. A. Logue ...... · Atlantic Richfield Company P. O. Bo): 360 Anchorage, Alaska 9951.0 Norlh American Producing9 North tlaska_{.n;, trict Post O~Jice a,' 30 Anchoraga, Alaska 99510 Telephone 907 277 5~37 June 29, 1978 Enclosed are copies of of the following Cased hole logs: Gmnma-Ray Neutron Log 'D.S. ~fS-2 5" ( 1 Dresser Atlas - 1 Go Wireline) Compensated Neutron Log D.S. ~4-15 2" ~ 5" Cement Bond Log D.S. #4-1 2" & 5" Neutron Log D.S. itl-4 5" Casing Collar Log & Perforating Record D.S.. ¢t1-13 5" Continuous Flow Survey Please 'sign and return copy of transmittal as receipt of data. Very truly yours, R.A. Logue North Operations EngineerSng Transmittal ~f373 "tlanticRich!!eldCompany North American Producing Division Alaska Regir ..... Post O.~[ice B_ .~60 Anchorage, Alaska 99510 Telephone 907 277 5S37 Reference' Enclosed are'Transient Pressure Surveys for the follow~2~g wells' *i}.s. #9-6 'D.S. #4-6 ~:D.S. #5-11 ' ~D.S~ #3-7 //5-8 :' . I)~Correcte8 revised data) Please sign attached copy as receipt of data. Very truly yours, R. A. L°gue North Operations Engineering Indicates key well data Transmittal #366 ~-~North Alaska District I-;n~,ineer~h]g T RAN SlXl I T TA L FrOlll ' J. A. Rochoit/R. A. Logue Scale' Acid or Fracture Treatment Log · BHP Buildup & Flow Profile Survey Borehole Geometry Log Carbon Ox~ygen Log Casing Collar Log Cement Bond Log ...... ~ Compensated Neutron Log - Cased Hole Core Analysis - Interval Core No. Core Description (~IC) - Interval Core Description (Cony.) - Core No. Directional Su~ey - Gyro - Single Shot - }.Mltishot 'Engineering Production- Log Flui. d Analysis ~ . Fluid Density · Gamma Ray Location Plat Monthly Well Test Data Mud Log Perforating Record · State Reservoir Pressure Report Surveillance Reports Temperature Log Transient Pressure Surveys TFD Logs - Duel Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Fm~nation Density Log - Borehole Compensated Sonic Log - Porosity Log Receipt Acknowledged By' . ~. ~_ · }']_case Return. Receipt To: Ms. R. A. Logue Atlantic Richfield Co:npany P. O. Box 360 Anchorage, Alaska 995].0 · , Xerox Sepia BL Line Date' Atlai~ticRichfieldCompany North Amer~'~ Producing Division North Alask istrict Post Office Box 360 Anchorage, Alaska 995'!0 Telephone 907 277 5637 April 4, 1978 Mr. Hoyle H. Hamilton State of A1 aska Department of Natural Resources DivisiOn of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 5-8 (22-6-10-15) Permit No~ 77-24 Dear Sir- Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /am EnclosUre Form 10-403 REV. 1-10~73 Subml t "1 ntentions" in T rlplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL11 OTHER NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, AK 99510 4. LOCATION OF WELL At SUrface 2428'N & 234'E of SW cr Sec. 32, TllN, R15E, UM 13. ELE;VATIONS (Show whether DF, RT, GR, etc.) 64' RKB ~4. Check Appropriate Box 'To Indicate Nature of Notice, Rel 5. APl NUMERICAL CODE 50-029-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 28329 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay Unit 9. WELL NO. DS 5-8 (22-6-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe nB,a.~ Field Pv,,,rl hnc~ 1~. 'SlE:~.~'Y.';' ~., Y~:, '(BOlq'I:fM HOLE OBJECTIVE) Sec. 6, TION, R15E, UM 12. PERMIT NO. 77-24 3ort, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF [__...J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING M U LTI PLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEz Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Accepted riq @ 0900 hrs 3/18/78. Pulled & laid 5-1/2" tbg. Replaced collapsed jt and reran 5-1/2" tbg compl assy w/tailpipe @ 10,602', pkr @ 10,471', BAL-O nipple @ 2173'. Tstd pkoff, control lines, & annul, OK. NU & tstd tree to 5000 psi, OK. Pulled dummy valve. Ran CCL/dummy gun. Ran & set ball valve. Tstd OK. Released rig @ 0600 hrs 3/24/78. 16. I hereby certify that the foregoing is true and correct District Drilling Engineer April 4, 1978 . . TITLE DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side AtlantiL-RichfieldCompany North American Producing Division North Alasl istrict Post Office i~o× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 5-8 (22-6-10-15) Permit No. 77-24 i Dear Sir' Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, ~ Frank M. Brown District Drilling Engineer /am Enclosure Form REV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proi3osal$ to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-029-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 28329 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR. 9. WELL NO. P.O. Box 360; Anchorage, AK 99510 DS 5-8 (22-6-10-15) 4. LOCATION OF WELL At su trace 2428'N & 234'E of SW cr Sec. 32, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, et~) 64' RKB 14. 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi eld-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R15E, UM 12. PERMIT NO. 77-24 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING ORACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and log form.) 15; DESCRIBE PROPOSED OR COMPLE-FED OPERATIONS (Clearly state all pertlneilt detell~, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to pull and replace the 5-1/2" tubing string to correct a tubing leak. During the repair operation a 13-5/8" 5000 psi RSRRA BOP stack will be utilized. This work is expected to begin March 17, 1978. 16. I hereby certify that~he f04'e~oing Is true, and correct TITLE (This space for Sta.te~1flce use)./'~,," '\ 1 APPROVED District Drilling.Engineer DATE - 3/!5/78 DATE See Instructions On Reverse Side '--Xorth Alasta I)istrSct Er~gj!ne~e'-'~--~[ T R A N S M I T T A L To' From: J. A. Rochon/R. A. Logue Transmit. ted herewith are the foilo:..,'ing, for the subject ,,:eli' ?;DT-' Run No. Scale Xerox Sepia BL Line Acid or Fracture Treatment Log - BHP Buildup & Flow Profile Survey Borehole GeOnletry Log Carbon OxF%en Log. Casing Collar Log . Cement Bon.d Log Compensated Neutron Log - Cased Hole · Core Analysis - Interval Core No. Core Description (SMC) - Inte~al · Core Description (Cony.) - Core No. Directional Survey- Gyro - Single Shot - Multishot " Engineering Production Log 'FlUid Analysis Fluid Density Gamma Ray Location Plat Monthly ?,'ell Test Data Mud Log Perforating RecOrd State Reservoir Pressure Report Surveillance Reports Temperature Log Transient Pressure Surveys TVD Logs - Duel Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Fmm. ation Density Log -- Borehole Compensated Sonic Log - Porosity Log !~eceipt. AclmoWledged By' .~'~ }'lease Return Receipt To' Ms. R. A. Logue Atlantic Richfield Company P. O. Box 360 ~a~chorage, Alaska 99510 Date' ,~-~.- / V ,- ~Y North Alaska District Engineering TRANSMITTAL To' From: J. A. Rochon/D. R. Jackson Date' March 3, .'1978 .- Well Name' D.S. 5-8 . Transmitted herewith are the following for the subject well' Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log 2" BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log' Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv..) - Core No. Directional SurVey - Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gan~na Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog ~.'~dlog- Interval Sample Log (A.R. C6.) - Interval Synergetic Log TVD-DIL TVD-Porosity Log 211 ea. ~ ea. Receipt Ack--owl_edged For: Date' ' ~/a~da"'~. [i~ /~ /.d~ At'tn: F4r. Donovan Jackson Please return receipt to: Atlantic Richfield Co, any North Alaska Engineering P. O. Box 360 Anchorage, Alaska 99510 #791 North Alaska District Engineering TRANSMITTAL TO' From' Date' Januar. y 11,1978 Well Nane' J. A. Rochon/D. R. Jackson D.S. 5-8 Trm~smitted herewith are the following for the subject well' No. : Scale- Xerox Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Gsrmna Ray Log BHC Sonic/Gan~na Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval' Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. DireCtional Survey.- Gyro_ Single ShOt Multishot Drill Stem Test - Test No. 2ml Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog ~'Hcrolog b~dlog - Interval Smnple Log (A.R. Co.--) - Interval Synergetic Log ~VD-DIL TV])-Porosity Log Initial trasient Pressure Survey:Nov8 . Receipt Ackmowledged For: -- Date: ,,, Attni bk. Donovan Jackson · .Please return receipt to: Atlantic Richfield Company North Alaska Engineering P.. O. Box 560 Anchorage, Alaska 99510 By' ~ ~IGNED BY - #752 MILE 4. NORTH RD. BOX 3453 KENAI, ALASKA 99611 PH. (907! 283-4403 P.O. BOX 4-1~51 ANCHORAGE. ALASKA gg5Og TELEPHONE' I=907~' 27~','3525 TLX 0902-6481 Company Well Location ATLANTIC RICHFIELD COMPANY Location DRILL SITE #5 #8 NORTH SLOPE State Date M.D. SS ALASKA 8 NOVEMBER 1977 40584 40585 PRESS. PRESS. GRAD IENr Elev. -64 Well Information Datum -8800 ,Zero Pt. T.H. Csg9 5/8to 11857, ~to Tbg. 5;~ to 10,54.2.' ~to Perfs. Pkr. . PBTD ~ Csg Press Oil Level H20 Level Well status Prod rate Date last test Status of well last test Prod. rate last test · Press. last test Press. this test Press. change Element Nos. 40585 Calib. No. Remarks BHT = 186° 40584 ~lv~ .... _ , \ : -, :\ ; p } J ! , : ; ~,iI · ! ':'f' I' ~ ' ' ' ' : i''~ .... ~ ~ t ~ ,,' ;~1,,~i;~ ~: ~[~k~' ~l,~ i~ , . , ~ . . :'' i i ~ , i , tl ;f ; ~ : - , : : , i - , . , , , , . ~ ti iii !11 I J Ill [iii { I iii) ~llJll]~i ifil iii iii[ ' '' [ l i i t i ti itl Il i i ii i ,,,t ~,,,,,~ ~,,,,,,! '"~1"~1 t'iil-~l~ '~tll';~ ~Ii[ ..... '' IOO0 Pressure 2000 Field -PRUDHOE BAY Formation SADLEROCHIT 3000 4000 8800 4352 4351 .315 8600 4289 4287 .330 6000 3415 3412 .325 2000 2127 2127 . 332 -35 1453 1452 . MILE 4, NORTH RD. BOX 3453 KENAI. ALASKA 99611 PH. {9071 283-4403 P.O. BOX 4-1551 ANCHORAGE. ALASKA g9509 TELEPHONE 1907) 276-3525 TLX 0902-~481 .. Company ATLANTIC RICHFIELD COMPANY Location DRILL SITE #5 Well #8 Field PRUDHOE BAY State ALASKA Location NORTH SLOPE Formation SADLEROCHIT 1000 2008ressure 3000 /-, 000 M.D. 0 r , , ' ....... i,, ' , ...... " ..... 11255 I I ~ilili,,~:i~ii: ';"i, i ii!i i~ Ilil i}li:iiii, 11 ,~.~ till I ! i i lltiiiii iii! '1~I I Jill Ii ~i!it!1 i1~ I i, , [l ' 1 iill iiii i~ llli Itli, iit~ .... '"' ...... "'"' '!!" Ii' !' '! ! ' ' ' ' ' '-:4-~~l''~ ' ' ' ~' 'i ' I ..... " tli 1 J ' !it ,il~,'~,~,~, ~ ..... ,'.,~,, ,. ,iii , I ~ , ..... ~,' ~!I !i!ilil~ ~].1 IIIi,i1~1 iiillil! !itl il~i iill lili iili iit! !i!! !1il llli Date S~- 8 NOVEMBER 1977 40584 40585 PRESS. PRESS. GRADIENT 8800 4352 ' 4351 6000 3428 3425 .323 2000 2140 2142 .321 -35 1470 1469 .330. Elev. -64 Well Information Datum -8800 Zero Pt. T.H. Csg. 9 5/I~o 11857 ~.to Tbg. 5% to ]-'0542 .... to Perfs. Pkr .... PBTD ~ Csg Press Oil Level H20 Level Well status Prod rate Date last test Status of well last test Prod. rat~ last test Press. last test Press. this test Press. change Element Nos. 40585 Calib. No. Remarks BHT = 186 4O584 North Alaska District Fn~gineering TRANSM! TTAL To' From: J. A. Rochon/D. R. Jackson Date' Jammryg,_'1978" Well Name' Transmitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log. BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log' Compensated Neutron-Fo~xnation Density Compensated Neutron Log Core Analysis - Inte~nzal Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot b~ltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Garmna Ray/CCL Laterolog Location Plat Microlaterolog Microlog b'~2d!og- Interval Sample Log (A. R. Co. ) - Interval Synergetic Log TVD-DIL TVD-Porosity Log Collar ~ : 5" Receipt Acknowledged For: Date: · Please retrain receipt to: AttO-/ ~. Donovan Jac~zson A~ntic Richfield Co. any Nb'rth Alaska -Engineering P. O. Box 360 Anchorage, Alaska 99310 D.S. 5-8 Xerox Sepia BL. Line ea. /. ea. #735 Atl~nticRiichfieldCompany North Ameri¢~'~- Producin9 Division North Alaska .~trict Post Office Bo× 360 Anchorage, Alaska 99510 Telephonic 907 277 5637 December 28, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and.Gas 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT:~ DS 5-8~(22-6-10-15) Permit No. 77-24 DS 5-~1 (12-31-11-15)Permit No 77-30 DS 5-16 (31-30-11-15)Permit No. 77-43 DS 9-14 (11-2-10-15) Permit No. 77-25 DS 9-15 (11-1-10-15) Permit No. 77-36 DS 9-16 (33-3-10-15) Permit No. 77-37 Dear Sir: Enclosed please find a Sundry Notice outlining our changes for the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB/mln Enclosures Form 10-403 REV. 1-10~73 Subml t "1 ntentions" in Triplicate '*Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL I--.J OTHER 2. NAME OF OPERATOR ATLANTIC RICHFIELD COMPANY 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 2428' N & 234' E of SW cr Sec 32, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 64' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 15. APl NUMERICAL CODE 50-029-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 28~29 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 5-8 (22-6-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 6, T10N, R15E, UM 12. PERMIT NO. 77-24 3ort, or Other Data NOTICE OF INTENTION TO: r-'--'-3 I"-'-1 TEST WATER SHUT-OFF ~ PULL OR ALTER CASING ~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Correct Perforated Intervals SUBSEQUENT REPORT OF: WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Began perf operations.il/5/77. Tstd tree, csg & wireline BOP's. Pulled dummy valve~ Perf'd intervals 11,510' - 11,530', 11,490' - 11,510', 11,482' - 11,490', 11,440' - 11,459', 11,400' - 11,420', 11,365' - 11,385', 11,351' - 11,365' w/4 shots per ft. All perf'd depths referenced to BHCS/GR open hole log of 6/26/77. Ran Amerada press bombs. Flowed well. Ran & set ball valve @ 2,186'. Tstd balance & control lines to 5000 psi, ok. Bled press above ball valve, held ok. Installed & tstd tree cap to 5000 psi ok. Released well to Production Dept. 11/19/77. This report replaces the one previously sent dated 11/25/77. 16. I hereby ce~fy that t. he foregoi~rue and correct T~TL~District Drilling Engineer DATE. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.- TITLE DATE See Instructions On Reverse Side North Alaska District Engineering TRANSMITTAL To' From: J. A. Rochon/D. R. Jackson Dat~ December 19 Well Name' D.S. 5-8 Transmitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log . ,, Compensated Neutron-Formation Density -Compensated Neutron Log .. Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Singl~' Shot , b~ltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL .Laterolog Location Plat Microlaterolog Microlog b~dlog- Interval . Sample Log (A. R. Co.) Interval Synergetic Log TFD-DIL TVD-Porosity Log Fluid Dessity Xerox Sepia BL Line Receipt Acknowledged For: - Date: . /~.~.0 ~/7 /F*7~z ~ttn: 5h'. IJonovan Jackson Please retm~ rec. eipt to' Atlantic Richfield Company North Alaska Engineering . P. O. Box 360 Anchorage, Alaska 99510 A~l~r~ficRichfieldCompanF North Ameri¢ >roducin~q Divi~io~ North A~aska Umtrict Pos~ Office Bo~ 360 A~chorage, A~a~ka 99510 T~fephone 907 277 5637 December 15, 1977 Mr. Russell A. Douglass State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: It has come to my attention recently that wells 5-8 thru 5-16 as well as DS 9-13 thru 9-16 will n~t. g~ on production until mid January or February. So a~-this~m~ I Will submit only the -~ubsequent SUndry not'ices and submit completion reports as soon as the wells go on production. Very truly yours, Karla K. Lenz ~' Engineering Associate KKL/am At~.r~ic~RichfieldCompan~, · North Arneric, roducin9 North A~aska A~chorage, A~aska 99~0 Te~ephor~e 907 277 December 15, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: (~DS 5-8~?(22-6-10-15) Permit No 77-24 ~DS'-~Sf~ (33-32-11-15) Permit No 77-34 DS 5-10 (14-32-11-15) Permit No. 77-45 DS 5-11 (12-31-11-15)Permit No. 77-30 DS 5-12 (41-31-11-15) Permit No. 77-14 DS 5-13 (43-29-11-15) Permit No. 77-26 DS 5-14 (13-29-11-15) Permit No. 77-33 DS 5-15 (43-30-11-15) Permit No. 77-35 DS 5-16 (41-30-11-15) Permit No. 77-43 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above mentioned wells. Very truly yours, M. Brown District Drilling Engineer /am Enclosures Form 10-403 REV. 1-~1. 0~7 3 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELLi i OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 28329 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360; Anchorage, Alaska 99510 DS 5-8 (22-6-10-15) 4. LOCATION OF WELL At surface 2428'N & 234'E of SW cr Sec. 32, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 64' RKB Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R15E, UM 12. PERMIT NO. 77-24 }ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOC)T OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perforate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~letalls, and give pertinent dates, including estimated date of starting any proposed work. Began perf operations 11/5/77. Tstd tree, csg & wireline BOP's. Pulled dummy valve. Perf'd intervals 11,510' - 11,530', 11,490' - 11,510', 11,482' - 11,490', 11,441' - 11,460', 11,400' - 11,420', 11,366' - 11,386', 11,351' - 11,365' w/4 shots per ft. Ran Smerada press bombs. Flowed well. Ran & set ball valve @ 2,186'. Tstd balance & control lines to 5000 psi OK. Bled press above ball valve, held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production Dept. 11/19/77. 16. I hereby certify that t~e~ foregoing is true and correct SIGNED TITLE District Drls. Ensineer DATE. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side THRU: O.K. Gilbreth, Jr. DI rector Hoyle ti. Hami Iron //~~/ Chief Petroleum Enginee DEPARTMENT OF NATURAL RESOURCES vision of Oil and Gas Conservation November 22, 1977 Harold R. Hawkins Petroleum Inspector To witness - subsurface safety(SSSV) valves and surface safety valves(SSV) ARCO- PRUDHOE BAY Drill Site 5-8/5-9/5-10/5-11/ 5-12/5-13/5-14/5~ 15/5-16 November 16 - i went to the slope by Wlen Airline at 10:00 a.m. arriving on slope at 11:30 a.m. and Arco Base Camp at 12:30 p.m. Purpose of trip to witness tests on subsurface safety valves and surface safety valves for Arco on Drill Site 5. There were'9 SSSV's and SSV's to test. Average test time on these wells was ] 1/2 hours per well including observation. Between tests it took 2 to 4 1/2 hours to manifold up on another well. DRILL We// SITE NO. SSSV SSV 5 8 OK OK 5 9 OK OK 5 10 OK OK 5 11 OK OK 5 12 '~ OK OK 5 13 OK OK 5 14 OK OK 5 15 OK OK 5. 16 OK OK TUB I NG TEBT I SSS V PS I PS I DEPTtt , 1400 900 2166 1400 900 2202 1400 900 2204 14OO 9OO 2216 1400 900 2184 1400 900 2246 1400 900 2250 1400 900 2222 1400 900 2256 When Well No. 13 test's were started there was a break in the bleed line. This caused a 20 hour delay in testing. The clean up operations resulting from the break are on separate report. November 19 - Tests were completed. All SSSV's and SSV's for Arco on Drill Site 5. There were no leaks. Tests were satisfactory. HH:fad Drlg. Permit No.__ Operator ~ ~/~-z9 AlaSKa Oil and Gas Conservation CommitL~ Field Inspection Report Wel 1/Platfm Sec T R Represented by/~]/?/.f~/2~Name & Number_~)~ ~,~"~ ~ Satisfactory Type Inspection Yes No Item ( ) Location,General () () () () () () () () (~) () () () () () () ()'() () () 1. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( /filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells / 6. Subsurface-No. Wells /__ ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls. , , , ( ) Final Abandonment SatisFactory Type Inspection Yes No Item ( ) BOPE Tests () () () () () () () () () () () () () () () () () () () () () () () () () () 15. "Casing set @ 16 Test fluid-( )wtr.--~-)mud ( ) oil 17 Master Hyd. Control Sys.- psig 18 N btls. , , , ___psig 19 R2emote Controls 20 Drilling spool-~"outlets 21 Kill Line-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs flas 24. Chokes-( )Remote( )Pos.(-)-A-dj. 25. Test Plug-( )Hellhd~ )csa( )none 26. Annular Preventer, 27. Blind Rams, ~psiQ ( ) ( ) 11. P&A Marker ( ) ( ) 28. Pipe Rams ~_psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psig Pad' leveled ( ) ( ) 14. observation time "~-~-~/days~~i ( ) ( ) 31. Safety Floor valves-~ Total inspection Total number ~leaks and/or e~uip, f.a, ilures Remarks -~'--~ ~ 7~£- ~ ~z~/~ ~?!', -' -~ ~ ~ ~?-.~ ?~-~- %;7~zi~/2--~Z-~~-/'9---l? cc' ~/_),r? ~',/~t.~U_~_-q Notify in days or ~hen r~dy' {nspected ,~tlan~iichfieldCompany North Amc ,n Producing Divisioh North Ala, District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 7, 1977 .. Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' D.S. 5-7 (22-5-10-15) Permit No. 77-13 ! ...... ~ ..... ~5.~2~. ( 22-6-10-15 )' Permit No. 77-24 D.S. 5-9 (33-32-11-15) Permit No. 77-34 ., .... D.S. 5-12 (41-31-11-15) Permit 'No. 77-14 D.S. 5-13 (43-29-11-15) Permit No. 77-26 D.S. 5-14 (13-29-11-15) Permit No. 77-33 Dear Sir' Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wells. Very: truly yours, Frank M. Brown District Drilling Engineer /am Enciosures 'ii'.,./ FOrr~', 10-403 REV. 1-10-73 Submit °'1 ntentlons" in Triplicate & "SUbsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS oN WELLS (Do not use thls form for proposals to drill or to deepen U~e "APPLICATION FOR PERMIT--" for such proposals.) OIL ~ CAS I---! WELLI/~J WELL L..J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3- ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 4. LOCATION OF WELL At SUrface 2428'N & 234'E of SW cr Sec. 32, T11N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 64' RKB 99510 14. Check Appropriate Box To Indicate Nature of Notice, Re: NOTICE OF INTENTION TO: TEST WATER SHUT~)FF · FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Perforate 5. APl NUMERICAL CODE 50-029-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 28329 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ~,. UNIT. FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. D.S. 5-8 (22-6-10-15) 10. FIELD AND POOL, OR WILDCAT rudhoe Bay Fi el d-Prudhoe oil Pool 11. SEC., T., R;, M., (BOTTOM HOLE OBJECTIVE) Sec. 6, TION, R15E, UM 12. PERMIT NO. 77-24 3orr, or Other Data SUBSEQUENT REPORT Of: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all p9rtlnent details, and glve pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere during perforating operations. The downhole safety valve will be installed and tested upon conclusion of job. Estimated Start Date' 9/25/77 16. I hereby certify that the foregoing is true and correct S iGiN E D/~~~~Z~/~~ ' TITLE District Drilling Engineer (This space for State office use) Appp, OVED BYL/~' {~- ~ TITLE CONDITIONS OF APPROVAL, IF AN~: Petroleum Engi neer See Instructions On Reverse Side DATE Copy Returned North Alaska District Engineering ~ ST~ ~ B~' T~D 'TO; From: J. A. Rocl~on/D. R. Jackson I)ate: _ 'August_10, 1977 Well Name: D.S. 5-8 Transmitted hermvi.th are the follm¢ing for the subject well: Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Intmwal Core No. Core Descrip-tion (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - ~ ~.~ltishot - Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog 'Location Plat ' Microlaterolog Microlog Mudlog- Interval Sample Log (A. lt. CoT) - Synergetic Log TVD-DII, TVD-Porosity Log ea. 0 ea. ! ea. A 677 SO23 7-15-77 Eastman I~ipstock 5~ _ Iea: ~ es;. Receipt Acknowledged For: PI. ease return receipt to' Atl~tic Richfield Company North Alaska Engineering blanager P. O. Box 360 Anchorage, Alaska 99510 #545 AtlanficRichfie~dCompany North Americ_~_9 Producing Division North Aiask strict Post Office l~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 2, 1977 Mr. HoyleHamilton state of Alaska' Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 m 1 CONFER: , Subject:Permit Drill Site No. 7?-245-8 (22-6-10-15) ~clos~ pl~se fi~ a C~le~on Re~rt along wi~ ~e ~ill~g His~ ~d M~-S~t D~ectio~l S~ey for ~e ~e ~tion~' well. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN L ':'-~-.-' : other st ructk)ns on reverse side? i ii ii ii ii i i i WELL £OMPLEIION OR RECOMPLEIION REPORI AND LOG* i t i iii i i ii ,a, :¥~ o:,~ we~:.: " ' o.. ~ ~,~ ~ ~ X~ ELL W ELL DR Y Other b. TYPE OF COMPL~()N: WEIr. OVER ~ EN ~ BACK RESVR, Other ~ NAM E OF OPERATOR ADDRESS OF OPERATOR Atlantic Richfield C~y P. O. Box 360; Anchorage, Alaska 99510 4, ],o< ,,'rl~)N OF WI':I,L (Report location clearly and in accordance with amy State requirements)* 5. APl N~CAL CODE 50-029-20248 ~. LE. AS~ DESIGNATION AffqD S~.RIAL NO. ADI. 28329 7. IF IND1A2~, ALLOTTEE OR TRIBE; NAiVLE 8. UNIT,FAYL1VI OR LE~kSE NAME Prudhoe Bay Unit / Prudho~ Oil Pool At surface 2428'N & 234'E of SW tr Sec. 32~ TllN~ R15E~ UM ~t top prod, tnter,al reported below 1398'S & 1595'E of NW cr Sec. 6, T10N, R15E, UM At total depth 1841~S & 987~E of NW tr Sec. 6, T10N~ R15F.~ UM i1. SEC., T., Il.., NI., (BOTTOM Iq:OLE OI:LJECrIVE) Sec. 6~ T10N~ R15E~ UM I:~,. PErR2VIIT Ix[O, 177-24 6/8/77 6/29/77 7/4/77 64' ...,~ ~OW ~Y* CABLE TOOL8 11,860'~, 9237'~11,750'~, 9165'~ S~qle . , PRODUCiNO [N~HVAL(S~, OF ~IS COMP~TIO~--TO,F, BOSOM, NA~E (~D AND ~)~ ,23. ~VAS D!R~iCTIONAL ~ SURVEY ~IADE ~p Sadl~~t 10,883'~, 8614'~ ~ Yes ~se Sadl~hit 11,747'~, 9163'~ 24 'I"YPk; [,;l_,E('Till(' AND OTttER, LOGS RUN D1L/SP/BHC/GR, FDC/CNL/GR/Cal, GR/CNL/CCL I ~. , , ,1 I/ -- Ill I CASING RECORD (Report all strings set in well) WEIGHT, LB, F'F, [ 'GRAD,.E I DEPTH SET (MD) 94# [ H-40 I 109' 72# Butt /MN-80 ] 2733' 47# Butt 1..N-80&/11,837} / r,-- 51 ": "' 20 92578 26 LIN ".:R R~iCOtKI~ ~::.~: 'fop {?,:o, ~-o'~'To:.< ,~<o) s.~:~<~ ~:~x**, %8 PERF~')]42'I lO'NS OPEN TO P~oDuC~ON [gt~crval 's~ze and nurnbei) i i iii i i ii i ii i i 30. PI%ODUCTION HOLE SIZE [ C'~d[LNTING RECOPd) i A2/fOUNT PULLED 17-~" ~ 5000 sx ~cti6~e[ II ~t 12-%" 1200 sx Class G ~t 27, TUBING RECOP~ SCi:E~ [J~D~ SIZE DEPTH SET (55D) ~ PACKER SET (?~D) 5-~" ........10..'602' ~.i 10,471~ 29, ACID, Si!GT, FJiAC~ GEE, C~IENT SQUL~Z~, ETC~ D~-~-~TIi iNT~q. VA3L (MD) IAS':OUN£ ::2~D I'£!ND OF MAXFP~iAL US'ED i ~ i ii DA'['E FItL%T ['I~.O[~JCTION!PIIODUCT1ON MEI[iOD (Flov:ii*g, gas lifi, pumping--size and type of pump) IX~:ELL STATUS (Producing or ~nut-in) FL,OW, TUfHN(; U~'SI.NO PRE~SURE ICXLC~T~ OI~BBL. GAS--~CF. GAS tSold, used .for'/uel, vented, etc.) 32. LiST OF ATTACHMENTS Drilling History, Directional Survey WATER--BBL. } OIL GRAVITY-A/~I (COi%R.) l t TEST WITNESSED BY I hereby certif,~,~hat the foregoing and attached information is complete and correct as determined from all-atailable records /Cc'--z /f7 ~d,O ~ m TITLE Dis~ict Drill~g Eng~eer DATE ~ SIC;NED :~'' ~ ~ ~ ~ ' "~ i i i i i i i *(See Instructions and Spaces Jar Additional Data on Reverse Side) _ ..... - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lan:ds and leases ira Alaska. Item: 16: Indicate which elevation is used as reference (where no~ otherwise shown'~ for depth measure- ments g~ven in other spaces on this form and in any aft,~ch:~'~e,"~s Items :20, aad :22:: If this well is completed for separatc production from more than one ~nterval zone (multiple completion), so state in item 20, and in ite,~ 22 show the p~cJuc~:.1_l interval, or .c~tervals, top(s), bottom(s) and name (s) (if any) for only the interval! ref~orted in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. It~m~: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF' FORMATION TESTS INCLUDIN(; INTEI'{.VAD TF~STED. I'HE~URE DATA AND'fLEcoVEHIES OF OIL. GAS. 35. G EOL,OG IC WAT~q. AND MUD NAME MEAS. DEPTH. T/~U~' V'ET~T. DEPTli , AND DE'~Cq'EI) S:I'IOWS OF OIL, GAS O'R DRILLING HISTORY DS 5-8 (22-6-10-15) API No. 50-029-20248, ADL 28329, Permit No. 77-24 Spudded well @ 0600 hrs 6/8/77. Drld 17-1/2" hole to 2750'. Ran 13-3/8" 72# MN-80 csg w/shoe @ 2733', FC @ 2652'. Cmtd w/5000 sx Arcticset II cmt mixed to 15.2 ppg. Floats held OK. Installed pkoff. Drld FC & cmt to 2730'. Drld float shoe & CO to 2750'. Drld 10' new hole.' Tstd form to 0.65 psi/ft gradient. Drld 12-1/4" hole to 11,769'.. Ran DIL/SP/BHC/GR to 11,766'. Ran FDC/CNL/GR. Ran 9-5/8" 47# N-80 butt csg w/shoe @ 11,837', FC @ 11,748', lower FO @ 2461', upper FO @ 2338'. Cmtd w/1200 sx Class G cmt @ 15.8 ppg. Bumped plug w/3000 psi. Floats held OK. Landed & tstd pkoff. Worked upper FO & tstd. Opened lower FO & pumped thru w/anul closed. Cmtd thru lower FO w/300 sx Arcticset. Closed FO & tstd to 3000 psi. Opened upper FO & circ. Arctic Packed thru upper FO. Wtr washed 9-5/8" x 13-3/8" anul w/642 bbls wtr, break thru @ 168 bbls. Pumped: 45 bbls spacer & 255 bbls gel pack. Drld out to 11,750'. Press tstd csg to 3000 psi. Displ mud w/10.6 CaCl2. Ran GR/CNL/CCL. Ran gauge ring & junk bskt, Ran 5-1/2" 17# N-80 AB Mod 8rd compl asbly w/tailpipe @ 10,602', pkr @ 10,471', SBR @ 10,420', sliding sleeve @ 10,309', landing nipple @ 2172'. ~ Displ CaC12 in tbg w/250 bbls diesel. Dropped ball & set pkr. Tstd pkr w/3000 psi. ND BOP. NU & tstd xmas tree to 5000 psi. Pulled dun~ny valve & ran CCL & dungy gun. Ran dungy valve.' Tstd control lines to 5000 psi. RU for long term tbg tst. Released rig @ '1200 'hrs 7/4/77. A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIOtVA L SURVEY Atlantic Rich£ield COMPANY D. S. 5-8 WELL NAME Prudhoe LOCATION JOB NUMBER A677 S023 TYPE OF SURVEY Multi-shot DATE 7-15-77 SURVEY BY Kevin Durling OFFICE Alaska RA~'IUS~., OF CURVATURE ~',~E~muu' ur CO~vi~UTATiui",~S, K B ELEV, 64 Fi', CO,~.IPUTED FOR EASTMAN WHIPSTOCK' INC. BY F. M, LINDSEY AN!) ASSOCIATES RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC CO~.iPUTER TRUE MEAS. DRIFT VERTICAL SUB DRIFT [)FP Tt-t ANGLE DEPTH SEA DIREC TOTAL COORDINAI'E5 D ~,I DEG. ........... _gQG LLG ! 1244 0 30 1243,98 1179,98 N41,OOE 2,14 N 4,91 E .... 2-21~-'o ...... i ....... 0 .... Sf~+-~-T-8-~-: ........ ~'1'8 ~". ~9 ~'Z+'",'65E; ....... ~--'v.-:: .... , ............ : ........ : 1~.,:~8. h. 12,92 i 18,03 2800 0 45 2799,82 2735.82 S~4,00E 15.96 Iq 20,16 i 25.72 2986 7 0 2985,29 2921,29 S4!,()OW 6,~2 ~'.~ !5,47 E 16,7i ~-fi) ....il o ~ 1 ~ ~, 4 2 ~ 10'4',"~2 ....... ~'4, i · o. 0W ................... !.8., ~.;~ ......... 5 ................. ~..,7.1 ..... ~, ............ 3~58 15 0 3349 .62--528"5 ,']~ .... ~2i-~"'.OOW 49.00 S 3451 ].7 o ~439.Ol :~3'75'"01 ....... s~3-"-oow 57.~o s 3730 22 0 3701,94 3637.94 S50,O0'W 131,84 S 3523 Z~ 0 3787,86 372~,86 SSO,OOW 154,72 S ~009 27 O ~102 28 0 33,g5 51,16 71.30 93,82 146,04 175.02 3956,40 3892,40 S49,00W 205.51 S 205.01 4038.89 3974.89 S39,00W 236,36 S 235,81 59,55 5 34 85.02 S 36 59 57 w 2.!5~ 84, 113.57 S 38 53 ~0 ~' 2,i78 112. 144,40 S 40 51 12 w 1,083 i43, 177,46 S 42 0 58 W 2.198____ ]_7~_ 212.76 S 4.3 20 50 w 1,075 250.37 S 44 21 0 ~ '2.151 290,99 S 45 4 i~ P~ 2.162 290, 333,b7 S 44 55 99 ¥~ 2,002 4195 28 0 4121,00 4057,00 536,OOW 270,99 S 262,38 V: 377.20 S 44 4 ~l W 1,5i4 ~77, 42S~ 30 0 4202,34 413-8--~,-~- .... 'S-~-g;-'(-)o'v." 307.47 s 2us. SCi l'~ 42t.89 S 43 12 54 w 2.151 '*21. 43~1 31 0 4282.47 4218,47 S35,00~' 345.89 s 316,29 '.r 466,70 S 42 26 26 '~.? 1,112 4475 33 0 ' 4362,1.B 429¢.,18 s36.0()w 3~.6.44 s 34.5.22 '~;7 5i5.'[8 s 41 46 30 '~'~ 2,152 4568 35 0 44~9,2~----4"~"~-~]"~-8----g'55,00v.' 42~-.-7:3 'J ........ 375,41 w b69,90 S 41 12 !Z W 2.179 RECORD OF SU~'~'' ,.xv [fY ALL CALCULATIONS P ~ 7~'~' ERFO, ,d~[.) bY I B tv1 ELECTRONIC COi"IPUTER TRUE DOG LEG DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O__.5_._U [_~,__E.~S.. ~[::V_b.,.f:i. LT.] ~CT_i_i O .M D E G, D H ,. 4754 42 0 4585.25 4521.25 SS6.00W 4940 4~ 0 4717.86 4653.86 S~6.OOW 522.16 5 442,66 W 684.55 S 40 17 23 ~,~ 4.30! 682., 573.47 S 479.94 .W 747.81 S ~9 55 34 w 2.151 627.58 S 519.26 W 814.55 S 39 36 i4 W 4.30! )1.~ 884,90 S 39 25 12 w 2.105 o~0. 5034 49 0 4780,14 47].6.14 S39.00W 683.43'5 562,11 W ..... 5'%27'--2+~ ....-0--4'-8-~7~_-~-9'-6- ....~?~'~'-~"-~-~ ......... S4~.~)'O~i .........~-~'~%~-~-'-~ ............ ~u~.63 W 953.44 S 39 30 47-W 5.632 949, 5220 47 0 4906.98 4842.98 S42.00W 785.69 S 651.77 W 1020.84 S 39 40 39 w i.075 1016. [63!3 46 0 4971.00 4,907.00 $42.00W 835.82 S 696,91 W 108g,24 S 39 49 17 W 1.075 1083, 0.000 1150., 0.000 1217. 55g2 46 0 5685 46 0 5778 46 0 1258.82 S 40 9' 38 W 6.uO0 12d4. -- 1~55.66 S 40 16 33 it,' 0.773 1351. 1422.49 $ 40 24 14 W 0,000 lg!8.~ 5~71 46 0 5358.62 5294.62 543.OOW 1132.14 S 967.6~+ W 148,9.32 S 40 31 i4 W O.OOO 5964 45 0 5423.80 5359.80 S43.00'w' 1180.65 S 1012.88 W 1555.59 S 40 37 34 v,~' 1.075 6057 46 0 5488.9B 5424.98 $4.3,0(')W 1229,16 S 1058.12 W 1621.87 S 40 43 2~ '¥¥' i.075 1551. 6150 ~+6 0 5553.59 5489.59 .S44.00i.,'] 1277.69 S 1104.17 W 1688,69 S 40 5~ 0 ~,,, 0.173 ...... 6Pi~W--4"~----O--5-6'i-?'"'~-'~-~-~-~-3'""'O'i $4~:'-CO'W !326,61 b 1i5-i-.41 W 1756.61 S 40 57 2! W 2.i51 1752. 5337 ~'(j ........D ....-~-~"~"';"-6-~j ....... 5'~'i"~-",63 - S45.00w 1377,2! S 1201.14 w 1827,41 S ~1 5 ~6 w__.2.217 ...... ~"3'0 51 0 5737,83 5673.E3 ..... 'S4-5"'-O'OW 1427.95 S 1251.88 w 1899.01 S 41 14_._27 ~,~ 1.075 s57-~---:~ 0 ':70T;-?-F--Y?':T,'?2- ..... s45".001,: 1479.4-2 S !305.34 v': 1971.84 S 41 Z2 ~S .... ?: .....%.,__QZ~ ............ 6709 51 0 5910.8T 5846.87 545.00~¢~ 1582.70 S 1406.63 W 2117.44 S 41 37 44 W 1.075 2~_,_ 6~02., 51 0 5969,40 5905.40 S45o0C:f,, 16~3.B1.~ ~c 1457.73 W 2189o59 ~ 41 ~+4 25 N 0.000 2186. 6~95 51 0 6027.93 5963.9~ $44~00k: 1685.~6 S 1505,39 W 2261.79 S 4i 49 42 W 0.836 698S 50 0 6087.07 6023,08 S49.00W 1734.74 S 1560.43 W 2333.29 S 41 7081 50 0 6146.86 6082.86 S43.COW 1764.20 S 1611.65 W 2404.33 S 42 5 28 W 4.941 7174 49 0 6207.26 6143.26 5~2.00¢: 1836.34 S 1659.4B ~,,, 247 7267 49 0 6268.27 6204.27 S42.00'4 18~8.b0 S !706,39 '.,,,' 254 261 5 · 23 S 42. 5. .... .b__9_a' 0 ,_O_i:_O . l 6 .. i._: S_.!+_.2 ........ 5_ P. O___i'~.~.O._,_(.\G.t) ___26_lZ... RFCORD OF q~ tR~-~Y ALL CALCULATIONS PERFOR!',,IED BY I B H ELECTRONIC COi'..iPtJTEiR TRUE ,' ' D_OfL.L E a hIEAS. DRIFT VERTICAL SUB DRIFT TOTAL COORDINATiS C L, 0 ,,% U___R__[f $, SEV_~RITY .&ECTI( b I S 1' A N C E A N G LE _DiG / Z O.~_T ,_D_LSI~ D ~'i S DEPTH A~'GLE DEPTH .SEA D!REC D ~,.,I DEG. 7454 49 0 6390.95 6326.96 542.000 1993.38 S 1.¢00.83 7547 48 0 6452.58 6388,58 542.000 7640 48 0 65L4.81 6450.8~~ .... ~.~_.OOW 7733 48 0 6577.04 55Z3.04 S42o00~ 7826 49 0 6638.66 6574,66 542.000 7920 49 0 6700.33 6636.33 S42.000 2045.14 S 1847.43 ~ 2096,50 S ..1_8~ S · 68 2147.86 S ~,_9___39 · 92 2199.62 S 198o.53 2252,35 S 2034.00 W 8013 49 0 6761.34 6697,34 542,000 2304.51 S 2080,96 8199 50' 0 6881.52 681T.52 542.00W 2410,00 S 21';'5.95 8292 50 0 6941.30 6877.30 S43.00'W 2462.53 S 2224,08 .. . ......... 87~..~..~.__! ........ ~_._7_099._:__~_~ ........ 6.9~._6_?_.~_~ ........ s4~ ..00w ......... K~_lP._~_2hs__~_.27 ~. 847~ 50 0 7059.61 69~5,61 543.000 2567.49 S 2321.96 8571 50 0 7119.39 7055,39 S4a.OOW 2619.17 S 2371.00 -8%'-641--~-5 6 .... ~l-W~-ff-ff?"i'i-g;"Y~ ...... g"41~'"601126 7o.4: s 2420 S757 50 0 7238.95 7'-Y'~7-+-;~: ....... :'~':-"OOW 2721.23 S 2470,42 303 ! .J 3171. 22._42.-. 3 _~_,_ : 5 93_.,.. 3671. 8850 50 0 7298.72 7234.72 S44.000 2772.04 S 2520.36 W 3740.52 S 42 16 38 w 0,824 3742. 8943 50 0 7358.50 7294,50 S44.00v,; 2823.29 S 2569.85 t,,~' b317,73 S 42 18 34 W 0.000 3813, 9036 50 0 7418.28 7364.28 545,00i'~ 2874.10 S 2619.78 b',' ~88~.92 S 42 20 58 W 0.824 9130 50 0 7478.71 7414,71 545.000 2925,02 S 2670.70 W ~960.85 S 42 23 51 ~',: 0,000 9316 50 O 759S.26 7534.26 S45.00W 3025.77 S 27'f1.~5 ~,'.~ 4103,20 S 42 29 17 W 9409 50 0 7658.04 7594.04 545.OOW 3076.14 S 282!,83 W ~+174.37 S 42 31 51 V,' O.CO0 4170. 9502 50 O 7717.82 7653,82 S45.000 3126.52 9595 50 0 7'7-?- 7 .-~o ,:j ........ -7"1-i 3 · 60 54-5.00W 3176.90 ........ ~-:J-i:. ':--5-b,. , .... 0 _-~'c~-:~,..,. ..... _,':~----~ ~.~ ,. 7:-',"ff~----S-4-5-R~O::f. .... -: 227. z -/ 2~72,20 t,,.¢ ~245.55 S 42 34 20 'v'; O.~oO 29~2.58 t,.' 4316.73 S 42 36 44 ,:, 0.000 2972.95 ', 4387.91 S 42 39 4 ~',' 0.000 424.1. 45!3. 9-~7' 8 1 49 0 7897.78 7833,78 S45.00W 3277.28 9874 49 0 7958.79 789a.79 S46.000 3326.47 0967 49 0 8019.81 7955.81 546.000 33~-'23-- S _°022.96 ',',' 4458.57 S 42 ,+1 16 W 1,075 S 3073,02 ,,,,i 4528.67 S 42 43 55 W 0.~12 S ~123o51 ~,',~ 4598.75 S 42 46 5~ ~' O.uO0 4525. ! C'E, & r~ a9 0 80S0.92 ' ] :.:i'~% "4"9 -6 ........ ~':r;'-:';'4 ~0!6.~2 546.000 342~.9.~ S078.49 546.00w 3473.27 3174.00 ~,.¢ e66s.U3 S 42 e9 40 :: O.CO0 3225.03 W a739.66 S ~:2 ~2 3~ ~', O.O00 a"f 36. ' RECORD OF SURVEY · ALL CALCULATIONS PERFORM¢:'?,,...,.,.., ,...,rev, I B r''~-, ELr'CTRO:"IC,~. ,.: COHPUTCR,,... TRUE DOGLEG MEAS. DRIFT VERTICAL SUB DRIFT TOTAL CO()RD[t',IATES C L 0 S U R E S' .SEVERITY SECT_jU DEPT!~ ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/IOOFT DISTAi D M DEG. D hl S 10247 48 0 8204.11 8140.tl S46.00W 3521.65 S 3275.13 W 4809,21 S 42 55 22 W 1.075 4~06. 10340 49 0 8265.73 8201.73 S47.00W 3569,59 S 3325~65 w 4878.73 S 42 58 25 w 10433 49 0 8326,75 ~262,75 S49,00W 3616.56 S 33'77.81W 4948,65 S 43 2 ~2 W 1,237 4875. ! .623 10526 50 0 .9387,15 8323,15 SSI,OOW 3662,01 S 3431.98 W 5018.85 S 43 U 34 W 1.658 10713 51 0 8506,72 8442,72 S55.00W 3749.52 S 3546,01 W 5160,7~ S 43 24 7 ;? '2.22~ 5~7, 10806 51 0 8565.25 8501. 10899 51 0 8623,78. 8559. 25 555,00W 3790,97 S 3605,22 ~',' 5231,55 S 43 33 40 ~' 0,900 5230, 78 S54,00W 3832.94 S 3664,06 W 5302,52 S 43 42 34 w 0.836__5301,_ 30 ...... ~'54 C,~ · . 0 000 5372.. · 0 ~. 3875 42 S 3722 53 W 5373.65 S 43 50 49 W · _ 20 554,00V. 3918,20 S 378'!,41 W 5445,31 S 43 58 55 W 1.075 5444.' 07 S54.00W 3961,74 S 3841.B4 W 5518,27 S 44 6 57 W 0.000 551'7, 11085 52 08740,20 E'676, 11179 52 0 8798,07 8734., 11272 51 0 8855,96 8791,96 S54,00W 4004,52 S 3900.22 W 5589,98 11365 51 0 8914,49 f!850,49 S54,00W 4047,00 S 3958.69 '¥'...' 5661,23 S .44 22 4 '~.;' 0,000 56iz0._ 11458 50 0 8973,64 8909,64 S54,00W 4089,18 S 4016.74 11551 49 0 9034,04 8970,04 $55,00W 41B0,25 $ 4.074,31 11644 49 0 9095,05 9031,05 S54.00U 4171,01 S 4i31.46 11769 49 0 9177,06 9113.06 853,00W 4227,62 S 4206,92 11860 49 0 9236,76 9172.7~ S53.00w 4268,95 $ 4261.76 W 5731,99 S 4.4 29 V:' 5801,64 S 44 ~.~ 5870,80 S '44 43 37 W 0.812 5870, W 5893,17 S 44 45 38 '~ 2.516 5893. W 5904,14 S 44 51 33 t,~' 0.000 5904. W 6032.13 S 44 57 0 ?,' 0,000 00_~._~,. t"4 Ar,1 E DE P T H , DE P T H t3/x, SE SAD 11747 9162.63 42:L7.~:~3 S a193,66 ~: 594,,7,,?"ff_0____~ z~____~ ..... D__O .... :LZ_~',,, .90_.9_~,,63 , , _ TRUE MEASURED VERTICAL SUb MD-TVD VERTICAl. DEPTH DEPTH SEA D :]: FFEREFiCii CORRECTION TOTAL COORD i NATIE,5 16~ 164. 100 0 0 0,01 264 264. 2 00 0 (') [) ' 0 ~ ' il , I . ..:_i'~ __564 564.. 500 0 0 __ C. 16 t"4 ~_,~_1 :J [i 764 76Z~, 700 0 0 O,B6 N 2,07 864__ 86~, 800 0 0 O,B6 .~ 2.6.]. 964 964, 900 0 0 __O,f15 N 3.~_19 i 1064 1064, 1000 0 0 1.22 1164 I].64. 1100 0 0 1,69 N 4,41 1264 1264. 1200 0 0 2.27 N 5,02 1364 1364. 1300 0 0 5,63 E 1464 1464. 1400 0 0 3,76 N 6,28 [ 1564 1564, 1500 0 0 4,62 N 6.98 [ 166a 1564. 1600 0 0 5,55 N 7.73 1764 1764. 1700 0 0 6,56 Fi B,5i 1864 !86z~. 1800 0 0 7,65 N 9,34 196a 196a. 1900 0 0 8.81 N 10,22 E 2054 2064. 2000 0 0 10.06 I',i 11,13 E 2164 2164. 2100 226a 2264. 2200 2364 2364, 2300 2464 2464 · 2400 0 0 11,58 N 12.07 E 12.78 N 13,06 ~ 14,0P i"i 14,17 ~ F-'- 15.02 I',4 15,46 E i5,6~J N 16,85 2664 266a. 2600 0 0 16,01 ,N 18.28 E 2764 2764. 2700 0 0 16.0~ i"{ 19.68 E 2864 2864. 2800 0 0 14.52 N 21,41 E 2965 296a~ 2900 0 0 8.19 N i7,09 E 3066 306a. 3000 1 1 3167 3164. 3100 3 :4_ '3270 3264, 3200 5 2 3373 3364. 3300 8 3 3477 346a. 3400 13 5 3583 3564, 3500 18 5 TRUE MEASURED VERTICAL 5UD i',I D- T VD VERTICAL 3689 366~, 3600 25 7 ~22,02 S i07.36 W 3V97 3764, 3700 33__ 8 148.23 3 906 388~. 3800 42 9 4017 3964. g900 53 4~130 4,064., 4000 66 13 4244 4164, 4100 79 13 4359 4264, 4200 95 16 4z+77 4364, 4300 113 4598 4464. 4400 134 21 4726 4564, 4500 161 27 4862 4664, 4600 197 36 5009 4764, 4700 245 48 5157 4864, 4800 293 48 5303 4964, 4900 339 46 5447 5064, 5000 383 44 5591 5164, 5100 427 ~4 5735 5264, 5200 471 /+4. 5879 5364, 5300 515 44 -- 6021 5464. 5400 557 42 707 57 6165 5566. 5500 601 4a 63].6 56gZ-' 5600 6672 5764. 5'700 14.5i.ll S 1275.03 W , __ 5634 5864. 5800 770 63 1541,17 S 1365.10 5793 596~, 5900 829 59 1628,86 S 1452,79 6952 6064, 6000 888 59 i716,22 S t~59,U2 7107 6164, 6100 943 55 i798,77 S 162b,17 7260 6264. 6200 996 53 1884,57 & 1702.86 74].3 6364, 6300 1049 53 i970,53 $ 1780,07 7564 6464. 6400 1100 5i 2054o5~ $ 1855o88 7713 6564, 6500 1149 49 Z136,8~ $ 19~9,98 7864 6664. 6600 1200 5i 2220,94 $ 2005,72 8017 6764, 6700 1253 53 2306,75 5 2082,98 8171 6864, 6800 1307 5a 2394.06 S 216i,60 2242,42 8327 6964, 6900 1363 56 2482,19 8a85 7064, 7000 1421 58 2571,31 IV, EASLIRED DEPTH AND OTHER PATA Z'OR EVERY EVEN 100 FEET 0'( ,SUe3 SEA DEPTH, , TRUE MEASURED VERTICAL SUB F','iD-.TVD VER'FIgAL DEPTH DEPTH SEA D I FFir.;RLhlCE CORRECTION TOTAL COORID ]' I',tATE S 8640 7164, 7100 1476 55 2657,19 $ 2407,72 W 87.96 7264. 720(;) 1532 56 27~2,al S 9107 7464, 7400 1643 ~6 Z912.56 S 2658,2~ W 926 Z '/'~ ~'~"; .....%6'5 ...... ~-'E~-E ............................ 9574 7764. 7700 1810 56 ~16~,43 S 2911,11 9729 7862, 7800 1865 55 3249,52 S 2995,g0 W 9882 '7964, 7900 1918 53 ' 10034 806,/+, 8000 19'70 52 3410,35 .5 3159,88 W 10186 8].64, 8100 2022 52 3490,00 S 2~242,35 W i03'~-7 8264. 8200 2073 51 3568,05 $ 3324.00 W 10645 8464, 8400 21B1 55 3718,54 S 3503,54 W 10804 10963 11123 8564, 8500 2240 59 3790.08 S D603,94 W 8(:,64. 8600 2299 59 386Z,,13 S 3704.24 W 11284 8864. 8800 2420 61 11443 8964. 8900 2479 59 4082,40 11596 9064, 9000 2532 53 4.149,85 11749 9164, 9100 2585 53 4218,54 S 4194,8f~ ~ 3~07 · 76 4007,4i 4102,05 i ,"4 T E R P~.O_L.A T E..D V_~,_~_F~S__F_OJ~V_=.t:,I_i..O OO_E b..~T__O .FL...-~.~iA,,%U.I~LD~4....q~P-T,P.~.--'~ ' TRUE 2,'iE A 5UR E D V E R T :[ C A L DEPTH DEPTH S[.:A TOTAL COOR[) II'~ATE5 .... 1000 999. 935. 0.97 4000 39 ':~.,~'; · 3884, 202°84 S 202.94- ,5000 4757. 4693, . 663,39 S 546.20 W .~/ 6000 544.9, 5385, 1199.~3 S 1030~.3('.) W V 7000---- 6094. 6030. 1740.81 S t567.~2 V,,' I/' 8000 6752. 6688, 2297.21 S 2074.a0 W ~" 9000 7395. 73,31, 28.5/4.,53 S 2600,35 W .ix ,- 10000 80al. 7977. ~392.5~ S 3141.a2 W ~':'~ HORIZONTAL- VIEW ................ : _ SCALE 1" I000 ATLANTIC RICHFIELD. WELL N0~-5'8 RADIUS OF CURVATURE MAGNETIC M U LTI-SHOT_~-.'.-_- i 6400 o 6800 6000 7200 .' ! - - ' : ....... ] ALL DEPTHS . 8 40O ........ . . ...... : ........ , TVD =9;2:57', TMD 11~860 '" " : ..... ; .... :'-:: .... ! ...... .':'-:--: ...... .i .......... - .... : .... ---i --- 800 - I~00- _ · I$00- 2000 ~800- 4000 ................ VERTICAL- SECTION SCALE.. I"= 10004_ RADIUS OF CURVATURE ....... MAGNETIC MULTI-SHOT ALE~-DEPTHS SHOWN ARE TVD -- 6~0 - '~ .............. ' ; ~ ............... , --. ~ · - .............................. ...... 6O0 LOCATED IN THE APPENDIX UI WFL UI IPR LOG UI CALIPER SURVEY UI VOLAN ~ CURVE DATA [~ STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER: North Alaska District ]~gineering £ONdDENTIAL To: From TRANSMITTAL J. A. Rochon/D. R. Jackson Date' July ,28,, 1977 Well Name' Trm~smitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Co~npensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot ~ltishot Drill Stem Test - Test No. Dual Induction LaterologFormation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog Mudlop~- Interval Sample Log (A.R. C6.') - Interval Synergetic Log T\rD-DIL TFD-Porosity Log 2" and 5" D.S. #5-8 Xerox Sepia BI., Line I ea. Rece ip t ;Ad~ o~,~ec~ge'~ For' Please return receipt to: Atlm~ti~ P~chfield Company North Ai~ka Engineer,'rig b'lanager P. O. Box 360 Anchorage, M. aska 99B10 # 534 ,,AflantiCRichfieldCompany -~ North American Producing Division ..~.--~ North Alas )istrict Post Office box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 13, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 ~(22-6-10-15) Permit No. 77-24 Subject: D.S. 5-13 (XX-29-11-15) Permit No. 77-26 Enclosed please find our Monthly Report on the above mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form No. P--4 RI~. $- 1-70 OIL w~LL STATE OF ALA~SKA svB~rr ~ mm:ucA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS wELL OTHER NAME OF OP]~.ATOR 3. ADDRESS OF' OPERATOR Atlantic Richfield Company P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL 2428' N & 234' E of SW cr Sec. 32, TllN, R15E, UM APl NUAIER1CAL CODE 50-029-20248 6 I.EASE DESIGNA~ON AND S~IAL NO ADL 28329 IF INDIA},[. AI~DTT-E.E OR TRIBE NAME 8. L,~IT F.~RA4 OR LEASE NAME Prudhoe Bay g WELL DS 5-8 (22-6-10-15) 10. Fll~.~.r) A_ND POOL, Oil WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11 SEC, T., R., M.. (BO?~TOM HOLE OB,TECT~ .Sec. 6, T10N, R15E, UM ' IT 13. RE~ORT TOTAL DEPTlq AT END OF MONTH, CHA. NGES IN HOLE S17-E. CASING AND C~A~iENTING JOBS INCLUDING DEPTH SET A_Nq3 VOLLqVIE~ USED. PERFORATIONS, ~-F~TS ~ HESULTS FISHING JOB~ JI/NK IN HOLEAND SIDE-TRACKED HOLE A~D ANY OTIdER SIGNIFICANT CI-L&NGES IN HOLI~ CONDITIONS. Spudded well @ 0600 hrs 6/8/77. Drld 17-½" hole to 2750'. Ran 13-3/8" 72# MN-80 csg w/shoe @ 2733', FC @ 2652'. Cmtdw/5000 sxArcticset II cmtmixed to 15.2 ppg. Floats held OK. Installed pkoff. Drld FC & cmt to 2730'. Drld float shoe & CO to 2750'. Drld 10' new hole. Tstd form to 0.65 psi/ft gradient. Drld 12- ¼" hole to 11,769'. Ran DIL/SP/BHC/GRto 11,766'. Ran 9-5/8" 47# N-80 butt csg w/shoe @ 11,837', FC @ 11,748', lower FO @ 2461', upper FO @ 2338'. Cmtd w/1200 sx Class G cmt @ 15.8 ppg. Bumped plugw/3000 psi. Floats held OK. Landed & tstd pkoff. Worked upperFO & tstd. As of June 30 opened lower FO & pumped thru w/anul closed. Prep to cmtthru lower FO. sm~/~ . ~ District Drilling Enginee~r~. ) NOTE --Report on this form is required for eQCh calendar month% regardless of the status of operations, and must I~ filed In duplicate with the oil and gas conlervat/on committee bythe 15~ of the succeeding month, unle88 otherwise directed. STATE of ALASKA DEP~ 0F NATORAL ~ Divisic~ of Oil and Gas Conservation FROM: TO: ' O. K. Gilbre~h, Jr. Director Hoyle H. ~mtilton ~[ B~n LeNonman ~ DATE :J~y 7, 1977 SUBJECT:~(~DE Test, ~kr(~O',.~ r~q 5-8 and-9;,'00 ~4-' dele via BP charter for ne~se, arriving, there at 10:30 AM. ~ Rig #141 persorm~l met n~ at the aircraft and trams- ~ me to well DS 5-8 where nippling up was in progress fc~ BC~E tests. Arco drilling f~ was Ken ~ and Parker toolpusher %ms Tcm Black. Tests began~ at 10:00 PM with t3~ annular ~reventer t~st_~., to 3000 psig. Top pipe rare, ~ valve in the kill line, tlr Swaco super~e and ball type floor valve then tested to 5000 psig. Lowe= kelly valve and ~ pipe rams ti~n te~ to 5000 psig. Kelly cock tested ~ 5000 psig. 1900, 1650, and 1875 psig. Re~0¢~ ~_re actuated and later sets of pipe rams, blir~ rar.~ and arurd]ar preverrter w~re closed simul~ly, clos/ng' in eleven seconds. Dart type floor valve was c~ the floor. Eight valves and ~ty flanges in the ck~ke manifold tested to 5000 psig. The a~co ~r~ was actuated fully open and fully closed and the man,_~! adjustable cbnke was free moving. Outside wing~.' valve ~n the kill Line and outside valve on the choke line tested to 5000 psig. The inside valve on the kill I/ne tested to 5000 .psig. ~, t~ insid~ valve on the choke We ~ the location which was ~ell ' ~' crg.~anzze~, steel ~.m~lded fuel tarf~ not k~um~, rig in good z~, reserve pit well built, and ~11 sign not received frcm Anchorage. tes~md 5000 PSig and tes~bs ~ ouncluded at ]3.:50 AM. A field /ns~on r~ was prepared with the grig~ given to Ken Jc~es, a oopy mailed to Bob ~lines and a copy attacdled to this re~ Kirk t~b, ite, drilling forec~un, advised SS5%~ and SCEV tests would probably be conducted, on NGI-10 during the af~. ~, J~xe_..13,~ .!?..7...7 - Tested SS~ and SCSV c~., Aroo's I,~"I-10. ~y_, J~une...!4, 1977 - Tested SSSV's and SCSV's cn BP's C--2, D-3, E-4, ~h2.- ' sealed ~%bee raises at Arco's COTU. ~ ~, Arco's DS 5-8 -2- July 7, 1977 ~Y~_ ~_~, ~?..7 - I de~ Deadhc~se at 2:30 Pbl via BP charter az~~ ~ ~age'a~' 4:00 PM and at my ~ at 4:30 PM. ~_~_~i: I wi~ su~~~ ~ test at Arco's DS 5-8. Attachment . ~Ka Oil and Gas Conservation Con~., Field Inspection Report Drlg. Permit No. _ ~" ~ Wel 1/~ Sec~ . T~.~.~Pt/~. ~ ~',~_M Operator__~~ ~ Represented by ~ ~ ~ ~~/~,~ Name & Number ~ Satisfactory Typ~p~c~n ~ /~ Satisfactory Type on Yes No Item (~ocation,General Yes No Item (~OPE Tests 5 ' . ( ) (~' 1. Well Sign (~ ( ) 1 ./~asin~ set (~ ( ) 2. General Housekeeping (~ ( ) 16. T~S~ fluid-( )wt~')mud (~Oil (~ ( ) ~. Reserve Pit-( )open( )filled (~' ( ) 17. Master Hyd. Control Sys.-~si~ (~() 4. Rig (~' ( ) 18. N2 btls~,~,~.~/~lg ( ) ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data ( ) ( ) 7. Well Nos. , , , ( ) ( ) 8. Hrs. obser , , , ( ) ( ) 9. BS&W ,-- ( ) ( ) 10. Gr. Bbls. 19. Remote Controls (~)'~ ( ) 20. Drilling spool- a "outlets (~)~ ( ) 21. Kill Li.ne-(~Check valve (~' ( ) 22. Choke Flowline ( ) HCR valve (~)~ ( ) 23. Choke Manifold No. valvs (~'~' ( ) 24 Chokes-(jb)4~emote( )Pos.(~dj'~~ (6J-~' ( ) 25'.. Test Pluo-(~,~Fellhd( )cs.q( )none ( ) , , , 26. Annular Preventer~sio ( ) Final AbandOnment -- (~ ( ) 27. Blind Rams~~io - ' ( ) ( ) 11. P&A Marker (~)~() 28. Pipe Rams,i~m~siq ( ) ( ) 12. Water well-( )capped( )plugged ((J~() 29. Kelly & Kelly-coc~~psio ( ) ( ) 13. Clean-up (~ ( ) 30. Lower Kelly valve~~p~ip" ( ) ( ) 14. Pad leveled (~,~() 31. Safety Floor valves--L~- ~ (~rt Total inspection observation time_J~ hrs/d~ Total number leaks and/or equip, failures Remarks CC fy in days or when ready InSpected ,~7~;~,' ~,,~,;~,~ ,~;L' ;,~ ~,,',~,' ~,..:~ ,,,, .,, ~::,,,~ ~,~,: ~ :~,' ,, ,,; ,',,,. :,, ~, ,,,~.~,,,~ ,~...,, ~ ~, ", ~ ~ ,~:,,,~ ~ ,~,'~ ~ ~,,,,~.~ .~ ,~, ,,. ~,~ ,~,~ ,~ ~.,. ;~, ,~,:~ ,~,~ ~ ,,,~,, ~,~,~, ,,., ,, ~ ~ ~,, 1977 Atlantic Rx--chfie]xt Permit No.. 77-24 Atlantic P~ckfield ~ AnChorage, Alaska 9'9501 Sir: Enclosed is ~ a~ appticatic~ f~r permit to drill the above referenced. ,all at a location in Secti~'on 6, Township 10Al, Range 15E, U.M. Many rivers ~ ~ ~ their drainage sys~ have ~ classified as L~t for ~ ~i~ or migratio~ of anadr~ fish. Operations in ~ areas are subj~ ~ ~ 16.50.870 and t~e .requlatic~s ~gated thereur~ (Title 5, ~ ~__strati~ ~x~e). Prior to ou~x~ing opera~tions you n~y be c~n~ by ~ Habitat Coord~'s offioe, De~- m~nt of Fish ~ ~. ~llution of any waters ~ ~ State is pro~/bited by ~S 46, Chapter 03, ~cicte 7 ~ t/~ re~ ~~~ pr~gated ther~ (Title 18, Alaska Admin/strative ~, ~ 70) ~ by the Federal Water Pollution Cc~I ~, as ~. Prior ~ ~ing operations you may be ccr~_'a_~ued by a re~tive of ~ De~t of Env~tal Conservation. Pursuant to AS 38.40, ~ Hire Under State Leases, the Alaska Department of ~ is ~~ notif~ of ~ is~ of this permit to drill. ~ aid us ~ schec%aling field ~rk, ~ would appreciate your notifying~ this office within 48 ~s after t~ ~11 is spudded. We would also like to be notified ~ ~ a representative of the Division r~y be present to %<itness test~ of blc~-aput preventer equipment before surface casing shoe is drill~l. P. B. ~ 5-8 (22-6-10-15) -2- June 3, 1977 ~ ~ ev~t of ~~nsi~a or abar~~t please give this office adequa_ te ~ notificatic~ so that w~ may have a witness present. Very truly yours, Depar~nt of Fish and ~, Habitat Sectic~ w/o encl. De~t of Envi_~ntal ~aticn w/o encl. Divisiu~ w/o eric1. AtlanticRichfieldCompany North Amer:~-~n Producing Division North Alas, )istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 3, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 DIR C. GEOL J ..... C.-'ENG J 1 ENG .... 5 f"!, .? : 0:'~-)- I ~1 Rt V J CONFER: Subject: D.S. 5-8 (22-6-10-15) Dear Mr. Hamilton' Enclosed is our Application for Permit to Drill together with the $100.00 application fee and survey plat for the above mentioned well Very truly yours, F. M. Brown District Drilling Engineer /vp Enclosure Form ]13-401 RE'V, 1-1-71 la. TYPE OF WORK SUBMIT IN 'I'I? ATE STATE OF ALASKA OIL AND GAS CONSERVATION COMM~TT~Y ~' ~ !977 PERMIT TO DRILL OR DEE~io 8:PZ! API No. 50-029-20248 6. LEASE I)ESIGNA'IION ANt) SERIAl. NO. O~DL 28329 DRILL b. TYPE OF %~T]LL Ol L GAS ,,T~L L [~ WELL DEEPEN r-l SINGLE MULTII'LE OTHER ZONE [] ZONE [-'-] 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchoraqe, ^laska 4. LOCATION OF WELL Ats"r~28' N & 234' E of SW cr At proposed prod. zone (@-8800'SS) 1410'5 & 99501 Sec 32, TllN,R15E,UM 1350'E of NW cr Sec 6,T10N,R15E,UM 13. DISTANCE IN MIEES AND DIRECTION FROM NEAREST TOW2q OR POST OFFICE* Approximately 5 miles northeast of Deadhorse, Alaska 7. IF INDIAN, ALLOT-lEE OR TRIBE NAME 8. UNIT t?ARM OR LEASE NAME Prudhoe Bay 9. WELL NO. DS 5-8 (22-6-10-15) 10. FIELD AND POOl., OR WILDCAT Prudhoe B..ay-Sadl erochi t 11.SEC.,T, R., M., (BOTTOM tIOLE OBJECTIVE) Sec. 6,T10N~R15E,UM . 12. 14. BOND INFORMATION: TWE Sta.tewidesuret~,d/o, No. Federal Insurance. #8011-38-40 ^mou,t $100,000 17. 15, DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 1350' DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2500' t 16. No. OF ACRES IN LEASE 2501 19. PROPOSED DEPTtl 9325TVD (ll610'MD) 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 64' RKB 23. PROPOSED CASI:NG AND CEMENIING PROGRAM NO.ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OK CABLE TOOLS Rot.ary 22. ;~PPR6~(. DATE WORK 9,'ILL START June 20 ,_1977 "-~IZE O~, HoLE .r ' SIZE 6F 6AsING' WEIGHT. P~R FOOT GRADE , SETT. ING DEPTH Quantity of cement ' '36" 20" 94# H-40. 80' . 550 sx Permafrost II to surfaco .... 1.7%" 13,3/8" 72#.. _ MN-80 2700' Circ to surface-approx 5000 qx 12~" 9-5/8" 47~ MN-gO .llfilO' 2fiNO'+cmf rnlllmn on 1~ ~tag~~rox .. ~ .. & S00-~5 !500 sx) p!,,~ qnn'+co!umn.on -Atlantic Richfield Company proposes to directionally this Well to 11,610 +MD, 9325'+TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. The 17~" conductor hole will be drilled without a Hydril or diverter per your letter of March 24, 1977 approving our request of waiver. A 13-5/8" 5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be pr.essure tested each week and operationally tested each trip. A string of 55" 17~ N80 tubing, packer and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. The well will not be perforated at this time. A non-freezing fluid will be left in .all uncemented annuli within the permafrost interval. IN ~O~ SPACE DESCRIBE PROPOSED PROGRAM: If propo~l is to deepen give data o~ present productive zone and proposed new productive zone. If pro.mi is to d~ o~ deepen dkectionally. ~ve ~rt~ent data on subs~face locations and measured anti true vertical depths, Give blowout preventer pm~am. 24. I here~fE that the Foregoing is True and Correct // Dist. Drilling Engr. DATE 7 '~ TITLE (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED MUD LOG []YES [] NO ] []YES DIRECTIONAL SURVEY REQUIRED [~Yes [] NO CONDITIONS OF APPROVAL, IF ANY: OTIIER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-029-20248.~ PERMIT NO. , 7,7-2,4, APPROVAL DATE APPOVEDBY ~~'~: g~-"~,~ TITLE *See Instruction On Reverse Side June 3, 1977 DATE June 3, 1977 SEC. 31 SEC. 6 Well We Well 6 We 15 Well 14 WEST DRILL PAD Well 13 Well 12 ~.._We I I · \\Well I0 ~ gWell 8 ~ Well 259' In~ell No. 18 AT ?0' 16':.'~().U5'5" Y t) D4. U 7C:5.14 ~L, NG. t48024'23.920'' X 697 ,,)35.49 Well No. 17 LAT. 70') 5'59.8(.)1" LONG. 148° 24'23.188" Well No.16 LAT. 70° 5' 58.647" LONG 148° 24'22.462" Well No. 15 LAT. 7(_)c 5'57.495" LONG. 148° 24'?1.735 Well No. 14 LAT. 70° 5'56.334" LONG· 148° 24'20.999" Well No.13 LAT 70° 5' 55. 183" LONG. 14d;~' 24 202C, F, Well No. 12 LAT 70° 5 LONG. 148~ 24 Well Nc. II L AT. 70° 5 LONG. 14U° 24 Well Nc. lO Y q 949 646.72 X 697 OG 3.69 Y 5 !)49 53().13 X F, 97 09168 949 413.71 097 I IV.7 I Y 5 949 296.3,5 X CUT 48.L,u Y 5 U49 80.05 X 'C:37 75.35 '54.(928" Y 5 94U 003.31 ' i"3 5C()" X 697 20 3.06 '52.875" Y 5 '.¢48 946./4 '18.826" X 697 2ZI.93 LAT 70° 5'51 FIG" L_~?NG. 148° 24' 18 114" Well No. 9 LAT 70° 15' 50 !~67" LONG. 148° Well No. 8 LAT. 70j 15'4'J 41 i Et)NC. 148 '~ 24'iG Well No. 7 LAT 7'-'" lg'4t 256" LONG. 14Rn 24'15 Y,,~- ')48 ;s29.61 X 69 7 259.47 Y 5 948 ,'1&.50 X ,;97 f87.86 948 SL~G.AO f-,)"515.98 Y 5 '.-)48 4./9 .'.)1 X 607 343.72 SEC.32 Seciion Line SEC. 5 CERTIFICATE OF SURVEYOR HEREBY CERTIFY ThAT I AM PROPERLY REGIS- TERED AND LICENSED TO PRACTICE LANDSUR- VEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY ~UPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. 4,/I ./?,,.' DATE ATLANTIC RICHFIELD CO. AS - BUILT DRILL SiTE No. 5 Locai'ed in Protracted Sections 31 &32, TllN ,R15 E, UMIAT MERIDIAN, ALASKA ~ PREPARED BY t~iEWlT-f"V. LOUNDSBURY & ASSOCIATE', 725 W 6th AVENUE,,~NCHORAGE~ ALASKA DATE APR._II3_~.!9__'/'_7- SCALE I"= 300' CHKDBY GDD FLD. BK 77-2 CHECK LIST FOR NEW WELL PERMITS Company ,, Yes No Remarks 1.Is the permit fee attached ...................... Lease & Well No. 2. Is Well to be located in a defined pool .............. X~a~ 3. Is a registered survey plat attached ................. /fY~J~ 4. Is well located proper distance from property line ......... y/~a~ 5. Is well located proper distance from other wells ........... K~ 6. Is sufficient undedicated acreage available in this pool ...... _.. yfKqJ~ 7. .Is well to be deviated ' ~ 8. Is operator the only affected party ' . ..... 9. Can permit be approved before ten-day wait . ? ' lO. Does operator have a bond in force '. ................ ll. Is a conservation order needed .................... 12. Is administrative~approval needed ................. 13. Is conductor string provided' - . ....... 14. Is enough cement used to circulate on conductor and surface .... ~'q~'5. Will ~"6'~'nt""ti~e in s~urfac'e~and intermediate or Production St:rings . ~" 1'6. Will cement cover all known productive horizons ........... 17. Will surface casing protect fresh water zones ........... 18. Will all casing.give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating -'Test to ! 20. Has DMEM approved Plan of OPeration ............... Additional Requirements' ..~.~ ~'-~ ~.~ ¢.~~.~ ~ Approval Recommended: Geology: ~ Engin-eerin~- HWK ~~,, LCS ~ RAD Revised 11/17/76 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. Company LIBRARY TAPE CURVE SPECIFICATIONS ARCO ALASKA, INC. S.O. # 25270 -- ECC # 1964 Well D.S. # 5-8 Field PRUDHOE BAY County, State NORTH S123P_~..AI.A.qWA Date 5-5-84 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale CN1 LSN1 SSN1 GR1 CCL1 CN2 COMPENSATED NEUTRON LONG SPACED DETECTOR SHORT SPACED DETECTOR GAMMA RAY " CASING COLLAR LOCATOR COMPENSATED NEUTRON PASS 1 PASS 2 CN/MSN 60 - 0 0 - 200 60 - 560 0-100, 100-200 0 - -30 60 - 0 i LSN2 , LONG SPACED DETECTOR " " I 0 - 200 SSN2 ! SHORT SPACED DETECTOR " " 60 - 560 I GR2 I GAMMA RAY " " 0-10o, 100-200 ' CCL2 CASING COLLAR LOCATOR " " 0 - -30 CN3 'i COMPENSATED NEUTRON PASS 3 " 60 - 0 ,, LSN3 LONG SPACED DETECTOR " " 0 - 200 I SSN3 SHORT SPACED DETECTOR " " 60 - 560 · GR3- GAMMA RAY " " 0-100, 100-200 CCL3 CASING COLLAR LOCATOR " " 0 - -30 ,, CNAV t COMPENSATED NEUTRON AVERAGE 60 - 0 D~TE: 511 $/,?.4: TZMS: '7:5 ARCO ,S,L~SK~ T!',,iC,. ;3.S. .;-8 RUN ,3ii 5-5-84 nRUDHO= RAY NO,RT.-; SLOPE,, DEPTH GR1 I_;R2 G,~'3 LSN1 LSN2 LSN3 3SN1 SSN2 SSN3 CN1 CN::2 2N3 CNAV' ?__T_,. ............ ~_.2_.~ ......... -~_.~._':. ........... A. '~ ]: .... ~ '/, .*; i"07'34 ...... 0 0 4~ .~.0 ........... ~,.~,:~ .... x ................ 90.9: ........................... 0.0;' :-" .... :-0,0 ..... 2a2'4 0.0 0.0 2~,9 ~.3 10735. ~. O. t, 5. O.~] 0.0 00.9 0.0 0.0 242.4 0.0 0.0 24.0 8.3 J,__O_Z.~_.6....._,. .............. !::).: ............ ._q_.,_ ............ &L.-. ................ 0..,.0.. .0,..~ ......... .9.....3..._,...7. ............... .9_-_0_. ............... O_.....:._q._.~.~.!_,_?_ ........... 9_,_0_ ......... ...O.._.,.._9__Z_...:~..,_.,_*--~±.P .... .,"., 10737 0 0 4,4 3 0 o 0 90 ~ "' 0 0 0 ~an 6 0 0 3 0 24 7 .5 2'_ · 10742.. O. O, 45. 0,3 0.0 80.3 0,0 0,0 2;27.9 0.0 0.0 25.9' "P,O. · j~.;~.,?~:~,...~ ..................... ~:$~ ....................... 0..,.~..~,.,~ ....... ~ ....... O~,;O~ .... ~ ,~ .... 1. 8 O. 0 O. 0 2 31.0 O. 0 O. 0 Z 6.8 ~. 9 .!.:¢ ............. ~...., ......................... ~ ~ ................. ~_.~ ................. ~..$..., ...................... 0..,...:~ ................ ,~...,..w ............ ......~...,....~ .................. R..,_.~ .................. ~..~...~..........~_~..?.~..J ................ 2.,_.P ............. P..~...R:...._~..Z...~.....~ ......... :.._.~..~....~ ....... ' ........... 10745. O. O. 49. 0.0 0.0 77.5 0.0 0.0 226.8 0.0. 0.0 2$.O 9.3 10746. O. O. 53. O.O 0.0 7¢.4 ~.0 0.0 Z27.8 0.0 0.0 ~7.3 .'9.1 10747. O. O. 52. 3.0 0.0 78.0 0.0 O.O 227,7 0.0 0.0 27.9 9.3 '~ m m -'~ q r' "' D ~ ~ ~ ,~ ~ '~ ~ ¢'1 ' ~ ~ ' ~ ~...R~,..~.~. ............... ~...~ ................ ~.~ ...... ~ :~..~ ......... '~..,..~ ........... ~.~..~ ......... ~ '....~. ~'. ....... ~...~...~ .............. :::.~. ~ .... ~ ::.~..~..~ ............... ~...~....q ................. 0....~.~ ......... ~...~..~....? ......... :?.~_~ ................................ 10749. O. O. 56. 0.0 0.0 76.7 0.0 0.0 2.21.3 0.0 0.0 27.5 ;.2 , 7~ 5 4~ ~ ~ ~ 7 .... ~ ,~ ~ · ~ ~ ~ ~ ~1~ m ~ ~ ~ ~ 0 v . 13751. 46. 4;.... ~.. 73.1 '2.1. 71..5 _~1~.:~ /'I'~.3, ~I;.~, 2~.4 ~9.*` ~.7~ 2s..~ ~~a. ; ~. ~ s. s ;.. ~ ~....~ .... 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'::~' ""~':': '.~&,,,,¢.,,..,,~;,.~.:~:":::"'":: :~:'"::""~'. 8' ......... ~"'"'.:, ~ ......... '9 :~"~: ........, 8~'"'" ............................ .......1 d: ........ 75 41 ....... ~., v .................. · 4 & .......... . *' ~' · 5 ~'~. o~ ,A ........... P 2 ~ ? ~ 1 ~ ,,,,.../ :*'N~'. ': v&,,~::'7~:,._';;:::~'~',. =.~ . v- ~ ~,. . 5 -5 a' ."' ~ ~ .... '4 ''~. ............ ;~.~ ......... ~'""~ ....... ............ ( ...................................... "~"5F~'"2""; ................. ;'~'; ............. ~'"% .......... ~. ~.3 ~7.4 . so..~~.5., zoo'D', zoo.~ .3~.~ 10763 46 43 44 ~I 5 5~ ! 52 ? iul 3 I~5 4 ig5.1 59 5 36 ~3 .3~ 7 5~ 3 'TS'?'~"~'"; ............. ~"4"'; ............. ~"5"; ............... ~'g"; ............... ~,"~'"'~"i3 .............. g')'";"g .................. ~"'~'"';'T-":i'~TT?-'--C~'T;"'~' ....... ~'"~"~"';'"g-"3":¢:"':"~'"'"~'U'T~ ......... ~"'~T"?'":~'~*T/~ .................. '~'37,S'"5 ~ .... ;'0'~ .......... ~"~"; ..... ~ ..... ........ ~.~.~; '''~ ......... ~'"'~ ...... ..... >~ ........... ~1.~ ................ :~ .............. ~ ~"~ ...... ............ ~ ............... ~,~.:~'"~.~:; ......... ~'""~":q, ....... ~ .............. 3~.,~:':' ............ z ..... .~.~:"'~ ........... ~ ......... ~'"'.~:,. ............ ..... ~' ............. 'x'"?:~.~ ........................................... 10766, 45. 43. aq ........ 51 ~ 52'.4 51.,~" 1~1..D tP2.8 19~ ........... ~ ......... ~"~'~,,.~';'"'""'~.0..,.'~ ..... ~9..~ ............................. 3,,~.~'~5:"-'Z ...................... 10767. 67. 4~. 55. 50.1 50.7 51.1 t89.4 193.3 1'9'2.7 39.0 41.2 40.0 40.1 .....1..~ 7~.~ .5 ....... Z'~ .................... 1.~;5"'~' .............. .................... ~""5 ..................... ~'":~ ................... '<'~.~'~ ............ ~:;"~ ..... ....... ;5' ................. '~t.1 .............................. 1~.~-':;: ..... :~ ........ 13.T'f ................... .1 r'5"s~,.~ ......... ..... i ......... ,0.~.?"~ ...... 5 ....... =~9. ,,,'i ....... 3~,~=F'-"5"~'~..,, .:~ .............. : ...... 13769. 1';7. ~5. 95. 4~ ~ LC ~ ¢~ ] .... ....... ,u 1~-'.~ 1:~5.~ I;~ 2 z;' ~ ~ 07 ~ u.:~ ~~1~. ......... t3Z. I~).'T-'~,. ~. ,)'; .... ~'.: ...... .... ~ ............ ~<~.~..T-~ ............... 1~1.~F: ......... 184.o~ ............... :"':'C~.~1.~ .................. :'-'3~.~,'~- .......... ~.~7"-ff ........................... ~0. , . ~.~...Y ...... ~"',~'"".-~ ...........:: ...... ..!...2L~..!.,. ...... !..E5.,. ......... ~. ~..~...~ ......... !. ~ .~..~ ............... ~. ~. ,~.. ~ .............. ~..~.. ~..7. ................ .~..!..~...~ ......... .L2~..~....2_..!..~_5..~.Z_..L?..0.~_~ ...... ~..~...~.2....2L~.._~_...!5.~:t..~_.%2. ..................... 10772 ~'~ 141 t1~ ~7 1 .~1.~. e~.l '2~0.0 '~n!;'9 ~'0~;~ '~.n~ x~,'1 '3t.3 3'i:.'~..' ..... .......................................... ~ ................... .? .............. ~ ...................... e ............. , ...... - ...... ~ ........................................... :.~.....~ ............................. %....~ .................................. ~......:....:C .......... :: ............... :.C.. ~ ....... ~ ........... .~ .......................... : ..... ~.. ............ ~ .' .......... 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'::...:..~_ .........~ ............... ............................................ , ..................................... :,:..~:.~....., .................... . .......... ,.....,.... .~u.8 .~!,~ ~'22,~ 2,:,+.~ ~?~.~ ~5.~ Z5,7' ~'.Z .......................................................................................................................................................................................................................................................... : .............................................. ; ..................... · ........................................... ~077~. ~. ~. ~3. 69·1 ~2.~ 7~.3 ~0.~ ~.1 ~t~.~ ~7.~ ~.1 2~.0 2~.~ ............. ................ ......... :7 :-.::;..... ::.:'...:...::.. ~0777. ~3. ~9.~. 51.~ ~.~ 6~.~ ~0~.~ ~.~ ~03.1 3t.3 ~.~ 3~.3 30.~ "<5'"~"7Y"; ......... ~"'~"% ................ ~'~"'; ........... ~'i""': ............. ~"7";"~. ........... ~"~"T'"~. ............. ~'"~":;":~ ...... ~-~"~T~. ........ ~'~":~'FS'"'~"'~-T::"~ ....... ~"~";""~ .......... 1~7~'., ~ ..... ~7. 1S~ .,.~3. ~ ~1....~. ~'~...o" 1~1.~, ._~5.5 ~-~0.,. ~.~ ~ ~.,,.1 3 ..~.p..~..~.~..~F ........ 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",~;.' ....~'~., :.'.,,,.,. ~'~, · '):.'.'i.' ~ ................. · ........................... ~ , ............................................................................. VV VV VV VV VV VV VV VV VV V V ~V VV VV VV VV ~E RR RR 11 VV EE RR ~ 1i VV EE ~R R~ Ii VV ~E HR ~ II 000000 000000 5555555555 000000 000000 5555555555 O0 O0 O0 O0 55 O0 O0 O0 O0 55 O0 0000 O0 0000 555555 O0 0000 O0 0000 555555 O0 O0 O0 O0 O0 O0 55 O0 O0 O0 O0 O0 O0 55 0000 O0 0000 O0 55 0000 O0 0000 O0 55 O0 O0 O0 O0 55 55 O0 O0 O0 O0 55 55 000000 000000 555555 000000 000000 555555 Yl ~Y Y~ Y~ *STAPT* USER PCA[~ [10707,57002] dOD ,qOhI'rr)~ s~s ~LI0~;34 dbL-79. ,START, }ICE: DSKh: VERi~ 1.005<057> [10707 ,57002] P~INTED: 1~-[)C'I'-79 14:24:59 QUkUE', SWITC~,S: /~'ILk:~'ORT /CUPIES:i /SPACING:i /DI~,,~11':107 74S8 [')AT~. I 6-0CT-79 lb-OCT-79 14:23:45 14:24:18 $OMMARY OF DATA .LE:NGTi4 OE' f~ECUROS; i018 LE,~NGTi4 01;; LAST t~ECURO: 490 S¥IES LEb)G~tH: 62 BiTES ~'ILE NA~tE: EDiT .001 MA,XIMUM PHYSICAL RECORD NEXT FILE NA~E: LENGTH: 1024 TAPE TRAILE~ 01 TAPE NA~,~E: 57002 SERVICE NAME: TAP~2 CONTINUATION NEXT TAPE Ct]~!~ENT5: DATE; 79/10/1~ !~IS TAP~ VERfFICA~ION ~IS~fNG LVP 010,H02 VERIFICATI[]'~. LISTING PAGE,'"' 1 ** REEI, HEADER ** SERVICE NAME DATE :8?/Ob/ 3 ORIGIN : PREVIOUS REEb CO~HE~TS ~bI8 TAPE~ ARCO ABASKA~ INC,~ PRUDHOE BAY D,S, ** TAPE HEADER ** SERVICE NAME DATE :87/06! ORIGIN :7232 ONTINUATIO~ PREVIOUS TAPE : COMMENTS :~IS TAPg~ ARCO ALASKA, INC~, PRUDHOE BAY D,$, #5-8, APl b0-029-20248 EOF ** FILE HEADER FIt,,E NAME )EDIT ,001 VERSION DAT~ : MAX :ILETYPE PREVIOUS FI~E : INFORMATION RECORDS ** ~E~ CONTENTS UNIT TYPE CATE SIZE COD~ CN : ARCO ALAMKA~ INC, P.S., 5 ' 8 PRUDHOE BAY ~:RTH SLOPE 000 000 018 065 000 000 010 000 000 o12 000 000 004 06,5 000 O00 004 065 000 000 00,2 :0~5 O00 000 012 06 § OOO 000 MNEM CONTENTS U 13 IYPE CATE SiZE CODE 0 O0 000 001 Obb LVP 010.H02 VERIFICATI[]N LISTING PAGE 2 ************************************************************************************ * SCHLUMBERG~:R * AbASKA COMPUTING C~NTER ************************************************************************************ COMPANY = ARC(] AbASKA, INC, MAY COUNTY = NORTH SI~OPE 80ROOGH STATE m AbASKA OB NUMBER AT AKCCI 72324: UN NO b DATE: i~O(;G~D~ 11-~A¥-H7 ANALYS~: ~OUG &MITH A$ING ASING FbUID 37~" TO 2733° 13o25~ 'lO 11860' 9,5. 5 TO 10552' C~LIDE 12,25" ~0 11860' SANDSTONE ON 2428' N AND 234" E OF SE C SECTION 32 RANGE 15E bVP O10,HO2 VERIFICATION LI. 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NpH! -999'2500 NRA ~999. 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DEPT RNRA ~C~ NPHI 10728 000o GR -999 2500 NCNb -999 2500 NPH! -999 2500 FCNL -999 2500 NRAT -999 2500 TENS -999 2500 NPHI -999 2500 FCNL -999 2500 NRAT -999 2500 TENS -999 2500 RNRA -999 2500 NPHI FILE TRAILER '1 FILE NAME IEDIT .001 N # ~ tl~ LENGTH { 1024 FILE TYPE NEXT FILE NAME FILE NAME {EDIT ,002 SERVICE NiNE { VERSION # : ENGTH : 1024 :VIOU$ FILE : 2.4141 21,3257 22.7539 mRA~ ~91,0000 'tENS 2.6496 ANNA 1225,0000 OR 24, 3 39.8926 mRA~ 42~,5000 I'~NS ,9375 R~RA 1185.0000 GR 3,7500 ~CNL 42,5049 '999,~500 NRAT -999. 500 TENS -999,2500 RNRA '999,2500 GR '999,~500 NCNb '999, 500 208~,0000 2 6504 1155 0000 2 7793 28 218~ 1933 0000 3.5898 ,, :oooo 9590 82,0000 1600.0000 -999 2500 -999 2500 -999 2500 -999 2500 -99~ 2500 TYPE 2 4 8 9 SIZE i REPR CODE 66 3 ~5 ENTRoY . IJ.N LVP OlO,H02 VERIFICAT]'DN LILTING PtGE 7 0 ! 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API AP1 ID ORDER # bOG TYPE DEPT VT O0 000 CCh P$1 O0 150 CCh PS2 O0 150 CCL PS3 O0 150 DATA ** DEPT 11705,9961 CCh DEPT 11700,2461 CCL DEPT 11600,2481 CCL DEPT 11500,2461 CCh DEPT 11400,2461 CCh DEPT 11300,24~! CCh DEPT 11200,2461 CCh DEPT 11100,2461 CCL DEPT 11000,24bl CCL DEPT 10900,2451 CCL DEPT 10800,2461 CCh DEPT 10728,0879 CCL API AP1 FILE 8IZE CLASS MOD NO, O0 0 0 4 O1 0 0 4 Ol 0 0 4 O1 0 0 4 FiL£ NAME {EDIT ,002 MAXi~..'I)!~ LENGTH : NEXT FiLE NAME: 1024 EOF -1,7822 CCL -1,7822 CCL -1.7334 CCh -1,6729 CC/, -1.757R CCL -1,7822 CC~ -1.5508 CCh -1.6357 CCL -1,6846 CCL -~.9170 CCL -1.6973 CC~ -999,2500 CCh REPR PROCESS CODE (OCTAU) 1 68 OOoO0000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 -999,2500 CCh -999.2500 CCh -2,3511 CCh -2,2637 CCL -2.3760 CCL -2.3535 CCi, '2.2461 CCL -2.3909 CCh '2.4038 CC~ =2,3105 CCh -2.1992 CCL -999.2500 CCD -999,2500 -999,2500 -].4180 =J.5078 -3.$188 -~.30~7 -3,2949 -3,3430 -3.3457 -3.3076 -3,3516 '999,2500 S ATE :87106/ RIGiN :7232 I LV~ OlO,H02 VE~I~'ICATION LISTING PAGE CO~I~U~TIO~ # :01 COMMENTS :bis TAPE, ~aCO ~4AS~, ,~NC,, PRODHOE ~A¥ O,S, #5'8, AP1 50-029-2024~ DATE 187106/ 3 ORIGIN : Eb NAME 172324 ONTINUATION # lO1 N~X? R~£L NAME ~ COMMENTS ~LIS TAP~ ARC() ALASKA, INC.~ PRUDHDE BA~ D.S~ #5-8, AP~ 50-029-20248 SC~LUNSERGEf~ CO~4PUTI. f,~G CLN~f~ 10707,57002 REEL NAf~E: . ,A.L S~;RV1CE NAME: ~;D!T' ~.EEL CtJNTINI]A'TIk)N NU~qBER: O1 PREVIOUS REEL NA~aE: COMMENTS: bis FOR~A/ CUSTOmiZER T A P E DATE: 79/10/1~ TAPE HEADE~ LENGTH: 132 BYTES TAPE NAME: 57002 SERVICE NAME: EDIT ~APE COnTINUATiON N{J~,BER: P~EVIOUS TAPE NAME: C{]~MENTS: 01 DATE: 79/10/lb FILE ,~iEADER LENG'fH: b2 bYTES ~ILE NA~aE: EDiT .001 ~.AX.I(qU.~ PHYSICAL RECORD LENGTH: 1024 PREVIOUS FILE NA?4E: FILE co~t~kN~rs PlAiN PASS ~'1~S%~ TNkiN REPffAT SECUND ~ELL $iIE I.N I' OPY, AT I U t.~ l~EC C P,.D 194 ~YTES ATLANTIC MICHFiELD COMPANY DRILL SiTt, 5-8 PRUDHOE BAY 15E ~[.iB/h SbOPk ~L, ASKA b[LNG~I H -· 450 BLOCKS: 0 1 ENTRY 0 DATtIM SPECIP I. CATION ENTRY lC TO'iL 5VURD~ ONI%'S APl AP1 APl AFI fflbf]~ SIZE EAP PROC 1 DP]PT ~'T o 2 GR CNb (;AP1 42 31 r ~'~' ~,l /~ NPHi CNL PO 42 68 7~ (; 0 4 0 0 1 o8 0 0 ~'~ ~ 4 NRAT CNL C/C 42 42 I f) 0 4 0 0 1 68 O 0 l,~ ~ 5 ~C.N L C~[, CPS 42 ~4 92 0 o ~ o 0 I 68 0 0 ,~ ~..~ ~ 6 ~'CNL CNL CPS 42 ~]4 93 0 0 4 0 0 1 68 0 0 7 GR CNL GAPI 8 NPHI CNL PO 42 68 3 0 0 4 0 0 1 58 0 O 9 NRAT Ch~L C/C .~.0 NCNL CNL CPS 42 34 92 0 0 ~ 0 0 ~ b8 0 0 ~ I FCF~L CN.L CPS 42 34 93 0 0 ~ 0 0 I 68 0 0 DEPTH 1.~51.5.000 11500.000 11400.000 11300.000 11200.000 11100.000 11000°000 10900.000 108O0.000 10700 . 000 10600.000 1O590.000 MN f~CNL GR ['C N b NCNb NCNb NCNb GR I~ CNB .NCNb GR FCNL NCNI,., GR NCNL GR FCNh kCNL NCNL FCNL NCNb ~ C N 1, NCNL VALOE .]2.856 196.911 -999.000 i]0.527 186.615 -999,000 19.986 171.171 -999.000 21.580 204.033 -999.000 24.644 224.36'7 -999.00O 23,296 1,7~.319 584.727 27.58~ 196.91,1 813.899 44 621] 1851757 640.068 155.673 133.848 477.477 78,208 118,833 47].616 77.227 112.827 0.000 71.344 122.2~5 0.000 N P,H 1 GR FCNL NPHI NPH I G~ FCNB .N P ?t I FCNL NPtii (iF, FC NL GR P'C NL N P H I FCNL ~PHi G~ ~'CNL GE ~CNL, GR NP~ 1 GR F CNL NPHI F'C f,~b 29.66O -999.000 -999.000 29,200 -999.000 -999.000 28.460 -999.000 -999.000 23.740 -999.000 -999.000 23.080 -999.000 -999.000 ,31.060 23.541 175.461 28.680 30.650 i98.627 25.980 50,874 202.059 ql .580 153.407 123.981 42.860 1.846 117.975 4 ,]. 960 I .840 0,000 45.100 1..846 0.000 lq~ L~tjN lC NRAT NPH 1 NPMi NPHI NPHI NRAT NPHI NRAT NPHi NPHi NPH/ NPHI NPHi NRAi NPHi VAL, U~ 2.95~ -999.000 ]~. 106 -999.000 3.1,38 -999.000 2.798 -999. 000 2.938 -999. 000 3.220 -999.000 3.106 28.540 2. 970 20,380 3. ~00 43.100 3.818 -5.000 4.066 -5.000 -5.000 **~ N a d 0 N I C NCNb, NCNh RAT N RA'I NCN6 RAT NCNb NC NRAT N C N 6 NRA'f N C N b NkAI' NC Nb NRAI' NCNb ~.,~ A.1~ ~NC N b NRAT vAbuE 5~5.585 -999.000 515.289 -999.000 538.395 -999.000 5~1.501 -999.000 0e7.524 582.I53 -999.000 610.q73 3.144 5'71,.U57 494.20~ 4.098 454.?~0 3,850 458.172 0.000 47U.184 O.OOO