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182-157
• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ' ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ❑ Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ® Service • ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 5/23/2012 • 182 - 157 ' 311 - 282 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 10/4/1982 50 029 - 20831 - 00 - 00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 10/18/1982 - PBU 13 -15 1090' FSL, 1125' FEL, SEC. 14, T10N, R14E, UM • Top of Productive Horizon: 8. KB (ft above MSL): 89' 15. Field / Pool(s): 305' FSL, 5137' FEL, SEC. 14, T10N, R14E, UM GL (ft above MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 348' FSL, 73' FEL, SEC. 15, T10N, R14E, UM 9163' 7991' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 686113 - y 5931130 ' Zone ASP4 10642' • 9217' • ADL 028315 028314 • TPI: x- 682122 y- 5930247 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 681906 y 5930285 Zone- ASP4 None 18. Directional Survey: 0 Yes 0 : 1 No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) _ N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIL / SP / GR, DIL / BHCS / GR / SP, LDT / CNL / GR / Cal, CBL / VDL / GR / CCL N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM To I BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H -40 Surface 79' Surface 79" 30" 350 sx Arctic Set II 13 -3/8" 72# L -80 Surface 2581' Surface 2581' 17 -1/2" 2700 sx Fondu. 400 sx Permafrost 'C' 9 -5/8" 47# L -80 Surface 10209' Surface 8850' _ 12 -1/4" .500 sx Class 'G' 7" 29# L -80 9904' 10639' 8597' 9214' 8 -1/2" 335 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 5 -1/2 ", 17 #, L -80 x 3013' - 9947' 9841' / 8545' MD TVD MD TVD 4 -1/2 ", 12.6#, N -80 E ce EQ DEPTH A RACT AMOUNT A D KIND OF KIND USED ,UN 3 rZU t 9163' - 10350' 35 Bbls Class 'G' A OG 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 4 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes = No Sidewall Core(s) Acquired? ❑ Yes IN No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None 1 ?'J , 1 3DAAS JUN 14 2012 �i,r - `�;,;: I .' ' Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Aeit Submit Original Only • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes IN No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 10230' 8864' None Shublik 10254' 8885' Sadlerochit 10344' 8960' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the • - ing is ue : • •• o the best of my knowledge. Signed: Joe Lastufka itle: Drilling Technologist Date: &AO PBU 13 -15 182 -157 311 -282 Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Takahiro Kosaka, 564 -5994 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. , Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • 13 -15, Well History (Pre Rig Sidetrack) Date Summary 11/20/11 CTU #9 w/ 1.75" CT (CTV =35.6 bbls). Objective: PXA for rotrary sidetrack. RIH w/ 2.5" nozzle assy. Liquid pack wellbore w/ 320 bbls KCI and underbalance w/ 170 bbls diesel. Laid in 35 bbls of 15.8 ppg cement from 10350' to 9100' 1:1 returns. Freeze protect coil w / 36 bbls of 60/40 methanol. Squeezed 6 bbls behind pipe. Cement top is approx at 9650' (within window). 11/22/11 RAN 2.55" CENT & 2" SAMPLE BAILER, SD @ 9163' SLM, OBTAIN SAMPLE OF CEMENT RAN 4.65" CENTRALIZER TO 3500' SLM, NO OBSTRUCTIONS. 11/23/11 T /I /0= 60/50/0+ Temp =S /I CMIT -TxIA PASSED to 4000 psi, MIT -OA to 2000 psi ( RST prep) Pumped 15.9 bbls ambient neat methanol down IA to reach test pressure for CMIT -TxIA. 1st 15 minutes TBG lost 30 psi, IA lost 50 psi. 2nd 15 minutes TBG lost 5 psi, IA lost 10 psi. 30 minute total T /IA= 35 psi /60psi. Bled TxIA pressure (- 10 bbls ). RD from IA RU to OA. 11/24/11 MIT -OA PASSED to 2000 psi ( RST prep) Pumped 3.4 bbls ambient neat methanol to reach test pressure. 1st 15 minutes OA lost 80 psi. 2nd 15 minutes OA lost 30 psi. 30 minute total= 110 psi. Bled OAP ( - 2 bbls) FWHP's= 500/450/10 SV, WV, SSV= S/I MV= 0 IA & OA= OTG . 12/01/11 ELINE TUBING PUNCH AND POWER CUTTER RECORD. INITIAL T /I /O = 230/600/0 PSI. SHOT TUBING PUNCH FROM 9158 -9163. , SHOTS MADE WITH SMALL TUBING PUNCHER, .24" AVERAGE EXIT HOLE, .05" MAX PENETRATION IN OUTER PIPE. LRS PERFORMED FULLBORE CIRC OUT WHILE E -LINE LEFT LOCATION FOR 16 HOUR RULE. SEE FULLBORE AWGRS FOR PUMP REPORT. 12/01/11 T /I /O = 300/300/50 (Circ well to seawater) Pumped 5 bbls of meth down TBG followed by 720 bbls of 110* Fresh Water, followed by 170 bbls of 90* diesel for Circ Out Freeze protect surface lines with 3 bbls neat meth followed by 4 bbls diesel. U -Tubed Tx IA for 1 hr. RDMO. FWHP= 450/450/250 E -Line arrive on location. IA and OA open to gauges. Operator notified. 12/02/11 (ELINE TUBING PUNCH AND POWER CUTTER RECORD). CUT 5.5" TUBING AT 3012.5' WITH A 4.15" POWERCUTTER. FINAL T /I /O = 0/450/0 PSI 04/13/12 T /I /O = 0/0/0. Performed PJSM. Shut MV and SSV. Pressured up to 3500 psi. for 5 min. Verified LTT. Bled pressure to 0 psi. Removed tree cap. Installed lubricator with 5" Gray type K BPV # 613. Performed lubricator pressure test to 250 psi low for 5 min. (passed) and 3500 psi high for 5 min. (passed). Tagged and set BPV at 120 " using no extensions. Attempted to test BPV to 1000 psi. by pumping through IA with triplex. Unable to achieve test with triplex and notified WSL. Verified LTT and rigged down lubricator. 04/15/12 T /I /0= SSV /230/0. Temp= SI. Assist Cameron w/ LPE (Eval TxIA). No AL. IA FL @ surface. Grease Crew pressured up tree w/ diesel to 5000 psi. Tubing hanger test void showed 0 psi. Pressured up IA from 230 psi to 1200 psi w/ AL gas (1600 psi) from 13 -14 in 15 minutes. IA decreased 370 psi to 830 psi in 15 mins. Re- pressured IA from 830 to 1200 psi in 40 minutes. Test void showed 0 psi. Cameron performed a passing 30 min PPPOT -T. IC test void tracked IAP (See Cameron's WSR for details). Bled IA from 1200 psi to 60 psi (gas) in 1.75 hrs. Monitored for 30 mins. WHPs unchanged. Final WHPs= 0/60/0. Page 1 of 2 • • 13 -15, Well History (Pre Rig Sidetrack) Date Summary 04/15/12 T /I /0= 60/60/0 Upon arrival, conducted PJSM. Performed Leak tight test against Master & SSV from top side, 3500 psi. /5 min. pass. Removed tree cap, attached lubricator with test dart, P.T.d against Master & SSV 250 /Iow..3500 /high..Pass. Set test dart. Applied 5000 psi. from top side against test dart upon request by Cameron Personnel (for seal test) Upon completion of P.T., bled tree to 0 psi. and pulled test dart. Removed lubricator, intalled tree cap, P.T.d to 500 psi. With BPV still installed, assisted DHD with applying pressure (jumper line from well 13 -14) to I.A.. Pressure Tested bottom of BPV thru I.A. 1050 psi. for 5 min. Pass (see chart in TRP folder) Upon completion of test, bled I.A. to 60 psi... DHD to complete bleed. TESTED BPV IS STILL SET. 04/15/12 T /I /O= SSV /260/0 Temp =Sl LPE(TxIA) PPPOT -T (PASS) PPPOT -IC RST Prep. LPE: VS set test dart. RU 2 HP BT Stung into TBG hanger test void. (0+ psi.) Bled void to 0 psi. VS pressured tree to 5000 psi. Monitored 30 min. test void pressure stayed at 0 psi. Pressured test void to 5000 psi. VS bled tree to 0 psi. Test void held pressure. Bled void to 0 psi. DHD Pressured IAP to 1100 psi. monitored 60 min. Test void pressure did not increase. Primary and secondary seals are holding. Stung into CSG hanger test void (1000 psi.). void pressure would not bleed off. DHD bled IAP to 60 psi. Test void tracked with IAP. Test void would not bled to 0 psi. Secondary seals are not holding. PPPOT -T: Pressured test void to 5000 psi. Lost 200 psi. in 15 min. lost 75 psi. in second 15 min. (PASS). Bled void to 0 psi. LDS functioned 10/7/11. 04/29/12 T /I /O = BPV /100 /0 Pulled 5x7 calico upper tree asse and installed new 5x7 FMC mod 120 upper master valve for dry hole tree assembly. torqued flanges to 1281 ftlbs. PT connections to 305 psi for 5 min (PASS) high PT to 5042 psi for 5 min (PASS). 05/10/12 T /I /O= BPV /80/0 Temp= SI Pumped 60bbls of diesel down IA, could not reach test pressure. Standby for well support to pull BPV and DHD to bleed well. 05/11/12 T /I /0= 240/250/0 LLR TxIA/MIT OA PASSED to 2000 psi (Sidetrack) Pumped 28 bbls diesel down IA to 2200 psi. Pressure fell off sharply. Established 1.33 bpm LLR @ 1900 psi for 20 mins. Pump 2.8 bbls diesel down OA to test MIT OAP lost 87 psi 1st 15 min, 2nd 15 min lost 30 psi. Bleed OAP to 0 psi. Pumped 5 bbls meth followed by 90 bbls 9.8 brine followed by 2 bbls diesel down TBG. Page 2 of 2 • 1 North America - ALASKA - BP Page 1 off - Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 I End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: DOYON 25 j Spud Date/Time: , Rig Release: Rig Contractor: DOYON DRILLING INC. I UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ' (ft) 5/12/2012 00:00 - 06:00 6.00 MOB P PRE SECURE AND SCOPE DOWN DERRICK. RAISE "C" SECTION. BLOW DOWN LINES. STAGE COMPLEXES FOR MOVE. LOWER CATTLE CHUTE. SKID RIG FLOOR AND SCOPE DERRICK TO HALF MAST FOR MOVE. 06:00 - 17:00 11.00 MOB P PRE ' LOWER DERRICK OVER TO HEADACHE. WALK CASING SHED AWAY FROM PIPE ' SHED. WALK PIPE SHED AWAY FROM SUB. WALK MOTOR COMPLEX AWAY FROM PUMP i COMPLEX. WALK PUMP COMPLEX AWAY i FROM PIT COMPLEX. STAGE RIG COMPLEXES ON PAD IN MOVE SEQUENCE. 17:00 - 18:30 1.50 I MOB N PRE WAIT ON SECURITY ESCORT TO ARRIVE AND AUTHORIZE MOVEMENT. 18:30 00:00 5.50 MOB N PRE PEAK SOW HOOKED TO SUB BROKE DOWN. WAIT ON MECHANIC TO REPAIR SOW. 5/13/2012 00:00 - 07:00 7.00 MOB P PRE MOVE CASING SHED, PIPE SHED AND SUB !BASE FROM V PAD TO DS #13 AND STAGE !ON DS #13. LOAD RIG MATS AND ANCILLARY RIG EQUIPMENT FOR TRANSPORT TO DS #13. CLEAN UP AREA AROUND RIG FOOTPRINT. 07:00 - 08:30 1.50 MOB P PRE STAGE CASING SHED, PIPE SHED AND SUB BASE ON DS #13. UNHOOKED TRUCKS. 08:30 - 10:00 1.50 MOB P PRE ROAD TRUCKS FROM DS #13 TO V PAD. 10 :00 - 11:00 1.00 MOB j N WAIT PRE WAIT ON TRUCKS - ROAD CONDITIONS. 11:00 - 12:30 1.50 MOB N WAIT PRE WAIT ON SECURITY ESCORT TO ARRIVE AT V PAD. 12:30 - 17:30 5.00 MOB P PRE MOVE PIT, PUMP AND POWER COMPLEXES FROM V PAD TO DS #13. 17:30 - 18:00 0.50 MOB P PRE STAGE PIT, PUMP AND POWER C OMPLEXES ON DS #13. UNHOOK TRUCKS. 18:00 00:00 6.00 MOB N WAIT PRE STAND BY ON PAD WAITING ON PAD PREP. 5/14/2012 00:00 - 06:30 6.50 MOB N WAIT PRE WAIT ON PAD PREPARATION. SET RIG MATS. PERFORM MP2 PM'S ON DEADMAN, #1 AND #2 MUD PUMPS, PIPESHED CONVEYORS, CAT ENGINE #3, STABBING BOARD, RIG TONGS, DOG COLLAR, 1 DRAWWORKS, BURGESS DEGASSER, MUD PRODUCT LIFT AND EZ TORQUE HYDRAULIC i CYLINDERS. 06:30 - 10:00 3.50 MOB P i PRE WHILE WAITING ON RIG MATS. CUT 3 X 12'S FOR MOTOR COMPLEX SHIMS, INSTALL WEATHER CUSHIONS BETWEEN PIPE SHED AND SUB. REMOVE JEEP FROM PIT COMPLEX. HOOK UP SOW AND DOZER TO 1 !CASING SHED. 110:00 - 11:00 1.00 ! MOB P PRE CONTINUE TO SET RIG MATS. 11:00 - 12:00 1.00 MOB P PRE STAGE CASING SHED NEAR WELL. MOVE SUB ONTO RIG MATS. 12:00 - 14:30 2.50 MOB P PRE SPOT SUB OVER WELL. 19:00 4.50 t 14:30 MOB P � - ' PRE SPOT & PIPE SHED MODULE TO SUB BASE. 19:00 - 20:00 1.00 MOB P PRE MOVE PIT, PUMP AND POWER COMPLEXES TO RIG MATS. Printed 6/4/2012 11:16:06AM • • 411 North America - ALASKA - BP •. Page 2 0t Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) 1 Start Date: 5/12/2012 End Date: IX3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: I Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date I From - To Hrs ! Task Code NPT NPT Depth Phase Description of Operations -- 1 ( j (hr) (ft) -- 20:00 - 21:00 1.00 RIGU P PRE PJSM. RAISED DERRICK TO HALF MAST. 21:00 - 21:30 0.50 RIGU P PRE PJSM. SKIDDED RIG FLOOR. 21:30 - 00:00 2.50 RIGU P PRE PJSM. RAISED CATTLE CHUTE. SPOTTED CASING SHED TO PIPE SHED. SPOTTED PIT AND PUMP COMPLEXES. 5/15/2012 00:00 - 01:30 1.50 RIGU P PRE SPOT POWER COMPLEX TO PUMP COMPLEX. SECURE CATTLE CHUTE. HOOK UP ELECTRICAL INTERCONNECT CABLES AND SERVICE LINES. 01:30 - 03:00 1 1.50 RIGU P PRE LOWER DERRICK "C" SECTION. CONTINUE HOOKING UP ELECTRICAL INTERCONNECT CABLES AND SERVICE LINES. SPOT 500 -BBL OPEN TOP TANK. 03:00 - 07:30 4.50 RIGU P PRE SCOPE DERRICK. RIG UP CIRCULATING LINES FROM SQUEEZE MANIFOLD TO CELLAR. WELL SUPPORT CREW RIG UP HARDLINE AND CHOKE MANIFOLD SKID TO 500 -BBL TANK AND PRESSURE TEST LINE AND CHOKE MANIFOLD TO 4000-PSI. -- - - - - - -- - - -- -- - - -- - - -- 07:30 - 10:30 3.00 RIGU P PRE J HANG KELLY HOSE RIG ACCEPTED AT 10:00 HRS 10:30 - 12:00 1.50 RIGU P PRE TEST SURFACE LINES & INTERCONNECTS T04,000 PSI - REMOVE FLANGES ON OA & IA FOR DOUBLE GATE VALVE INSTALLATION. 12:00 - 14:30 2.50 RIGU P PRE INSTALL DOUBLE GATE VALVES ON OA & IA - R/U TO TEST 133/8" x 95/8" ANNULUS 14:30 - 15:00 0.50 RIGU P PRE PRESSURE TEST LINES TO 2,500 PSI 15:00 - 16:00 1.00 RIGU P PRE PRESSURE TEST 13 3/8" x 9 5/8" ANNULUS - TEST PASSED - 250 PSI LOW / 2,000 HIGH FOR 5 / 30 MIN 1 CHARTED - LOST115PSIIN1ST15MIN - LOST 40 PSI IN 2ND 15 MIN 1 16:00 - 17:00 1.00 RIGU P PRE RIG UP DSM LUBRICATOR & PRESSURE TEST 1- 250 PSI LOW & 3,500 PSI HIGH FOR 5 / 5 MIN CHARTED 17:00 - 17:30 0.50 RIGU P PRE I PULL BPV WITH DSM LUBRICATOR 17:30 - 18:00 j 0.50 RIGU P PRE RIG UP TO REVERSE CIRCULATE 18:00 - 21:00 3.00 RIGU P PRE 1REVERSE CIRCULATE 404 BBLS OF 90 DEG 9.8 PPG BRINE - 3 BPM, 80 PSI - NO LOSSES WHILE REVERSE CIRCULATING - VISUALLY INSPECT BOP RAMS & ANNULAR PREVENTER. 21:00 - 21:30 0.50 RIGU ! P PRE PERFORM H2S & RIG EVACUATION DRILL WITH MARMON'S CREW - PERFORM AAR ON DRILL 1- MONITOR TUBING & IA PRESSURE = 0 PSI 21:30 - 22:00 0.50 RIGU P 1 PRE BLOW DOWN & RIG DOWN REVERSE ;CIRCULATING LINES. 22:00 - 23:00 1.00 RIGU P PRE I RIG UP DSM LUBRICATOR & PRESSURE TEST - 250 PSI LOW & 3,500 PSI HIGH FOR 5 / 5 MIN CHARTED. 23:00 - 23:30 II 0.50 RIGU P PRE INSTALL "K" TYPE BPV WITH DSM LUBRICATOR - R/D DSM LUBRICATOR. Printed 6/4/2012 11:16:06AM North America - ALASKA - BP • Page 3 • Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) 23:30 - 00:00 0.50 RIGU P J PRE PRESSURE TEST CIRCULATING LINES TO SQUEEZE MANIFOLD. - 250 PSI LOW & 2,000 PSI HIGH FOR 5 / 5 MIN CHARTED. 5/16/2012 00:00 - 01:00 1.00 BOPSUR P PRE PERFORM ROLLING PRESSURE TEST ON 1 THE IA TO 1000 PSI FOR 10 MIN. MONITOR TUBING PRESSURE DURING ROLLING TEST; NO PRESSURE OBSERVED. PUMPED AT 1.3 BPM TO MAINTAIN 1000 PSI. - 31 BBLS PUMPED, 2.3 BBLS RETURNED. - WTI, APPROVED LEAK TIGHT TFST OF BPV AS BARRIER. 01:00 - 02:30 1.50 BOPSUR P PRE B/D LINES AND RIG DOWN. - MONITOR IA FOR 30 MIN 02:30 - 05:00 2.50 BOPSUR P PRE N/D TREE AND ADAPTER FLANGE - PICK TO RIG FLOOR AND L/D THROUGH BEAVER SLIDE 05:00 - 06:00 1.00 BOPSUR P PRE CLEAN FLANGE SURFACE, INSPECT ITHREADS, MAKE TUBING HANGER !CROSSOVER DUMMY RUN, AND FUNCTION LDS, INSTALL TEST DART IN BPV 06:00 - 10:00 4.00 BOPSUR ! P PRE N/U BOP STACK - INSTALL 13 -5/8" OFFSET DOUBLE STUDDED ! ! ADAPTER AND 1.5' SPACER SPOOL - INSTALL 14' 13 -5/8" HIGH PRESSURE RISER 10:00 - 12:00 2.00 BOPSUR P PRE INSTALL CHOKE AND KILL LINE, FLOW LINE, JOE'S BOX, BELL NIPPLE RISER, STRIP -O- MATIC, AND DRAIN LINES. - CHANGE OUT 4" XT39 SAVER SUB TO 5" 1 4-1/2 IF. - RIG UP HOLE FILL LINE TO IA - STATIC LOSS RATE 20 BPH 12:00 - 14:30 2.50 BOPSUR P PRE RIG UP TO TEST BOPE WITH 5 -1/2" TEST JOINT - CLOSE UPPER 2 -7/8" X 5 -1/2" VBR AND TEST j- COULD NOT GET GOOD TEST ON 5 -1/2" NEST JOINT WITH VBR'S - -- -- - -- - - - -- 14:30 16:30 2.00 BOPSUR N SFAL ! PRE CHANGE OUT UPPER AND LOWER 2 -7/8" X 5 -1/2" VBR'S TO 4-1/2" X 7" VBR'S 16:30 - 00:00 7.50 BOPSUR P PRE TESTED RAMS TO 250 PSI LOW / 4000 PSI HIGH FOR 5 MIN EACH WITH 5 -1/2 "TEST JOINT. ALL TESTS CHARTED. SEE BOP TEST ATTACHMENT. - TROUBLESHOOT LEAK ON UPPER IBOP. 5/17/2012 00:00 - 05:30 5.50 BOPSUR N RREP -0.29 PRE i CHANGEOUT UPPER IBOP ON TOP DRIVE - REMOVE: SAVER SUB TO LOWER IBOP COMP RING, LOWER IBOP TO UPPER IBOP COMP RING, SAVER SUB, LOWER IBOP, ACTUATOR SLEEVE & YOKE, UPPER IBOP TO QUILL COMP RING, UPPER IBOP. 1- INSTALL: NEW UPPER IBOP & SAVER SUB, LOWER IBOP & SAVER SUB COMP RINGS 05:30 - 06:00 0.50 BOPSUR P PRE MAKE UP 5" TEST JOINT - FILL STACK AND 5" TEST JOINT. Printed 6/4/2012 11:16:06AM • North America - ALASKA - BP • Page 4 - Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay Site PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. ! UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 06:00 - 07:30 1.50 BOPSUR P (ft) PRE CONTINUE TESTING BOPE. TESTED ANNULAR TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MIN EACH WITH 5" TEST JOINT. TESTED RAMS TO 250 PSI LOW / 4000 PSI HIGH FOR 5 MIN EACH WITH 5" TEST JOINT. ALL TESTS CHARTED. SEE BOP TEST ATTACHMENT. 07:30 - 08:30 1.00 BOPSUR P DECOMP tRIG DOWN BOPE TEST EQUIPMENT I- B/D TOP DRIVE & KILL LINE __ INSTALL PS21 HANDSLIP INSERTS. 08:30 - 15:00 6.50 WHSUR P DECOMP I PREPARE FOR CUT & SLIP OF DRILLING LINE 1- PULL 750' OF DRILLING LINE & STAGE ON RIG FLOOR. - HANG BLOCKS. - SLIP 750' OF DRILLLING LINE ONTO DRUM. - STAGE 300' OF DRILLING LINE ON RIG FLOOR. - SLIP ON 1,050' OF NEW LINE ONTO DRAWORKS DRUM. 15:00 - 16:30 1.50 WHSUR P DECOMP HOLD PRE -SPUD MEETING WITH WELL ENGINEER M. RIXSE, WSL M. DINGER, AND RIG CREW 16:30 - 19:30 3.00 WHSUR P DECOMP SCUT 1,800' OF DRILLING LINE OFF OF DRUM 19:30 - 22:00 2.50 WHSUR P DECOMP j PICK UP DUTCH RISER & DSM LUBRICATOR TEST TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MIN CHARTED _ 22:00 - 00:00 2.00 WHSUR P ! DECOMP PULL TEST DART & LUBRICATE OUT TYPE "K" BPV - DISCONNECT LUBRICATOR AT QUICK CONNECT TEST SUB - PULL TEST DART WITH T -BAR - INSTALL LUBRICATOR & TEST QUICK CONNECT TEST SUB TO 250 PSI LOW, 5000 PSI HIGH FOR 5 MIN H LUBRICATE OUT TYPE "K" BPV. 5/18/2012 00:00 - 01:00 1.00 WHSUR P DECOMP R/D LUBRICATOR AND DUTCH RISER. 01:00 - 03:00 2.00 PULL P DECOMP MAKE UP 5 1/2" ITCO SPEAR BHA #1 TO 5" DRILLPIPE - ENGAGE TUBING HANGER WITH SPEAR - BLEED OFF CONTROL LINES AND BACK 1 OUT LDS - PULL TUBING HANGER FREE WITH 160K (106K OVERPULL) UP WT 54K 1 - UNSEAT HANGER AND MONITOR WELL FOR 10 MIN 03:00 - 04:30 1.50 PULL P DECOMP PULL SPEAR AND TUBING HANGER TO RIG ODE - DISCONNECT CONTROL LINES FROM HANGER - UD SPEAR AND TUBING HANGER M/U CROSSOVER TO HEADPIN 04:30 - 05:00 0.50 PULL P DECOMP I CIRCULATE 40 BBL SAFE SURF -O SWEEP FOLLOWED BY 280 BBLS 9.8 PPG BRINE - 330 GPM / 200 PSI - MONITOR WELL FOR 10 MIN 05:00 - 06:00 1.00 PULL P DECOMP RIG DOWN CIRCULATING LINES & RIG UP SCHLUMBERGER CONTROL LINE SPOOLER I - INSTALL 5 1/2" PS21 SLIP INSERTS. Printed 6/4/2012 11:16:06AM . • North America - ALASKA - BP • Page 5 ofij'3 , , . Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 5/12/2012 I End Date: X3- 010QT -C: (14,050,453.00 ) I Project: Prudhoe Bay ' Site: PB DS 13 Rig Name /No.: DOYON 25 ', Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date I From - To Hrs Task I Code NPT NPT Depth Phase I Description of Operations 06:00 - 11:00 5.00 PULL 1 P r DECOMP PULL OUT OF HOLE WITH 5 1/2" 17# LTC 8 ! ROUND TUBING AND CONTROL LINE FROM 3 013' MD TO 867' MD 11:00 - 11:30 0.50 PULL P DECOMP LAY DOWN CAMCO SSSV & RIG DOWN ! SCHLUMBERGER CONTROL LINE SPOOLER 11:30 - 14:00 2.50 PULL P DECOMP • LL • T • F H • LE WITH 5 1/2" 17# LTC 8 , ROHM) TI B LNG FROM 867' MD TO SURFACE I I- TOTAL OF 79 JOINTS OF 5 1/2" TBG., CAMCO ' SSSV, AND 3.14' CUT JOINT RECOVERED ! (6.375" OD FLARE) ,- 29 STEEL CONTROL LINE CLAMPS AND , i PINS, 4 STEEL BANDS (2 ON HANGER AND 2 ION SSSV NIPPLE) RECOVERED. - CLEAR & CLEAN RIG FLOOR. 14:00 - 15:00 1.00 PULL P DECOMP INSTALL WEAR BUSHING ! - LOSSES AT 7 BPH 15:00 - 15:30 0.50 CLEAN P ! DECOMP PICKUP CLEANOUT ASSEMBLY FROM i _ BEAVERSLIDE & STAGE ON RIG FLOOR 15:30 18:00 2.50 CLEAN P DECOMP MAKE UP CLEANOUT ASSEMBLY BHA #2 - M/U 81/2" MILL, 2 BOOT BASKETS, 9 5/8" CASING SCRAPER, BIT SUB, BUMPER SUB, AND OIL JARS TO 36' MD - RIH WITH 18 JOINTS OF 5" HWDP TO 596' MD 18:00 - 22:30 4.50 CLEAN P DECOMP RUN IN HOLE ON 5" SINGLES FROM 596' MD ;TO2,996' MD - P /UWT= 124K, S/OWT= 127K i - FLUID LOSS OF 20 BPH 22:30 - 23:30 1.00 CLEAN P DECOMP ! I TAG TOP OF 5 -1/2" TUBING STUB AT 3,017' MD PICK UP & RECONFIRM TAG - P/U TO 9 -5/8" EZSV SETTING DEPTH AT 2,781' MD - RECIPROCATE AND ROTATE WHICLE CIRC 3 SURFACE TO SURFACE VOLUMES I I - 650 GPM, 1,050 PSI 20 RPM, TQ = 1K PUMP 30 BBL HI-VIS SWEEP AFTER 1ST SURFACE TO SURFACE VOLUME WAS PUMPED; NO INCREASE IN CUTTINGS RETURNED I - B/D TOP DRIVE & MONITOR WELL FOR 10 MIN 1 23:30 - 00:00 0.50 CLEAN P DECOMP POOH WITH CLEANOUT ASSEMBLY TO 2,677' MD - LOSSES AT 20 BPH 5/19/2012 00:00 - 01:00 1.00 CLEAN P DECOMP POOH WITH CLEANOUT ASSEMBLY FROM 2,677' TO 596' 01:00 - 01:30 0.50 CLEAN P DECOMP j STAND BACK 5" HWDP AND UD CLEANOUT IASSEMBLY j - 1/2 CUP OF DEBRIS RECOVERED IN BOOT BASKETS 01:30 - 02:00 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR 02:00 - 02:30 0.50 EVAL P DECOMP HOLD PJSM FOR RIGGING UP ELINE AND RUNNING LOGGING TOOLS 02:30 - 05:00 2.50 EVAL P DECOMP ! R/U SLB ELINE AND M/U GR / CCL / SONIC / ISOLATION SCANNER LOGGING TOOLSTRING , 05:00 - 10:30 5.50 EVAL P DECOMP IRRIH WITH LOGGING TOOLS ON E -LINE. LOG FROM 3000' WLM TO SURFACE. - LAY DOWN LOGGING TOOLS _ - DISCUSS LOGGING RESULTS WITH TOWN Printed 6/4/2012 11:16:06AM ip North America - ALASKA - BP • Page 6 • Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 I End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay T, Site: PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task 1 Code j NPT NPT Depth Phase Description of Operations (hr) (ft) j 10:30 - 15:00 4.50 EVAL P DECOMP MAKE UP & RIH WITH 9 5/8" EZSV AND - SETTING TOOL ON E -LINE - SET EZSV AT 2,656' WLM 15:00 - 15:30 0.50 EVAL P DECOMP 1PRESSURE TEST EZSV & 9 5/8" CASING - TEST TO 250 PSI LOW, 5 MIN / 2,000 PSI HIGH, 30 MIN CHARTED. WTL APPROVAL TO CONTINUE OPERATIONS 15:30 - 17:00 1.50 EVAL P DECOMP R/D SLB E -LINE UNIT AND TOOLS 17:00 - 19:00 2.00 PULL P 1 DECOMP MAKE UP 95/8" CASING CUTTER ASSEMBLY M/U MULTI STRING CUTTER, XO, STABILIZER, PUP JT & HWDPTO 583' M D. _ 19:00 - 22:00 3.00 PULL P DECOMP SINGLE IN HOLE WITH DRILLPIPE RIH FROM 583' MD TO 2,194' MD. j- MONITOR WELL ON TRIP TANK. 22:00 - 23:00 1.00 PULL P DECOMP CUT 9 5/8" CASING AT 2,250' MD P/U = 105K, S/0 = 112K - OPEN KNIVES WITH 3 BPM / 150 PSI AND LOCATE 9 -5/8" COLLARS AT 2220' AND 2263' - CUT CASING AT 60 RPM, 1.5K FREE TORQUE, 5.5 BPM @ 700 PSI, TORQUE = 3 -5K i- OBSERVED GOOD INDICATION OF CUT WITH TQ DROPPING OFF TO 1.5K AND PRESS ON OA INCREASING TO 300 PSI 23:00 - 00:00 1.00 PULL P DECOMP ESTABLISH CIRCULATION THROUGH CASING , CUT. - OPEN OA TO FLOWBACK TANK ' I I - CLOSE ANNULAR AND ESTABLISH CIRCULATION I- PUMP 3 BBLS AT 2 BPM / 200 PSI. - CLOSE OA AND RIG UP LITTLE RED TO CEMENT LINE, PT LINES TO 3,500 PSI. 5/20/2012 00:00 - 02:00 2.00 PULL P DECOMP I CIRCULATE 120 DEG DIESEL DOWN DRILL PIPE & INTO OA WITH LITTLE RED - OPEN ANNULAR AND CIRC 35 BBLS OF 120 DEG DIESEL TO CSG CUTTER @ 2 BPM / 200 !PSI. - STOP CIRCULATION, SHUT IN ANNULAR, OPEN OA TO FLOWBACK TANK - PUMP 100 BBLS OF DIESEL AT 2 BPM / 500 PSI - OBSERVE DIESEL CHANNELING, SHUT DOWN AND LET SOAK FOR 20 MIN H PUMP REMAINING 31 BBLS OF DIESEL 1 - PUMP A TOTAL OF 131 BBL 120 DEG F DIESEL AT 2 BPM / 500 PSI. 02:00 - 03:00 1.00 PULL ; P r DECOMP SHUT IN OA & ALLOW DIESEL TO SOAK ARCTIC PACK IN OA. - R/D LRS HOT OIL UNIT. 03:00 - 05:00 2.00 PULL i P DECOMP I CIRCULATE OUT DIESEL AND ARCTIC PACK j TO FLOWBACK TANK. - DISPLACE DIESEL WITH 135 BBLS 9.8 PPG HEATED BRINE AT 3 BPM / 180 PSI - PUMP 35 BBLS SAFE SURF -O PILL AT 3 BPM / 220 PSI - PUMP 235 BBLS 9.8 PPG HEATED BRINE AT '2 BPM / 40 PSI j - INCREASE RATE TO 9.5 BPM / 1600 PSI WHEN SAFE SURF -O PILL REACHED SURFACE Printed 6/4/2012 11:16:06AM , • North America - ALASKA - BP • Page 7 • Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 5/12/2012 End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay I Site: PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 05:00 - 05:30 0.50 PULL P j DECOMP OPEN ANNULAR AND CIRCULATE SURFACE TO SURFACE VOLUME 9.8 PPG BRINE 1 - 399 GPM, 1,580 PSI - MW 9.8 IN / 9.8 OUT ' 05:30 - 06:00 0.50 PULL P DECOMP MONITOR WELL FOR 10 MIN (STATIC) _ L_ - R/D CIRULATING EQUIPMENT. ■ 06:00 - 07:00 1.00 PULL P DECOMP [ PULL OUT OF HOLE FROM 2.250' MD TO 583' - P/U SINGLE FROM PIPE SHED PRIOR TO POOH. 07:00 - 08:00 1.00 PULL P DECOMP i S LA WN Y DO 9 5/8" CASING CUTTER I ASSEMBLY BHA #3 " - RACK BACK 6 STANDS OF HWDP. - LID CASING CUTTER ASSEMBLY. 08:00 - 08:30 0.50 BOPSUR P DECOMP CHANGEOUT UPPER PIPE RAMS TO 9 5/8" I RAMS - MOBILIZE 95/8" ITCO SPEAR COMPONENTS & CHANGEOUT PS21 SLIP INSERTS. 108:30 - 10:00 1.50 BOPSUR P j DECOMP TEST UPPER PIPE RAMS WITH 95/8" TEST JOINT I- PULL WEAR RING & INSTALL TEST PLUG. I I- TEST 250 PSI LOW, 4000 PSI HIGH FOR 5 IMIN CHARTED. 10:00 - 11:00 1.00 PULL P DECOMP MAKE UP 9 5/8" ITCO SPEAR ASSEMBLY BHA #4 AND FNGAC SPFAR IN 8 -5 /R" CASING HANGER_ 11:00 - 12:00 1.00 PULL P DECOMP PULL 9 5/8" CASING HANGER TO RIG FLOOR - HANGER PULLED FREE AT 260K, 160K OVERPULL. - PULL HANGER TO RIG FLOOR, P/U WT 100K FOR 9 -5/8" CSG 1- RELEASE & UD 95/8" ITCO SPEAR BHA #4 LID 95/8" CASING HANGER 12:00 - 14:30 2.50 j PULL P DECOMP ; CIRCULATE 160 BBLS HEATED 9.8 PPG j I BRINE, TAKING RETURNS TO OPEN TOP TANK - STAGE PUMPS TO 512 GPM, 1130 PSI 14:30 - 16:30 2.00 PULL I P ! DECOMP PULL & UD 95/8" 47# L -80 BTC CASINSS - RECOVER CENTRALIZER EVERY 4TH JT 16:30 - 17:00 0.50 PULL P DECOMP SERVICE RIG WHILE CLEANING OUT SKATE BACK STOP CHAIN DRIVE 17:00 - 22:30 5.50 PULL P DECOMP PULL & LAY DOWN 95/8" 47# CASING !- L/D TOTAL OF 52 FULL JOINTS & ONE 30.62' CUT JOINT (9.75" OD FLARE OUT) - 13 BOW SPRING CENTRALIZERS 'RECOVERED 22:30 - 00:00 1.50 PULL P DECOMP CLEAR & CLEAN RIG FLOOR 1 , - R/D POWER TONG & CASING RUNNING TOOLS. - CLEAN AND CLEAR RIG FLOOR - CHANGEOUT UPPER PIPE RAMS TO 1/2" X 7' VBR'S. 5/21/2012 00:00 - 02:00 2.00 PULL P DECOMP CONTINUE TO CLEAN RIG FLOOR AND 02:00 03:30 1.50 PULL P DECOMP R/U ST C ARCTIC PACK - R/U STACK WASHER AND JET STACK - ARCTIC PACK RETURNS BLINDING OFF i SHAKERS Printed 6/4/2012 11:16:06AM N orth America - ALASKA - BP Page 8 Operation Summary Report — Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) — (ft) 03:30 - 05:00 1.50 BOPSUR P DECOMP R/U AND TEST 4 -1/2" X 7 " UPPER PIPE RAMS WITH 5" TEST JOINT - PULL WEAR RING & INSTALL TEST PLUG. 1 - TEST 250 PSI LOW, 4000 PSI HIGH FOR 5 MIN CHARTED. 05:00 - 06:00 1.00 BOPSUR P 1 1 DECOMP R/D TEST EQUIPMENT - INSTALL WEAR RING AND UD TEST JOINT 06:00 - 07:30 1.50 CLEAN P ; WEXIT M/U 13 -3/8" CLEANOUT ASSEMBLY BHA #5 - 12 1/4" BIT, BOOT BASKETS, CASING SCRAPER, 12 1/4" STRING MILL, JARS, 8" DC'S. - ATTEMPT TO RIH, TAKING WEIGHT WITH SCRAPER AT WELLHEAD. -POOH 07:30 - 09:30 2.00 CLEAN P WEXIT ; PICK UP SHEAR JOINT & PULL WEAR RING - SUCK OUT STACK. - WORK CASING SCRAPER THROUGH 'WELLHEAD & POOH. - SET WEAR RING & UD SHEAR JOINT. 09:30 - 11:00 1.50 CLEAN P I WEXIT MAKE UP 13 3/8" CLEANOUT ASSEMBLY BHA #5 WITH DC'S TO 238' MD 1 - CHANGEOUT SLIP INSERTS FOR 5" DP 11:00 - 12:00 1.00 CLEAN P WEXIT RUN IN HOLE WITH 133/8" CLEANOUT [ASSEMBLY BHA#5 ON 5" DP TO 1,182' MD 1 TIGHT SPOT ENCOUNTERED AT 1,182'_ MD 12:00 - 12:30 1 0.50 CLEAN P WEXIT I WORK THROUGH TIGHT SPOT AT 1,182' MD TO 1,208' MD - 126 GPM, 40 PSI - 15 RPM, TQ = 2 -8K ! � - P/U WT = 106K, S/0 WT = 110K ! - FREETQ =1K - TAKING 10K LBS FROM 1,184' MD TO 1,188' MD WITH NO ROTATION. 12:30 - 14:00 1.50 i CLEAN P 1 WEXIT I RUN IN HOLE WITH 133/8" CLEANOUT ASSEMBLY BHA #5 FROM 1,208' MD TO 2,250' MD � - TAG 9 5/8" CASING STUMP AT 2,250' MD 14:00 - 15:00 1.00 CLEAN P I WEXIT CIRCULATE & RECIPROCATE FROM 2,248' MD 1 F TO2,218' MD ■ 1 - 595 GPM, 610 PSI - PUMP 40 BBL SAFE - SURF -O PILL AT SAME RATE. 15:00 - 15:30 I 0.50 CLEAN P F WEXIT MONITOR WELL FOR 10 MIN, WELL STATIC - P/U SINGLE TO STAND BACK EVEN STANDS. 15:30 18:00 2.50 CLEAN P WEXIT PULL OUT OF HOLE ON ELEVATORS FROM 2,250' MD TO 798' MD i - ENCOUNTER 8K OVERPULL FROM 1,188' MD _ TO 1,184' MD - - -- - -- - -- ;18:00 - 20:00 1 2.00 CLEAN P WEXIT LAY DOWN 13 3/8" CLEANOUT ASSEMBLY BHA #5 20:00 - 20:30 1 0.50 CLEAN } P I ± WEXIT CLEAR & CLEAN RIG FLOOR � - UD BUMPER & JARS, BOOT BASKETS, FLOAT SUB, XO'S ON RIG FLOOR. 20:30 - 21:00 0.50 EVAL P j i WEXIT HOLD PRE -JOB SAFETY MEETING WITH RIG 1 CREW & SCHLUMBERGER PERSONNEL FOR 4 RUNNING E -LINE LOGGING TOOLS. 21:00 - 21:30 0.50 EVAL P WEXIT P/U WIRELINE TOOLS THROUGH BEAVERSLIDE Printed 6/4/2012 11:16:06AM North America - ALASKA - BP • Page 9 03 Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 End Date: 1X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. ; UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task Code NPT j NPT Depth; Phase Description of Operations (hr) (ft) 21:30 - 23:30 2.00 EVAL N SFAL WEXIT SAFETY STAND DOWN DUE TO DROPPED OBJECT FROM BEAVERSLIDE SEE REMARKS SECTION - HOLD INVESTIGATION WITH BP SUPERINTENDANT ALAN MADSEN, DDI HSE BOB MICK, SLB FSM BRIAN SUNTERLAND, SLB HSE RUBEN VELA. AFTER INVESTIGATION RECEIVED AUTHORIZATION TO PROCEED WITH OPERATIONS. 23:30 - 00:00 0.50 EVAL P WEXIT PICK UP E -LINE LOGGING TOOLS FROM 'BEAVERSLIDE TO RIG FLOOR. 5/22/2012 00:00 - 00:30 0.50 EVAL P WEXIT 1 R/U E -LINE LOGGING BHA WITH GAUGE RING / JUNK BASKET / CCL / GR 00:30 - 02:00 1.50 EVAL P WEXIT RIH WITH LOGGING ASSEMBLY AND TAG 9 -5/8" STUB AT 2246' WLM - LOG FROM STUB TO 1800' WLM - POOH AND UD LOGGING ASSEMBLY 02:00 07:30 5.50 EVAL WEXIT M/U E -LINE USIT LOGGING ASSEMBLY AND I Ls FROM 2240' WLM TO SURFACE. P i 07:30 - 08:30 1.00 CLEAN P WEXIT MOVE 8" DRILL COLLARS FROM ODS TO DS 08:30 - 13:00 4.50 CLEAN P WEXIT 1 P/U 5" DP SINGLES TO 2,180' MD !- POOH STANDING BACK 5" DP FROM 2,180' ' MD TO SURFACE 13:00 - 13:30 j 0.50 CLEAN P WEXIT CLEAR & CLEAN RIG FLOOR - CHANGEOUT FLUSH MOUNT SLIP INSERTS. - STAGE TOOLS FOR CASING SWEDGE BHA #6 13:30 - 17:00 3.50 CLEAN P WEXIT MAKE UP 12 1/4" CASING SWEDGE BHA #6 TO 799' MD - M/U BULL NOSE, 12.25" O.D. CSG SWEDGE, 18" DC'S, 12 114" IBS, JARS, FLOAT SUB. 17:00 - 18:00 1.00 CLEAN P WEXIT RUN IN WITH 12 1/4" CASING SWEDGE BHA #6 ON 5" DP SINGLES FROM 799' MD TO 1,156' MD 18:00 - 20:00 2.00 CLEAN P WEXIT WORK TIGHT AREAWITHSWEDGE - 1156' - 1163' (10K DRAG), 1163' - 1166' (20K DRAG), 1169' - 1173' (25 -30K DRAG) - WORK SWEDGE THROUGH TIGHT AREA 6 TIMES - PUMP AND ROTATE THROUGH TIGHT AREA, 210 GPM / 65 PSI, 20 RPM / 0.5K FREE TQ - REACHING TQ LIMIT OF 20K FT -LBS THROUGH TIGHT AREA - CONTINUE TO WORK SWEDGE WITH 30 1 RPM FROM 1159' - 1174' - FINAL TORQUE THROUGH TIGHT AREAS: 1164' - 1165' (5 -6K TQ), 1166' (9K TQ), 1169' - 1173' (15K TQ) - SHUT DOWN AND RUN SLICK, 1163' - 1165' (5K DRAG), 1166' (18K DRAG), 1169' - 1173' (20K DRAG) ENCOUNTER 5K DRAG WITH 12 -1/4" STABILIZER ACROSS TIGHT AREA 20:00 - 21:30 1.50 CLEAN P WEXIT RUN IN HOLE 12 1/4" CASING SWEDGE BHA #60N5 "DP FROM 1,173'MDTO1,845'MD Printed 6/4/2012 11:16:06AM • North America - ALASKA - BP ip Page 10 oCES- • Operation Summary Report Common Well Name: 13 -15 I AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: DOYON 25 ! Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date 1 From - To Hrs Task j Code NPT NPT Depth Phase Description of Operations (hr) — — (ft) 21:30 - 22:00 0.50 CLEAN P I WEXIT WORK SWEDGE THROUGH TIGHT AREA FROM 1846' - 1851' - INITIALLY 35K DRAG UP AND DOWN, WORK AREA 8X WITH NO IMPROVEMENT - PUMP AND ROTATE THROUGH TIGHT AREA, 210 GPM / 75 PSI, 30 RPM, 1K FREE TQ - WORK TIGHT AREA, TORQUE GRADUALLY DECREASING FROM 15K TO 4K !- SHUT DOWN AND RUN SLICK, 8K DRAG I FROM 1846' - 1851' - ENCOUNTER 1.5K DRAG WITH STABILIZER 'THROUGH TIGHT AREA 22:00 - 23:30 1.50 CLEAN P WEXIT , RIH FROM 1845' TO 2249' WITH NO PROBLEMS - MONITOR WELL FOR 10 MIN - STATIC - MW 9.8 IN / 9.8 OUT -_ 23:30 - 00:00 0.50 CLEAN P i WEXIT POOH ON ELEVATORS FROM 2249' TO 1555' - GO DOWN THROUGH TIGHT AREA FROM 1846' - 1851', 7K DRAG WITH SWEDGE, 1.5K DRAG WITH STABILIZER 5/23/2012 00:00 - 00:30 0.50 CLEAN P WEXIT POOH ON ELEVATORS FROM 1555' - 1155' - GO DOWN THROUGH TIGHT AREA WITH SWEDGE FROM 1161' - 1166' (17K DRAG), 1170' - 1174' (24K DRAG) - 9K DRAG WITH STABILIZER 00:30 - 02:30 2.00 CLEAN P WEXIT , WORK TIGHT AREA WITH SWEDGE - PUMP AND ROTATE THROUGH TIGHT AREA [FROM 1155' - 1175', 210 GPM / 65 PSI, 30 RPM / 0.5K FREE TQ '- FINAL TORQUE THROUGH TIGHT AREAS: [ 1162' - 1166' (6K TQ), 1169'- 1173'(9KTQ) - SHUT DOWN AND RUN SLICK, 1162' - 1166' - 17 ' (9K DRAG) (9K DRAG), 1169' 1 3 G - ENCOUNTER 4K DRAG WITH 12 -1/4" STABILIZER ACROSS TIGHT AREA 02:30 - 03:30 1.00 CLEAN P WEXIT POOH FROM 1178' TO BHA AT 799' 03:30 - 05:00 1.50 CLEAN P WEXIT L/D 12 -1/4" O.D. CASING SWEDGE BHA - NO ABNORMAL WEAR ON SWEDGE OR STABILIZER 05:00 - 05:30 0.50 STWHIP P C WEXIT R/U TO TEST 13 -3/8" CASING - CLEAN AND CLEAR RIG FLOOR 05:30 - 06:30 1.00 STWHIP ! P i WEXIT PRESSURE TEST 13 -3/8" CASING TFST TO 250 PSI LOW. 5 MIN / 2.000 PSI HIGH, 30 MIN CHARTED. - WTL APPROVAL TO CONTINUE OPERATIONS 06:30 - 07:00 0.50 STWHIP P ' WEXIT P/U BUMPER SUB AND JARS. BREAK OUT AND UD. - B/D KILL LINE 07:00 - 07:30 0.50 STWHIP P WEXIT SERVICE AND INSPECT TOP DRIVE AND BLOCKS - L/D CASING SWEDGE AND STABILIZER 07:30 - 08:00 0.50 STWHIP P WEXIT ! P/U MILLS AND FLEX JOINT TO RIG FLOOR 08:00 - 11:30 3.50 STWHIP I P WEXIT M/t1 12 -1/4" MILLING AND WHIPSTOCK ASSEMBLY - WHIPSTOCK, 12 -1/8" WINDOW MILL, LOWER 12" STING MILL, UPPER 12 -1/4" STRING MILL, L MWD, UBHO Printed 6/4/2012 11:16:06AM • North America - ALASKA - BP Page 11 q Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 I End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 111:30 - 15:00 3.50 STWHIP P WEXIT ; RIH WITH WHIPSTOCK / MILLING ASSEMBLYTO 2231' MD I - NO TIGHT AREAS OBSERVED - P/U 133K, S/O 142K 15:00 - 15:30 0.50 STWHIP P WEXIT PULSE TEST MWD AT 612 GPM, 735 PSI 15:30 - 17:00 1.50 STWHIP P WEXIT RIH WITH GYRO ON E -LINE. OBTAIN TOOLFACE AND ORIENT WHIPSTOCK - AZIMUTHAL TOOL FACE 59 DEGREES EAST (OF TRUE NORTH) 17:00 - 17:30 0.50 STWHIP P WEXIT _ - . = • ► I _ PT. T 2251' ET WHIPSTOCK - SET DOWN 27K TO SET ANCHOR - P/U 15K OVERPULL TO VERIFY ANCHOR SET '- 5/0 65K TO SHEAR MILLS OFF OF WHIPSTOCK 17:30 - 18:30 1.00 STWHIP P WEXIT DISPLACE WELL FROM 9.8 PPG BRINE TO 9.3 PPG LSND MILLING FLUID 35n (;PM 27n PSI s t - 18:30 - 00:00 5.50 STWHIP P WEXIT 1 MILL 12 -1/4" WINDOW IN 13 -3/8" CASING ' �, 15 A /i FROM 2220' MD TO 2235' MD - 655 GPM, 530 PSI - 80 RPM, 5 -15K TQ - 5 -12K WOB - MW 9.4 IN / 9.4 OUT i I - P/U = 130K, S/0 = 138K, ROT = 135K SPR'S @ 2201' MD, MW= 9.3 PPG, TIME _ 18:30 HRS #1 MP - 20/30 SPM = 60 / 80 PSI _ 1#2 MP - 20/30 SPM = 60 / 80 PSI MILL 12 -1/4" WINDOW IN 13 -3/8" CASING 5/24/2012 00:00 02:30 2.50 STWHIP I P WEXIT � FROM 2235' MD TO 2244' - 675 GPM, 590 PSI - 70 RPM, 3 -6K TQ - 8 -10K WOB MW 9.4 IN / 9.4 OUT - P/U = 130K, S/0 = 138K, ROT = 135K TOW = 2220' MD, MOW = 2232' MD, BOW = 12244' MD ;640 LBS OF METAL SHAVINGS RECOVERED 02:30 - 06:00 3.50 STWHIP P WEXIT 1 DRILL 20' OF NEW FORMATION TO 2252' MD 1- 676 GPM, 700 PSI - 70 RPM, 5 -9K TQ - 15K WOB - MW9.41N /9.4OUT - P/U = 129K, S/O = 139K, ROT = 135K_ _ 06:00 - 07:00 1.00 i STWHIP P WEXIT PUMP 32 BBL SUPERSWEEP - 676 GPM, 600 PSI - MINIMAL CUTTINGS RETURNED FROM SWEEP Printed 6/4/2012 11:16:06AM North America - ALASKA - BP • Page 12 - Operation Summary Report Common Well Name: 13 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/12/2012 End Date: X3- 010QT -C: (14,050,453.00 ) Project: Prudhoe Bay i Site: PB DS 13 Rig Name /No.: DOYON 25 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 13 -15A actual @89.72ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 08:00 1.00 STWHIP P WEXIT POOH TO 2197' MD. R/U TEST EQUIPMENT I AND PERFORM LOT. - TVD = 2232' MD - 12.5 PPG EMW LEAK OFF PRESSURE (361 PSI SURFACE PRESSURE) - LOT APPROVED BY WTL - R/D TEST EQUIPMENT MONITOR WELL FOR 10 MIN - STATIC - MW 9.4 PPG IN AND OUT 08:00 - 12:00 ! 4.00 STWHIP P WEXIT CONTINUE DRILLING OPENHOLE FROM 2252' TO 2275' MD - 676 GPM, 725 PSI - 80 RPM, 3-4K TQ - 20K WOB - MW 9.4 IN / 9.4 OUT 12:00 - 14:00 2.00 STWHIP P t WEXIT ,WORK MILLS THROUGH WINDOW WHILE CIRC SUPER SWEEP SURFACE TO SURFACE - 675 GPM, 700 PSI 80 RPM, 2-4K TQ MINIMAL CUTTINGS RETURNED FROM SWEEP DRIFT MILLS CLEAN THROUGH WINDOW WITHOUT CIRCULATING MONITOR WELL FOR 10 MIN - STATIC - MW 9.4 PPG IN AND OUT SPR'S @ 2220' MD, MW= 9.4 PPG, TIME = 13:25 HRS #1 MP - 20/30 SPM = 60 / 80 PSI #2 MP - 20/30 SPM = 60 / 80 PSI 14:00 - 17:00 3.00 STWHIP I P WEXIT POOH WITH MILLING ASSEMBLY FROM 2220' TO 873' MD MONITOR WELL FOR 10 MIN - STATIC - MW 9.4 IN / 9.4 OUT 17:00 - 18:00 1.00 STWHIP N SFAL WEXIT SAFETY STAND DOWN FOR INCIDENT INVESTIGATION TEAM ON DROPPED OBJECT FROM 5/21 /2012 18:00 - 19:30 , 1.50 T STWHIP P WEXIT LAY DOWN 12 1/4" WINDOW MILLING ASSEMBLY BHA #7 - STAND BACK HWDP. I- L/D SPIRAL DRILL COLLARS & MILLING ;ASSEMBLY. - ALL CONNECTIONS BROKE OUT AT 48 -50K I TQ - STARTER MILL 5/8" OUT OF GAUGE. - LOWER STRING MILL 1/2" OUT OF GUAGE. - UPPER STRING MILL IN GAUGE. 19:30 - 22:00 2.50 BOPSUR P WEXIT WASH BOP STACK & LAY MILLING ASSEMBLY DOWN BEAVERSLIDE P/U STACK WASHER & FLUSH STACK . '- PULL WEAR RING & FLUSH STACK. FUNCTION ALL RAMS & FLUSH STACK. PUMP THROUGH CHOKE & KILL LINE. 22:00 - 00:00 2.00 BOPSUR P WEXIT I PREPARE FOR BOPE TESTING - CLOSE BLIND SHEAR RAMS AND CHANGEOUT UPPER PIPE RAMS TO 2 7/8" x 5 1/2" VBR'S. - INSTALL TEST PLUG. - FILL STACK, TEST JOINT, & GAS BUSTER. Printed 6/4/2012 11:16:06AM i TREE = GRAY GEN 3 • X �` . WELLHEAD = GRAY ` ` � S NOTES: H2S READINGS AVERAGE 125 ACTUATOR = AXELSON V / D -1 5 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON MI. LDL 06/18/96 INDICATES LEAK BF. E EV = ' ' B9 \ w\ ���� & 1, SCALE@ 5480' 8� 4500'. KOP = 3100' i ' L tum MD 10259' � -------' (A7 r -' Max Angle = 43° @ 6500' : r 2205' 1 OTIS ROM SSSV NIP, ID = 4.562 ` Datum TVD = 8800' SS t + • 3012' —{JET CUT (12/3/11) 13 -3/8" CSG, 72 #, L -80, ID = 12,347" H 2581' I 9158' - 9163' H TBG PUNCH (12/02/11) � � 1 9163' - 10350' - -ITOP OFCMTPLUG (11/20/11) Minimum ID = 3.726 9936 c� / ., � o• 9821' H5.1/2" BOTPBRASSY , 4• ••4 4-1/2" OTIS XN NIPPLE • ■ 4 • •�•�•�4 � � � 9841' -- I9 -5/8" X5 -1/2' BOT3 -H PKR ► 4 . • . • ♦ • ♦ • ►:: :♦ 5 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID= 4.892" I —_ 9852' ► 9852' — I5 - 1/2" X 4 -1/2' XO, ID = 3.958" ► ► 0• 1 TOP OF 7" LNR I I 9904' ® ■ Ill ►�i�i ► ■ •• • 9935' H4 -1/2- OTIS XN NIP, 10 = 3.725" � •�•1 • 9946' --I4 -117' BOT SHEAROUT SUB • 4-112" TBG -PC. 12.6#, N-80, .0152 bpf, ID = 3.958" H I 9947' .. •�i�i +: : 9947' _j— I4 -12" WLEG, ID= 3.958" I Oi ••••••• • • � • � • � • � • � • • i I 9931' —IBM) TT LOGGED 12/31/82 ► ► ► ► 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 10209' ► •••• ■• • � • •4 PERFORATION SUMMARY REF LOG: BHCS on 10/18/82 I ANGLE AT TOP PERF: 33° @ 10234' Note: Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn/Sgz ' DATE • 3 -318" 8 10234 - 10254 S 11/20/11 I 10397' I -{ FISH 27 3 - 318" PERF GUN (SLM) 3-3/8" 8 10352 - 10382 0 12/31/82 41111 I 3 -3/8" 4 10390 - 10400 0 12/12/85 3-3/8" 8 10403 - 10413 0 12/12/85 ! 1 3 -3/8" 4 10414 - 10424 0 12/12/85 I 3 -3/8" 8 10424 - 10434 0 12/12/85 ■ 3 -3/8" 8 10434 - 10442 0 12/12/85 3 -3/8" 8 10446 - 10456 0 12/12/85 7" LNR 29 #, L -80, .0371 bpf, ID = 6.184" —I 10639' 1414114'1-f TD — I 10642' Q4.iiiiiii DATE REV BY COMMENTS DATE REV BY ' COMMENTS I PRUDHOE BAY UNIT 10/22182 ORIGINAL COMPLETION 12/16/11 RWMI PJC TBG PUNCH/JET CUT (12/1 -2/11) WELL: 13 -15 04/23/11 MSS/ PJC PULL HES BB PLUG (04/11/11) 01/16/12 TMN/JMD ADDED H25 SAFETY NOTE PERMIT No: '1821570 05/20/11 SRD/ PJC SET BKR IBP(05/18/11) API No: 50 -029- 20831 -00 • ' 06/02/11 CDJ/ PJC PULL IFB/ SET WRP(06/01- 02/11) Sec. 14, TCN, R14E, 77.95 FEL, 4931,49 FNL 10/10/11 TA/ PJC PULL WRP (10/6/11) 12/16/11 RRW/ PJC P&A PLUG (11/20/11) I BP Exploration (Alaska) a 5 IA ere&o ' DATE: 27-Jun-12 ::,.r-,, -, TRANS#: 5999 Da a elite Services Technician .;i rriiRPRIfi2F714[11TiPl Zi.74301(11M ::', "' ,- ,-; ; . :' ' - i ',:. ',.':-.' ; P:::(''' 1 ' ' r* '':1 II Da i.7 & Consuliing Services . „ ..„ 2'.5 f:3arnbeli St, Ste. 400 Anchorage, 5K 99503 g: 0Mce: (907) 273-1770 SCANNED FEB ? 5 zon - --7 7777,-7 '' - 7 : ''' '' ,7 '''' , ' - ' 777777 . 7 "7" 77 - 7 ''"'nT' ` ' :iq , 7:':: ' ;,0 , ' ' ; 10,0:§,OPNO".,a0_VV,VO:M:: ,';'''' '' A, 'W, ,,`':.'', ::: lf,fk 0 ti t :,' :' ,:: i;V/A* 1110 NAME ORDER # DIST DIST DIST DIST LOGGED PRINTS PRINTS V-229 BBSK-00116 X MDT 8-May-12 1 CD MPS-24 BAUJ-00129 X MEMORY LEAK DETECTION LO 1-Jun-12 1 1 CD V 13-15 C3NA-00019 X USIT/SONIC SCANNER 22-May-12 1 1 CD 13-15 BVYC-00037 X ISOLATION SCANNER 19-May-12 1 1 CD 04-18 C4W7-00015 X _ PRODUCTION PROFILE 26-May-12 1 1 CD _ C-27B C600-00011 X MEMORY LEAK DETECTION LO 5-Jun-12 1 1 CD 06-11 C3NA-00014 X CROSS FLOW W/ IBP 12-May-12 1 1 CD V-229 C3NA-00011 X - USIT/CBL 8-May-12 1 1 CD D-14A C4W7-00012 X SLIM CEMENT MAPPING TOOL 24-May-12 1 1 CD _ - . Z-40 C2JC-00007 X USIT/CBL 27-Mar-12 1 1 CD 1 15-01B C600-00010 X MEMORY PRODUCTION PROFIT 3-Jun-12 1 1 CD • ' X X Please return a signed copy to: Please return a signed copy to: BP PDC LR2-1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 • 4,Ve&data' RECEIVE: Gyrodata Incorporated NOV 01 201! 23000 Northwest Lake Dr. Houston,TX 77095 (281)213-6300 Alaska Oil& Gas Cats.Comnissior Fax:(281)213-6301 Ancnor8gc SGANI46 MAR 1 Z 2018. z-\2°r. \-6 SURVEY REPORT BP Exploration Drill Site: 13; Well 13-15, 4 1/2" tubing Prudhoe Bay, AK North Slope Borough AK0911 GCM192 22 September, 2011 2 Serving the Worldwide Energy industry with Precision Survey Instrumentation gyro/data Gyrodata Incorporated 23000 Northwest Lake Dr. Houston,TX 77095 (281)213-6300 Fax:(281)213-6301 October 17, 2011 State of Alaska -AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 13, Well 13-15 Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, // -1/- Rob Shoup North American Regional Manager RS:fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation • • 0 O O o 7:1 '-cEi cel0 X • 3 z x .a o 0 cu E E °' o x O N U •• 00 v, U d a) o o i tri a' (1) > C v cu cc:1cu U b > M ti W O O Z �-•-�• . N U U U > Q 3 Mt H - Y Lf.i C '> O U z N y Q 3-, 4-4 c� n • "' -a CO 0 a; > U X o Q 0 U v X 2 o o H Ix mi 0 a4 , • U o O w W . o b Q CD ca >00 � � en CA � H a tin C) � z Nx ' U 0 Z 2 •-? E (,1o 0 -o 0 o `~ Ems- o o o a a) o . N Y 0 N N N C/p C W 0 0 id 0 E O en .a ,.i i • ' >. crl >i >. 3>. U L>. C. • • ` W E-: 333 33333 3w www 33 O w t- M O O VO VO M I N 00 D, CD CN v) N a C/] O r- VD Cl N 00 'O Cl VD '- '- Mkin N N k00 W O 'cr O O -- -- -- -- O O O O O O O O H<• H it' Nq w Co• rUx oz W zzz zzzzz zzzzZ ZZ O p„ V0 0 vn N 00 M O O t� a, D, O M N V 00 ,t d- N 00 N v? 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Survey QC - RGS-CCSpecification Sheet gyro/ ata 1 SURVEY QUALITY CONTROL -SPECIFICATION DATA • PRE-JOB CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 64 269.22 628.67 0.00016429 -0.83 63 269.22 633.11 0.00016546 -1.45 62 225.17 -638.39 -0.00015900 -19.34 61 225.17 -632.24 -0.00015747 -21.65 60 45.81 -657.10 -0.00016381 -9.72 59 45.81 -667.61 -0.00016643 -8.27 58 359.40 -2270.01 -0.00054005 -5.90 57 359.41 -2269.83 -0.00054000 -5.55 56 330.17 -1663.43 -0.00040494 0.48 55 330.17 -1659.86 -0.00040407 1.48 54 300.87 -241.21 -0.00006148 2.58 53 300.87 -245.62 -0.00006261 3.18 52 269.55 634.64 0.00016586 -0.67 51 269.55 635.33 0.00016604 -1.27 50 240.74 80.41 0.00002052 -6.82 49 240.74 81.16 0.00002072 -7.01 48 209.88 -1382.36 -0.00033627 -11.69 47 209.87 -1375.33 -0.00033456 -10.43 46 180.60 -2192.34 -0.00052164 -9.71 45 180.60 -2195.41 -0.00052236 -8.90 44 149.90 -1596.72 -0.00038889 -1.38 43 149.90 -1594.35 -0.00038831 -1.02 42 120.46 -204.32 -0.00005211 3.06 41 120.46 -203.38 -0.00005187 3.73 40 89.71 624.99 0.00016334 2.10 39 89.71 626.58 0.00016375 1.54 38 60.35 9.53 0.00000243 -4.91 37 60.35 14.55 0.00000371 -4.75 36 29.84 -1449.31 -0.00035249 -8.51 35 29.84 -1453.83 -0.00035358 -8.12 34 0.08 -2272.79 -0.00054069 -9.17 33 0.08 -2274.32 -0.00054105 -9.31 32 269.42 655.88 0.00017142 -1.19 31 269.43 660.26 0.00017256 -2.74 30 224.89 -634.92 -0.00015807 -18.26 29 224.90 -641.30 -0.00015965 -21.29 28 44.83 -720.96 -0.00017944 -7.46 27 44.83 -715.87 -0.00017817 -8.22 26 0.02 -2252.68 -0.00053593 -3.24 25 0.01 -2257.94 -0.00053717 -3.51 24 329.40 -1618.05 -0.00039433 2.91 23 329.40 -1613.72 -0.00039328 1.19 22 299.93 -184.58 -0.00004711 5.35 21 299.92 -188.06 -0.00004800 5.34 20 270.03 657.06 0.00017173 0.27 19 270.03 655.52 0.00017133 2.10 18 240.23 67.48 0.00001721 -5.17 17 240.23 71.01 0.00001811 -5.39 16 210.91 -1321.47 -0.00032192 -11.82 15 210.91 -1332.04 -0.00032450 -11.93 14 179.79 -2201.68 -0.00052386 -6.11 13 179.79 -2206.78 -0.00052506 -6.37 12 150.32 -1617.31 -0.00039367 -2.14 11 150.32 -1614.96 -0.00039310 -3.30 10 120.72 -226.07 -0.00005764 3.92 9 120.72 -221.06 -0.00005636 2.53 8 90.31 618.78 0.00016171 3.11 7 90.31 619.81 0.00016198 3.86 6 60.09 11.13 0.00000284 -3.71 5 60.09 -0.20 -0.00000005 -3.91 4 31.11 -1396.99 -0.00034036 -7.02 s , SURV-Q167(OPS SUR-MA-003) 19`"Nov 03/Rev 15 Page 1 of 5 AK0911GCM192 • . Survey QC - RGS-C�Specification Sheet jata 3 31.10 -1399.27 -0.00034091 -7.71 2 0.75 -2271.69 -0.00054044 -3.53 1 0.75 -2267.85 -0.00053953 -3.21 MBO = -0.05 Gravity Error = -782.18 Scale Factor Uncertainty = -0.00018668 Rate Error = -4.29 POST-JOB CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 2140 270.07 -404.92 -0.00010563 7.09 2139 270.07 -399.01 -0.00010409 4.47 2138 225.46 -1453.01 -0.00036145 -6.30 2137 225.46 -1448.26 -0.00036027 -10.62 2136 45.49 -1537.51 -0.00038242 -17.50 2135 45.49 -1536.99 -0.00038229 -21.08 2134 0.13 -2898.39 -0.00068848 -12.96 2133 0.14 -2885.37 -0.00068541 -13.58 2132 330.66 -2421.29 -0.00058808 -3.77 2131 330.65 -2420.93 -0.00058799 -2.16 2130 300.93 -1198.24 -0.00030485 6.30 2129 300.93 -1197.53 -0.00030467 6.22 2128 269.64 -395.19 -0.00010309 8.85 2127 269.64 -396.70 -0.00010349 7.54 2126 241.19 -822.73 -0.00020978 2.88 2125 241.19 -821.06 -0.00020935 2.79 2124 210.73 -2036.28 -0.00049517 -3.73 2123 210.73 -2032.97 -0.00049437 -3.71 2122 180.91 -2765.87 -0.00065718 -5.99 2121 180.91 -2765.42 -0.00065707 -6.38 2120 150.01 -2313.87 -0.00056259 -7.47 2119 150.01 -2309.66 -0.00056157 -8.51 2118 120.04 -1115.75 -0.00028425 -1.57 2117 120.04 -1117.96 -0.00028481 -6.64 2116 90.38 -413.32 -0.00010782 -9.93 2115 90.38 -411.02 -0.00010722 -10.07 2114 60.76 -903.52 -0.00023021 -18.65 2113 60.76 -900.72 -0.00022949 -19.70 2112 30.11 -2162.43 -0.00052528 -22.64 2111 30.11 -2159.42 -0.00052455 -23.80 2110 359.99 -2866.01 -0.00068082 -21.12 2109 359.99 -2857.00 -0.00067869 -22.30 2108 269.93 -374.71 -0.00009776 7.38 2107 269.94 -366.20 -0.00009554 4.53 2106 225.27 -1443.52 -0.00035899 -18.84 2105 225.27 -1436.74 -0.00035731 -23.03 2104 45.18 -1532.71 -0.00038105 -24.24 2103 45.18 -1525.53 -0.00037927 -24.47 2102 359.76 -2889.33 -0.00068633 -19.76 2101 359.76 -2886.77 -0.00068572 -19.09 2100 329.87 -2381.85 -0.00057913 -0.10 2099 329.87 -2367.24 -0.00057560 -0.84 2098 300.28 -1158.19 -0.00029495 15.20 2097 300.28 -1157.01 -0.00029465 15.33 2096 269.56 -358.97 -0.00009366 16.00 2095 269.56 -359.63 -0.00009383 16.05 2094 240.41 -843.48 -0.00021483 3.14 2093 240.41 -844.49 -0.00021509 3.19 2092 210.37 -2054.85 -0.00049942 -8.07 2091 210.38 -2046.05 -0.00049730 -8.04 2090 179.96 -2780.82 -0.00066069 -6.33 2089 179.97 -2786.04 -0.00066193 -6.86 2088 150.56 -2322.54 -0.00056427 6.67 2087 150.56 -2321.64 -0.00056405 6.09 2086 121.50 -1147.99 -0.00029186 11.52 : SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 2 of 5 AK0911GCM192 • Survey QC - RGS-C Specification Sheet Wradata 2085 121.50 -1147.96 -0.00029186 11.12 2084 90.80 -281.83 -0.00007354 1.25 2083 90.79 -271.30 -0.00007079 0.59 2082 59.37 -855.63 -0.00021760 -16.91 2081 59.36 -848.46 -0.00021578 -17.37 2080 29.22 -2197.51 -0.00053316 -26.15 2079 29.22 -2191.57 -0.00053173 -26.45 2078 0.70 -2926.65 -0.00069517 -19.68 2077 0.70 -2923.44 -0.00069442 -19.81 MBO = -0.59 Gravity Error= -1599.98 Scale Factor Uncertainty = -0.00039109 Rate Error = -6.28 INITIALISATION Gyro Compass Reading /Station Raw Inclination Raw Azimuth Abs(ERMeas-ERTheo) 107 10.32 260.10 0.0834 108 10.32 260.14 0.0475 109 10.32 260.06 0.0467 110 10.32 260.07 0.0160 111 10.32 260.09 0.0491 112 10.32 260.11 0.0601 113 10.32 260.13 0.0498 114 10.32 260.13 0.0380 115 10.32 260.02 0.0203 116 10.32 260.11 0.0234 Average 10.32 260.10 0.0434 Tolerance on Average* 0.0814 Standard Deviation 0.00 0.04 0.0203 Tolerance on St. Dev.** 0.1° 0.2° 0.0365 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance = TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cosi)*J[(CosA*SinI*0.1)2+0.0821 o/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/CosI)*J[(CosA*SinI*0.1)2+(0.08?/(n-1))) 0/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 396.09 3474.84 15.22 253.25 0.002 -0.003 -0.001 0.000 2 548.88 4099.83 32.07 254.86 0.001 -0.001 -0.000 -0.001 3 770.39 3449.91 14.80 252.91 0.001 -0.002 -0.002 0.001 4 413.23 3149.95 10.36 260.79 -0.000 0.000 -0.001 0.000 Average 0.001 -0.002 -0.001 0.000 Standard Deviation 0.001 0.001 0.001 0.001 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * I Outrun * I Difference Inrun * I Outrun * I Difference r SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 3 of 5 AK0911GCM192 • Survey QC - RGS-likpecification Sheet ` / 100.00 0.21 0.21 0.00 287.41 287.59 -0.18 • 200.00 0.34 0.19 0.15 288.65 289.75 -1.10 300.00 0.37 0.23 0.13 297.67 302.26 -4.59 400.00 0.36 0.43 -0.06 316.45 335.39 -18.94 500.00 0.49 0.63 -0.14 7.87 9.70 -1.83 600.00 0.59 0.55 0.05 14.80 29.17 -14.37 700.00 0.51 0.45 0.05 44.25 47.79 -3.54 800.00 0.42 0.35 0.07 43.89 56.87 -12.98 900.00 0.32 0.25 0.07 62.19 65.41 -3.23 1000.00 0.30 0.16 0.14 23.83 47.98 -24.15 1100.00 0.24 0.08 0.16 28.25 29.12 -0.87 1200.00 0.22 0.30 -0.09 174.73 306.32 -131.59 1300.00 0.63 0.55 0.08 204.51 220.07 -15.56 1400.00 0.66 0.59 0.07 213.17 219.63 -6.46 1500.00 0.56 0.62 -0.06 210.64 223.76 -13.12 1600.00 0.57 0.53 0.03 229.55 227.61 1.94 1700.00 0.48 0.44 0.04 234.40 231.44 2.96 1800.00 0.36 0.42 -0.06 325.72 288.33 37.39 1900.00 0.52 0.41 0.11 339.43 347.94 -8.51 2000.00 0.27 0.37 -0.11 353.98 349.21 4.77 2100.00 0.15 0.33 -0.18 357.11 347.51 9.60 2200.00 0.16 0.26 -0.10 287.07 353.83 -66.77 2300.00 0.09 0.18 -0.09 294.54 0.55 -66.01 2400.00 0.19 0.31 -0.13 59.43 32.26 27.16 2500.00 0.60 0.45 0.15 62.04 65.20 -3.16 2600.00 0.76 0.58 0.18 58.02 61.16 -3.13 2700.00 0.79 0.70 0.09 49.19 55.33 -6.13 2800.00 0.89 1.07 -0.19 311.10 314.15 -3.05 2900.00 4.35 4.16 0.19 272.76 275.13 -2.37 3000.00 7.30 7.13 0.16 266.36 266.21 0.15 3100.00 9.14 8.88 0.26 264.19 264.51 -0.32 3125.00 9.54 9.44 0.10 262.06 262.17 -0.10 3150.00 10.32 10.20 0.12 260.11 260.95 -0.83 3175.00 10.57 10.47 0.10 260.35 260.81 -0.46 3200.00 11.14 11.02 0.12 259.79 260.47 -0.68 3225.00 11.38 11.32 0.05 259.90 260.01 -0.11 3250.00 11.60 11.58 0.02 259.65 259.87 -0.22 3275.00 12.25 12.19 0.05 256.23 256.77 -0.53 3300.00 12.60 12.61 -0.01 254.73 254.91 -0.18 3325.00 12.93 12.91 0.02 253.88 254.02 -0.14 3350.00 13.16 13.11 0.05 253.31 253.57 -0.26 3375.00 13.34 13.30 0.04 253.05 253.22 -0.17 3400.00 13.66 13.69 -0.03 252.84 252.97 -0.13 3425.00 14.19 14.20 -0.00 252.66 252.89 -0.23 3450.00 14.68 14.62 0.06 252.75 252.89 -0.15 • . SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 5 AK0911GCM192 • Survey QC - RGS-C,Specification Sheetgym/data 3475.00 15.27 15.22 0.05 252.94 253.06 -0.12 • 3500.00 16.59 16.41 0.17 251.63 251.95 -0.32 3525.00 17.70 17.62 0.08 250.90 251.01 -0.11 3550.00 18.20 18.17 0.04 250.75 250.89 -0.14 3575.00 18.79 18.79 -0.00 251.23 251.32 -0.09 3600.00 19.30 19.24 0.06 251.76 251.67 0.09 3625.00 19.62 19.63 -0.01 251.88 251.92 -0.04 3650.00 20.01 19.99 0.02 252.27 252.33 -0.06 3675.00 20.53 20.49 0.03 252.72 252.72 0.01 3700.00 20.90 20.87 0.03 252.79 252.86 -0.06 3725.00 21.45 21.42 0.02 253.18 253.20 -0.03 3750.00 22.16 22.07 0.09 253.24 253.27 -0.03 3775.00 22.72 22.70 0.02 253.24 253.28 -0.04 3800.00 23.45 23.43 0.02 253.53 253.53 -0.00 3825.00 23.89 23.84 0.04 253.54 253.60 -0.05 3850.00 24.45 24.42 0.03 253.57 253.59 -0.01 3875.00 25.16 25.10 0.06 253.83 253.85 -0.02 3900.00 25.81 25.71 0.09 253.74 253.71 0.03 3925.00 26.70 26.68 0.03 253.72 253.74 -0.02 3950.00 27.87 27.79 0.08 253.53 253.53 -0.00 3975.00 28.88 28.82 0.06 253.82 253.77 0.05 4000.00 29.46 29.48 -0.02 254.02 253.96 0.06 4025.00 30.13 30.10 0.03 254.19 254.17 0.02 4050.00 30.71 30.67 0.04 254.38 254.28 0.10 4075.00 31.30 31.28 0.03 254.55 254.52 0.02 Average 0.0399 -0.0308 Standard Deviation 0.0860 0.0859 Tolerance for both the Average and the Standard Casing 0.3° Casing 0.50 Deviation Drillpipe 0.3° Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths s as shown. P P • • . SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 5 of 5 AK0911GCM192 • • Survey QC - RGS-CT Analysis Sheet gtf SURVEY QUALITY CONTROL - DATA ANALYSIS REFERENCE SYSTEMS Grid System I Grid Correction 10.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 TVD 0.00 Northings 0.00 Eastings 0.00 Latitude 70.2168 Az. Ref: Grid/True True Grid Corrected Y/N? N Description CALIBRATION Tool Number 6098 I Calibration Date 20 Jun 2011 i OPERATING TEMPERATURE Calibration range From 50.08 To 120.14 Gyro operating range From 74.05 To 75.07 Spec'-Within calibration range FIELD ROLL TEST (Only valid on fixed structures. When not possible input roll test data performed after return to base) Cal value Pre job offset Post job offset Abs dif.cal.post Abs dif.pre.post Spec' Accel Scale 0.000056 -0.000187 -0.000391 0.000391 0.000204 Cal/Post- 0.00015 Mass Unbalance 39.52 -0.05 -0.59 0.59 0.54 Pre/Post- 0.4°/hr INITIALISATION Depth (Approx) 3149.94 No of stns 10 Spec'- Min No. -6 Azimuth Mean 260.10 Std deviation 0.04 Spec' -Azi SD 0.2° Inclination Mean 10.32 Std deviation 0.00 Spec'- Inc SD 0.1° Earth Horizontal Rate Mean (Abs(meas-theor)) 0.04 Std deviation 0.02 Spec'- See Q167 DRIFT TUNE Residual x gyro bias Mean -0.002 Std dev' 0.001 Spec's- Mean and SD - 0.333°/hr Residual y gyro bias Mean 0.000 Std dev' 0.001 Spec's- Mean and SD- 0.333°/hr TOOLFACE RATE Maximum toolface rate 136.97 I Spec'-400°/sec IN/OUT COMPARISON (AZI' N/A IF INC' <15° Inclination Difference Mean 0.04 Std dev' 0.09 Spec's Casing pipe 0.3° Azimuth Difference Mean -0.03 Std dev' 0.09 Spec's- Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 0.53 Spec- 5.0/1000 Vertical Divergence/1000 0.08 Spec'- 2.0/1000 DEPTH CONTROL Wireline Company Schlumberger I Line type 7/32 Encoder SF Schlumberger Max Depth (TD) 4099 CCL Corrected NO Zero Depth (Rig up) RKB @ 89 ft AMSL Rezero Depth +5.5 Given pup joint depth NA Measured P3 NA Strech cor. At TD divided by TD/1000 .8163 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 1.1224 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 ift GAMMA TO PDC LOG Spec'- 2.0/1000 . SURV-Q165(OPS SUR-MA-010)22' Jan 2004/Revision 20 Page 1 of 1 AK0911GCM192 • • Survey QC - RGS-CT Acceptance Sheet FIELD AND SURVEY INFORMATION Operator BP EXPLORATION (ALASKA) INC. Field/ Platform Well Number DRILL SITE 13 13- 15 Survey section From 0 ft. to 4099.ft. Date 20 Sep 2011 • Gyrodata Job No AK0911GCM192 Gyrodata Surveyors Steve Thompson Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation, after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13'Nov 03/Revision 12 Page 1 of 1 AK0911GCM192 >- co ill a) I > > !-1 LII s- _1 o 1-4 0 cp • o Z M • • 0 U- Ln (1.7w (3) 0 0 H - a) NI r < v.) U '• 000 tn eL z U) U •• 0, 0_ o a) U) < N 0 0 rn 4-, - H 0 0- LnLU NO 0 LU (f) C < 0 W N Lr) tr) Ln z •t? >- (i) < < •71( (r) Uj 0 LU ' 0 (7) ?er- < •• _1 C 0_ Lu - , fu 1 1111 1_ 111 1111 1111 1111 0 01 1 CL Ln 1-1 NOIIVNIDNI • >- cUW (1) � > LU O 1-. O O L O ' QQ)) �W 0E- Q _ 1- O Q 1- Q O� m _JZ - 0_ Z - Ln U O 'Ci- C7 O 0 t0 �t , Ch o_ O 4) CO < - O N O Ln M O O O co .--. 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Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13 -15 Sundry Number: 311 -282 Dear Mr. Egbejimba: r 6, Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair r DATED this d ay of September, 2011. Encl. • STATE OF ALASKA OT,,,, ,1( 9. lift �� i ALASKA •AND GAS CONSERVATION COMMISS• ECMV • APPLICATION FOR SUNDRY APPROVAL E 20 AAC 25.280 SFP 1 4 211h1 1. Type of Request: ❑ Abandon . ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Chaniggsksaiaearcons. C0mm13sjo, ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension Anchorage 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 182 - 157 - • 3. Address: - ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20831 -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: PBU13 -15 Spacing Exception Required? ❑ Yes .: No 9. Property Designation: 10. Field / Pool(s): ADL 028315 & 028314 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): 10642' - 9213' - 10572' 9153' 9925' 10397' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2581' 13 -3/8" 2581' 2581' 4930 2670 Intermediate 10209' 9-5/8" 10209' 8847' 6870 4760 Production Liner 735' 7" 9904' - 10639' 8593' - 9211' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 10234' - 10456' 8867' - 9055' 5 - 1/2 ", 17# x 4 - 1/2 ", 12.6# L - 80 / N - 80 9947' Packers and SSSV Type: 9 x 5 - 1/2" Baker '3 - packer Packers and SSSV 9841' / 8541' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development - ® Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 1, 2011 ❑ Oil ❑ WIN.) ❑ WDSPL I Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG - Suspended �* ' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Takahiro Kosaka, 564 -5994 Printed Name John Egbejimba Title Engineering Team Leader Prepared By Name/Number: Signature V ' = err Phone 564 - 5859 Date 13 / Terris Hubble, 564 -4628 �� +� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 3 1 �U,� Sundry Number: ;/ I ❑ Plug Integrity OP Test ❑ Mechanical Integrity Test ❑ Location Clearance A hiCOO c os,; 0 1 s' Other: '1t Z 60 U r si. A �1 1..w. Ti ' tt C b..a.;„, I I-ern. .. pl4 p 14c.e........ ro veva., /G°.t. Zo ,44c Z S r Z 6.) Subsequent Form Required: /4 yQ-z I . APPROVED BY Approved By: / COMMISSIONER TH L BDMS OMMISSION Date 7/2z/1) Form 10-403 Revised 01/2010 I`! 1 (31 n' Submit In Duplicate f v ,SEP 2 2 $01 • • • bp To: Alaska Oil & Gas Conservation Commission From: Takahiro Kosaka, Operations Drilling Engineer Date: September 1, 2011 Re: Prudhoe Bay - Request for Abandonment Sundry 13 -15 Sundry Request: Approval is requested for the P &A of Prudhoe Bay well 13 -15 in preparation for 13- 15A a rotary sidetrack well to a new Sag River target. All perforations will be squeezed off and the well will be abandoned with additional 1000' of cement and a mechanical plug. Existing 9 -5/8" casing is planned to be cut & pull or milled to 150' and the well will be kick off using cement plug. Well History: 13 -15 is a vertical WAG well drilled in 1982 and originally completed in the lvishak Zone 4. of 6.0 BCF and 20.6 MM bbl have been injected in this well. On Dec -1985 Zone 4 was re- perforated and on Jan - 1992 perforations were added to SGR. 27' of 3 -5/8" PERF GUN was left in hole at 10397' above the fill covering the lower perforations. LDL on 1996 and Caliper on 2006 identified leak hole in both 5 -1/2" and 4 -1/2" tubing. The well is SI since July -2006. Reason for Sidetrack: 13 -15A will be drilled to test ability to MI, Water and Gas flood in Sag River at 1500' to 2000' well spacing from planned producer 13 -12A. Recent History: 03/11/11 PPPOT -IC passed 03/11/11 PPPOT -T failed 05/18/11 CMIT -TxIA to 3000 psi, MIT -OA to 2000 psi passed with IBP in 7" liner 05/31/11 Pull IBP @10052' 06/01/11 Set WRP @9925" Pre -Rig Work: (Planned Start Date: 1- November -2011) 1 S Pull WRP ✓ 2 F lnjectivity Test • 3 F Fullbore P &A. -40 bbl of 15.8 ppg Class G cement. 4 S D &T cement. Tubing Punch, ' , 5 F Circ well to seawater. CMIT -TxIA to 3500 psi 6 E Jet cut TBG at -3000' c ,,, ) 7 V Set BPV p,ress. -�c s f ps �° �`'�'�- 8 F Test BPV Rig Work: (Planned Start Date: 15- December -2011) 1. De- Complete 13 -15 a. MIRU Doyon 25 &moo b. ND tree, NU and test BOPE to 250 55Gepsi a. Pull and LD 5 -1/2" completion. b. Clean out inside 9 -5/8" casing to the top of the tubing. c. Run GR /CCUUSIT in 9 -5/8" casing to determine casing cut point. d. Set 9 -5/8" EZSV at -2800' and test. +✓ e. Cut and pull 9 -5/8" casing. - f. Wash over, cut and pull 9 -5/8" to -2680'. Mill 9 -5/8" if necessary. ' g. Clean out 13 -3/8" and 12 -1/4" OH to the top of the 9 -5/8" casing � co f l .c C on e y 41' taa ` S T� ,s we ll xrn 00 [ 'l am ✓rt'C a40,o / Ask i� Frc•� r f well w�f 7ta G,�,�� 'ive( Ci nGr 4 h �i�i�''� c c y ir'rf6 , -��' T1 o f — • ? f c� .� r�[ wr /f arvr Tr , /'/i,'�� : J �I Gf �.r �, tt 9 'e Lek„ �� well 7Y) eva /vt7C p c h0I ���� � n � Ala ; rn� o lerv f ° deT Arvi r ref , y G mc�' prve40/` 0, U4 f J 1j te,,e // ry (9/4974 • • Pf 4 h. Set Kick off cement plug from -2280' to 2800'. (Following steps for new PTD 13 -15A) 2. Drill 12 -1/4" Intermediate Hole a. Kick off, drill 20' of formation and perform LOT b. RIH with 12 -1/4" drilling BHA with DIR /PWD /GR /RES. V c. Drill -70' into HRZ. - 3. Run and Cement 9 -5/8" Intermediate Casing. Ng.) a. Change to 9 -5/8" casing ram and test to 250/3500 psi. b. Run 9 -5/8" 40# L -80 casing to surface. c. Cement 1000' from shoe with 15.8 ppg Class G. d. Pressure test casing to 3500 psi for 30 minutes. e. Set casing slips and test pack -off. f. Install new tubing spool. g. NU and test BOP. 4. Drill 8 -3/4" Intermediate Hole a. RIH with 8 -3/4" drilling BHA with DIR /GR- at- Bit/RES. b. Drill out shoe plus 20' of formation and perform FIT. c. Drill to TSGR. 5. Run and Cement 7" Intermediate Liner. a. Change to 7" casing ram and test to 250/3500 psi. b. Run 7" 26# L -80 liner to 150' inside shoe. c. Cement to TOL with 15.8 ppg Class G. d. Pressure test liner to 3500 psi for 30 minutes. e. Run CBL across liner. 6. Drill 6 -1/8" Production Section a. RIH with 6 -1/8" BHA with DIR /PWD /GR- at- Bit/RES /NEU /DEN. b. Displace to drill -in fluid c. Drill out shoe plus 20' of formation and perform FIT. d. Drill 6 -1/8" production hole to TD. e. CBU, trip to shoe and back to TD, circulate until clean. MAD pass where required. 7. Run and Cement 4 -1/2" Production Liner a. Run 4 -1/2" 12.6# L -80 un- cemented liner with swell packers to 150' inside shoe. 8. Run 4 -1/2" Completion a. Run 4 -1/2" 12.6# L -80 completion to 4 -1/2" liner top. b. Reverse circulate to spot corrosion inhibited sea water followed by sufficient diesel for freeze protection. Allow diesel freeze protect to U -tube from IA to tubing. c. Set WRP. Set 4 -1/2 production packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 9. ND / NU / Rig Release a. Install and test TWC b. ND BOPE, NU Tree and test to 5000 psi c. Pull TWC. Set BPV d. RDMO Attachments: Current Well Schematic Pre -Rig Well Schematic Proposed Well Schematic Contact Drilling Engineer Takahiro Kosaka (907) 564 -5994 Production Engineer Megan Kimmet (907) 564 -5851 Geologist Cole Abel (907) 564 -5576 TREE _ . GRAY GEN 3 WELLHEAD = GRAY • SAFETY OS: WELL REQUIRES A SSSV ACTUATOR B OR = AXELSON 13-15 SCALE ON MI. LDL 4506/18/96 INDICATES LEAK & BF. ELEV = KOP = 3100' Max Angle = 43 Datum MD = 10259' TIT I 2205' 1-15-1/2" OTIS ROM SSSV NIP, ID = 4.562" Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I 2581' Minimum ID = 3.725" @ 9935' I I 9821' 1-15-1/2" BOTPBRASSY I 4 -1/2" OTIS XN NIPPLE l z 1.�� I 9841' I- -I9 -5/8" X 5 -1/2" BOT 3 -H PKR 1 5 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" H 9852' 1- ` 9852' 1-15-1/2" X 4 -112" XO, ID = 3.958" I TOP OF 7" LNR I-1 9904' Hs id 1 9925' I4 -1/2" STD WRP(6 /1/11) I 1 1 1 9935' H4 -1/2" OTIS XN NIP, ID = 3.725" I 9946' H 4-1n" BOT SHEAROUT SUB 14 -1/2" TBG -PC, 12.6 #, N-80, .0152 bpf, ID = 3.958" H 9947' 1 i , 9947' 1-14-1/2" WLEG, ID = 3.958" I 1 9931' I-I ELMD TT LOGGED 12/31/82 I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I-I 10209' PERFORATION SUMMARY I REF LOG: BHCS on 10/18/82 ANGLE AT TOP PERF: 33 @ 10234' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 8 10234 - 10254 C 01/10/92 3 -3/8" 8 10352 - 10382 C 12/31/82 10397' —I FISH - 27' 3 -3/8" PERF GUN (SLM) I 3 -3/8" 4 10390 - 10400 C 12/12/85 I 3 -3/8" 8 10403 - 10413 C 12/12/85 3 -3/8" 4 10414 - 10424 C 12/12/85 3 -3/8" 8 10424 - 10434 C 12/12/85 3 -3/8" 8 10434 - 10442 C 12/12/85 3 -3/8" 8 10446 - 10456 C 12/12/85 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 10639' 1 rfrf•Tyf• I TD H 10642' ►�4�1 ∎1�1�1�4�4�4 DATE REV BY COMMENTS ? DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/82 ORIGINAL COMPLETION 04/23/11 MSS/ PJC PULL HES BB PLUG (04/11/11) WELL: 13 -15 10/06/01 RN/KAK CORRECTIONS 05/20/11 SRD/ PJC SET BKR IBP (05/18/11) PERMIT No: n821570 03/16/06 COM/PAG WAIVER SAFETY NOTE (03/08/06) 06/02/11 CDJ/ PJC PULL IPB/ SET WRP (06/01 -02/11 API No: 50- 029 - 20831 -00 09/27/06 TWS /PAG SET HES BB PLUG @ 9891' Sec. 14, TION, R14E, 77.95 FEL, 4931.49 FNL 10/09/06 SKB/TLH WAIVER SFTY NOTE DELETED 02/09/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) LLHtAU = UNAY JArt l T NV I CJ: VV CLL KCWIJIICCJ A JJJ V TUATOR= •AXELSON 01 3 15 P re-Rig SCALE I. LDL 4506/18/96 INDICATES LEAK ELEV = 89' P= 3100' t Angle = 43@6500' ArcthPack (down squeeze{ um MD = 10259' O 2205' —{5 -1 /2" OTIS RQM SSSV NIP, ID = 4.562" I um TVD = 8800' SS C em ent (clown squeeze ) E sty ated TO C 2255' 13 -3/8" CSG, 72#, L -80, ID = 12.347" H 2581' Al , 300' JetC ut (1\1/4.4 r 5480' hole, 4578' possible hole E 5th aced TO C 8802' P &ATOC 9821' H5- 112 "BOTPBRASSY I 9841' — 19 - 5/8" X 5 -1/2" BOT3 -H PKR 5-1/2" TBG -PC 17# L -80 .0232 bpf ID = 4.892" — 1 9852' ' " 1' hole TOP OF 7" LNR H 9904' J el I 9935' 4-- 12 "OTIS XN,ID = 3.725" 9946' 9 12 "BOT SHEAROUT SUB 4-1/2" TT3G PC 12.6# N-80 .0152 bpf ID = 3.958" — 9947 / 9947. 4-1/2"W LEG, ID = 3.958" 9931' H ELMD TT LOGGED 12/31/82 9 -5/8" CSG, 47 #, L -80, ID = 8.681" --I 10209' • ■ I TSGR 10231'MD (8776'TVDss) PERFORATION SUMMARY REF LOG: BHCS on 10/18/82 ANGLE AT TOP PERF: 33 @ 10234' I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3-3/8" 8 10234 - 10254 C 01/10/92 3-3/8" 8 10352 - 10382 C 12/31/82 3-3/8" 4 10390 - 10400 C 12/12/85 • 10397' --I FISH - 27' 3 - 3/8" PERF GUN (SLM) 3-3/8" 8 10403 - 10413 C 12/12/85 I 3 -3/8" 4 10414 - 10424 C 12/12/85 3-3/8" 8 10424 - 10434 C 12/12/85 I 3-3/8" 8 10434 - 10442 C 12/12/85 3-3/8" 8 10446 - 10456 C 12/12/85 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" (--I 10639' TD H 10642' 1.6.6.4.6 4.4.4.4 )ATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 122/82 ORIGINAL COMPLETION 04/23/11 MSS /PJC PULL HES BB PLUG (04/11/11) WELL: 13 -15 /06/01 RN/KAK CORRECTIONS 05/20/11 SRD/PJC SET BKR IBP (05/18/11) PERMIT No: '1821570 /16/06 COM/PAG WAIVER SAFETY NOTE (03 /08/06) 06/02/11 CDJ /PJC PULL IBP/SET WRP (06/01-02/11) AR No: 50- 029 - 20831 -00 /27/06 TWS /PAG SET HES BB PLUG @ 9891' Sec. 14, TION, R14E, 77.95 FEL, 4931.49 FNL /09/06 SKB/TLH WAIVER SFTY NOTE DELETED /09/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) IAELLI D' 013 -1 5A i SAFETY OS: WELL REQUIRES A SSSV ACTUATOR= WHEN ON ML KB. ELEV = g9' P Loposed BF.ELEV= Max Angle = Lub]±atorVd1re (rBD ) - -- - - - -- - - -- - - -- Datum MD = Datum 8800'SS 2200' 412 "XN4Dpbw,MCX GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" -{ 2581' I ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3600 3571 . I 2 6700 5632 U 9 -5/8" milled to 2680' Kick off cement plug © 2610' Sv4 • V• 1 EZSV @ 2800' ♦ 111111�ft • 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ••111. �i 1 t 11 13 -15 54 @-4700' 49,-5/8" CSG, 47 #, L -80, ID= 8.681" H 1020W 9 - 5i8 "x 7 "Hangerr1' acker 11043' THRZ 11123' 9 -5/8 "40# L-80 HYD563 13= 8.681" 11193' 60 0 12324' 4-1/2"X Nppb ID= 3.813" 12359' 7 "x412 "PKR 8 -3/4" hole 4 12 "TBG 12.6# L -80 TCII0152 bpfID= 3.958" 12509' 12394' 4-1/2"X N1Dph D=3.813" 1 7 "x412 "Hanger/Packer 12509' 7"26# L-80 HYD563D= 6151" 12659' a , 600 TSGR 12659' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE I I I I 6 -1/8" hole a 4-1/2" Un- cemented LNR 12.6# L -80 TCII —J 20195' j • , 9 0 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/82 ORIGINAL COMPLETION 07/21/11 MSE PROPOSED RSTwp #6 WELL: 13 -15A 10/06/01 RN/KAK CORRECTIONS PERMIT No: 03/16/06 COM/PAG WAIVER SAFETY NOTE (03 /08/06) API No: 50- 029 - 20831 -0' 09/27/06 TWS /PAG SET HES BB PLUG 9891' Sec. 14, TON, R14E, 77.95 FEL, 4931.49 FNL 10/09/06 SKB /TLH WAIVER SFTY NOTE DELETED 02/09/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) .~ ~ ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 October 07, 2006 RECEIVED Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 OCT 1 3 2006 Alaska Oil & Gas Cons. CQfl1mission Anchorage Subject: 13-15 (PTD 1821570) Application for Cancellation of Sundry #399-091 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 399-091 for Prudhoe Bay well 13-15. The sundry was for continued water injection with slow TxlA communication. The well no longer passes compliance pressure testing. The well will remain shut-in while being evaluated for repair. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sin,erely, f\ ~ n '-__CX~ I~ Anrla Dube Well Integrity Coordinator 6CI\NNED ocr 3 1 2008 Attachments Application for Sundry Cancellation form 10-404 1. Operations Performed: Abandon D Alter CasingO Change Approved Program 0 Rt:.\Jt:.1 V E:.U ~ STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 1 3 2006 REPORT OF SUNDRY WELL OPERAIjQMSGas Cons. Commission Ållchofage I OtherŒ]10-403 Cane Repair WellO Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New PoolO Perforate 0 Stimulate D WaiverO f .. I I l r--- . ¡ 1 : i I ! P.O. Box 196612 Anchorage, Ak 99519-6612 ¡7. KB Elevation (ft): j . 89.00 : G. Property Designation: L ADL-028315 ¡! 1. Present Well Condition Summary: f ¡ Total Depth ! I (- , ~ .-. StratigraphicO 9. Well Name and Number: 13-15 Time Extension 0 Re-enter Suspended WellO 5. Permit to Drill Number: ExploratoryO 182-157 6. API Number ServiceŒ) 50-029-20831-00-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development 0 10. FieldlPool(s): Prudhoe Bay Field / Prudhoe Bay Pool measured 10642 feet true vertical 9213.0 feet Plugs (measured) 4-1/2" HES BB Plug set @ 9891 (09/27/2006) 27' 3-3/8" Perf Gun @ 10397 SLM Effective Depth measured 10639 feet true vertical 9211.0 feet Junk (measured) : Casing CONDUCTOR SURFACE PRODUCTION LINER Length 78 2528 10157 735 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 MD TVD Burst Collapse 54 132 54.0 132.0 1490 470 53 - 2581 53.0 - 2581.0 4930 2670 52 - 10209 52.0 - 8847.0 6870 4760 9904 - 10639 8593.0 - 9211.0 8160 7020 i ~ r ~ 7 Perforation depth: ; h- Measured depth: 10234-10382,10390-10400,10403-10442,10446-10456 j ~ ?";- True vertical depth: 8868-8992, 8999-9007, 9010-9043, 9046-9055 ~ . ~ i Tubing ( size. grade, and measured depth): [ f ~ ~ Packers & SSSV (type & measured depth): 5-112" 17# L-80 @ 49 9852 4-112" 12.6# L-80 @ 9852 9947 9-5/8" BOT 3-H Packer @ 9841 5-1/2" Otis RQM SSSV Nipple @ 2205 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: i13 ! Oil-Bbl Representative Dailv AveraQe Production or Injection Data Gas-Met Water-Bbl Casing Pressure o o Tubing Pressure 195 194 Prior to well operation: Subsequent to operation: . [14. Attachments: ~ í Copies of Logs and Surveys run _ Daily Report of Well Operations_ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service[!J WAG D GINJD WINJ[!J WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: 399-091 f~ 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Anna DI. be RBOMS 8FL () CT I 7 2006 Printed Name Anna D be r- n D _ Title Signature .... ex I\A.)A Ct./. ' (~ ~ Phone Form 10-404 Revised 4/2004 Well Integrity Coordinator 659-5102 Date 1 0/9/06 13-1J tl' IV #1821510) Internal Waiver Cancellation - Trouble Well All, An internal waiver was issued for TxlA communication on well 13-15 (PTD #1821570) on 03/08/06. The well has not passed waiver compliance testing for a CMIT - TxlA. The well is currently shut-in with a plug downhole. Plans are to conduct an LDL to determine the cause of the failed CMIT- TxlA. If possible, the well will be resecured to obtain a passing CMIT-TxIA and again apply for AA and waiver. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you, }lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 I of 1 10111/2006 9:46 AM 1 J-l J \.r 1 LI ff 1 o¿ 1 J I V} r laH~ lUl UUlalllUlt; .l-'a~.::Hllð \.....-lVlll - 1 AIL\. . HI Jim and Winton, An effort to obtain a CMIT-TxIA was attempted on 08/21/06 but aborted due to establishing a liquid leak rate of 0.74 gpm. It is suspected that the TTP is not holding. Plans are to pull the TTP, caliper the tubing to determine an appropriate set depth, and then to set an IBP to obtain a passing CMIT-TxIA. Once the well passes a CMIT-TxIA, a request will be submitted to cancel the old sundry and obtain an AA for continued injection. Please let me know if you have any other questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Dß Pager: (907) 659-5100 x1154 $CANNED SEP () B lD \ -----Original Message----- From: James Regg [.r:!I.9:i 1 t~..:j i~~S3~~..ª.r:!Ij...£1:.:..~..~..?:!:=_: a~.:~~] Sent: Thursday, August 31, 2006 10:49 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: PBU 13-15 and 14-14 MIT Failures Please provide an update of these wells PBU 13-15 failed a witnessed CMIT on 8/4/2006; PBU 14-14 has a TxIA waiver (Sundry 300-199) and failed witnessed MITIA and CMIT TxIA on 8/29/2006; looking at the OA pressure history, it appears there has been a slow tendency to re-pressure, although there was no indication of such during the witnessed MITs. Jim Regg AOGCC I of] 9/1/20064:]6 PM MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commis TO: Jim Regg P.I. Supervisor keÞc., '-1.,(' lCodOC , Z (<-- ul .. .. e,L' ..! ,I DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-15 PRUDHOE BA Y UNIT 13-15 \ ~ ')-' \~1 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..:JB2-- Comm Well Name: PRUDHOE BAY UNIT 13-15 API Well Number 50-029-20831-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060805151719 Permit Number: 182-157-0 Inspection Date: 8/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-15 Type Inj. N TVD 8541 IA 0 2980 2940 2900 2840 P.T. 1821570 TypeTest SPT Test psi 2135.25 OA 0 0 0 0 0 Interval OTHER PIF F t,......../ Tubing 0 2870 2820 2780 2730 Notes Well failed previous CMIT. Tubing tail plug had been reset with no improvement. Following the recorded test the IA was repressured to 3000 psi and observed for 30 minutes with a steady loss of 50 psi per 15 minutes, susf?d- tv.b,·~~ -tq~ l ?\<..4 I':> rWi- ~1Þ l c:(, i ;'8 ¡' (.,..;, ~ l 11?j¿ St- . ::] ~ ' Q..;¥-er c'\vla.J1'4..' she.s. ., 'i;eê.. C-Lf-kc ~~e{ e:(.,LQ (\ ../ NON-CONFIDENTIAL Wednesday, August 09, 2006 Page I of I RE: PBU 13-15 . . PTv:> $t-lcð2-_ 157 Jim, Our plan for this well is to redo the CMIT-TxIA with a triplex. This has been planned for tomorrow. If a CMIT-TxIA fails again, I will have the well secured and cancel the waiver/AA. I will send the MIT form for the test on 08/04/06 today as well. Thank you, Andrea Hughes (Filling in for Joe Anders) 659-5102 office 659-5100 xl154 pager $CANNED AUG 2 ~12ú06 -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Friday, August 18, 2006 9:32 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: PBU 13-15 Well failed consecutive CMITs (or CMIT and MITT) as I understand from inspectors report (attached); what is the status of this well? Jim Regg AOGCC 1 of 1 8/18/200610:12 AM MEMORANDUM e State of Alaska tit Alaska Oil and Gas Conservation Commission TO: Jim Regg0c¡:,'c,¡< 1(1-6 \O~ P.I. Supervisor DATE: Wednesday, July 19,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-15 PRUDHOE BAY UNIT 13-15 ~ \</\ \~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :::11312- Comm Well Name: PRUDHOE SAY UNIT 13-15 API Well Number 50-029-20831-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060714062036 Permit Number: 182-157-0 Inspection Date: 7/l3/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 13-15 ¡Type Inj. I N I TVD I IA I I ! I I I Well I I 9841 i 0 2960 2900 2830 2760 , ,I ! I I ¡ ! I I P.T. i 1821570 ITypeTest i SPT I Test psi i 2460,25 OA ì 0 0 0 i 0 i 0 I I " I I i -,- Interval REQVAR P/F F / Tubing i 0 I 2750 I 2690 I 2620 I 2550 I I Notes Well has known Tubing x lA communication. A plug had been set in the tailpipe and a CMIT was performed. Steady pressure losses of 70 psi per 15 minutes on e tubing and IA were observed. NON-CONFIDENTIAL 4', .' <,.. ~. Wednesday, July 19,2006 Page I of I MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg 'J (''/ P.I. Supervisor )\e11 'l Zee¡ Ò(~ DATE: Wednesday, July 27,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-15 PRUDHOE SAY UNIT 13-15 ~i6ð-",,\sr: FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .:Ili- Comm Well Name: PRUDHOE BAY UNIT 13-15 Insp Num: mitCS050726145955 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20831-00-00 Permit Number: 182-157-0 Inspector Name: Chuck Scheve Inspection Date: 7/25/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-15 Type Inj. N ITVD 9841 I IA 240 3020 2950 2940 P.T. 1821570 TypeTest SPT I Test psi 2460.25 lOA 0 0 0 0 I Interval REQV AR P/F P Tubing 20 2780 2720 2690 Notes: This Well has a known tubing leak. A plug had been set in tubing, and the CMIT performed. SÇANNEC AUG 0 9 2005 Wednesday, July 27, 2005 Page 1 of 1 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 / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / DS13 07/08/03 Dou~! Varble Not witnessed I Packer Depths (ft.) I Pretest Initial 15 Min. 30 Min. w""1~3-1~ I~'"¢' I~ I~'T~I ~'~'1 ~'~"~'1 Tubingl WoI 30001 ~3~I ~01 ,nt~1 2 P'T'D'I1821570I Type test I P I Test psiI 21361 I Casingl 14°1 3°°°l 294°1 29101 P/FI P Notes: CMIT TxlA, has rapid TxlA comm, 2-year CMIT against a TTP required by Sundry #399-091 WellI Type Inj. P.T.D.I Notes: P.T.D.] Notes: WellI Type Inj, P.T.D.I Notes: Type Inj. P.T.D.I 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) MIT Report Form Revised: 06/19/02 2003-0708_MIT_P B U_I 3-15.xls ;CA~NEE:" ~U~ 0 ~ 2003 ) ) ARCO Alaska Inc. Attn: Problem Well Specialist, PRB 24 Post Office Box 1 00360 Anchorage, Alaska 99510-0360 ~~ ~~ October 2, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ¡w-- 157 Subject: 03-11 Monthly Pressure Data, Per State Sundry Approval #399-084 ~C\-C::I~~"I 11-29 Monthly Pressure Data, Per State Sundry Approval #398-035 ~ ,-\-t)$ ';\ ",",,,,"" 13-15 Monthly Pressure Data, Per State Sundry Approval #399-091 ~~ -\:}\S~ / 13-17 Monthly Pressure Data, Per State Sundry Approval #298-275 'iS~ - (J~")..~./ 13-20 Monthly Pressure Data, Per State Sundry Approval #397-078 ~:;) -<:J~\J~\'../' P1-01 Monthly Pressure Data, Per State Sundry Approval #398-188 qs -(:)~ \:::¡ <.:.11 P2-34 Monthly Pressure Data, Per State Sundry Approval #398-243~1i.J -C)~'J. ~.?' Dear Mr. Wondzell: Attached please find daily injection reports on Wells 03-11, 11-29, 13-15, 13-17, 13-20, P1-01 and P2-34 for the month of September 1999. This report is submitted to comply with the State Sundry Approvals listed above. Also attached are MITIA reports conducted on injectors. If you require any additional information, please contact Jerry Dethlefs or me at (907) 659-5102. Sincerely, (o{~ ) Joe Anders Problem Well Specialist SCANNED JAN 1 1 2006 \S k"",' , - ... c:. \ ....) ,"""" C!. ~ -\ ~ <>. ,Q. (J.,-")\-Q~c. \- t '" "' _ <- ~'\ ~~~"S'S..~,,~ ~ ~ ~ ",-CA~ ~'t '0 \?Q:..~~~ ¿.,. C' ~L \. _ \o..\-"- ~ ~~S.....:J~"i.. ~ ü,~ \ ~ "" \~~~!t.c.) '')'1 <:;"C"'~ c:.\' ':> öv-....... c~"<:è.S ~CL \\"" "S ~ l'~~.-'\~a\-\c \ - i:!. s \,C>. ~ '" c-\. '-.), <:.... ~ "a..\-"- ú.. c:.o "",\,0" <.,.c-,' -¡,J;¡ "'"""-~ h -\ ...."",,\ ~ D \- '" '\ UC;.l..,\~¡;- ,,~ ~~~~_ W\ \-~ .i..-~~ d ".........0 \I"'~"-~\'- 0-\ c........ c-y,^-",\G. c- 't-(::) co ~~t.\~ ¡. v \r).,'f'..~ \) ,((;._~>".)-~ ~l o..~';¡'~ \\..)'; Ç> \x-. ~~ù \€.. L C- ~~rL ~ \ ~ ·s-oa ~çl. 0\ \<!. ~ ~ ~~ '1 \f\ '-.J «.-~\\~~- ~ . . . . - O~«-,ö-"--<")',~ Q>-<'- ~«- " C). \"',"" "'. 0"'- \. ~\ :n~ vc~ \ "'-.) It\.\ ~~'Z-';> ';. <0 ,~"> ~ ,'X~ " ç \-~ '( ~c."\ v--.. \- \- a \1'J\. c:, ;,< \. \-cs 't--I\.C) \' «.. c..\ a '::,. Q \ 'I . ~ ') \Gç~- \ ~~ ) ARca Well 13-15 September 1999 Injection Data D t f I· t· Volume Injected a e 0 nJec Ion (BWPD) 9/1 /99i~_ª..ª..~,..,,__,..._,. 9/2/99 1~ 989 __''''''__,...'_ 9/3/99 ~..!.ª-ª,ª.._,....___...._.. 9/4/99 _ ~..,.ª§2...,____.._ 9/5/99 i,,ª,ªJ..,__.. _, 9/6/99 4.!ª..??___ 9/7 /99 ~)~9Q..,...,_.........__.. 9/8/9 9 ~ª_ª_º__...., 9/9/99 i!...ª,ª_ª__,.............,..,_ 9/1 0/9 9 i_!..~,~..!..,..__.._..,'_ 9/11 /99 1..'..~~.§_.__..,___., 9/12/99 . ?"!J..?X.....,,.. . _ 9/ 1 3/99~..!~,ª?.._ ...' ......_.., 9/14/99 ~.lª~J_....____.....,_...._. 9/15/99 ~..,-ªªJ 9/16/99 4,991 9/17/99 4!ª_ªº.,.. 9/18/99 4,~90 9/19/99 4."ª~J._,, 9/20/99 1,,ª..~~,..,__,.., 9/21 /9 9 ~.!.~9 ~_.._.._.._....._ ." n..,.. _., 9/22/99,4l,ª~1_,_............ 9/2 3/99 ~..!-ª-ªJ..,...,_"__,__ 9/24/994..,9ª-..4...__..,_. _ 9/25/994"ª_ª_~,, 9/26/99 4,..ª~§..__,_. 9/27/99 4,~~,4_,.., : 9/28/99 4,986 9/29/99 ~..,_ª§)J_,.._ ___ 9/30/99 4,~_ª_~.._ Joe Anders/Jerry Dethlefs Problem Well Specialists ARCO Alaska, Inc. Tubing Pressure (psi) 1,414 1,414 1,414 1,~J4 1,340 1,415 .1,415. 1,415 1,249 1,249 1,249 1,481 1,?10 _ ... , ~_!?J_O 1,246 1,332 1 ,481 1,334 1,334 1,197 1,485 1,485 1,265 1,332 1,375 1,375 1,430 1,380 1,282 1,282 9-5/8" Pressure (ps i) ,1,,~.~_º.., ,1!~~º-. ... ~!..§..~º. 1. ,!§§-º...,..'..._n_.. ,...,__ ~,.'.ªº-º- '.. -.--- -_.-, "'- 1, ~_~º _._.,.. ..____ ..J..!65.º.. 1."~§..º_"_' , 1..,,~~-º 1".ªºº_. __...._....,__ 1,300 ~, "'~º"º"'--'-'" .1,.,,--ªº-º ..,............_...,.. '...',....__ 1,300 -- ----.--.--.. -.........-...--..--.---.- 1_,ª_º-º 1,500 1,600 1,600 1!§..º-º 1,§Q_º .. 1_,_5..9--º.. "n, __.._ ..._.,.. 1,650 . __.__,..____·M____ '.. 1 '_§..~_º._'m 1,500 1 ,5.9.0 1,~-º9 1-,-~~g 1,560 1,600 1,600 ARCO Alaska Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 May 22, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ORIGINAL Re: 13-15 Sundry Notice and Waiver Request Dear Mr. Wondzell: Attached is a Sundry application for ARCO well 13-15. The application requests waiver approval for resumption of water injection into the well with known tubing x annulus communication. The 9 5/8" casing continues to demonstrate integrity as shown by MIT tests, and we believe control and proper monitoring of PWI injection can be maintained. Details of the proposed monitoring and testing routines to assure isolation are included as attachments to this letter. If you have any questions please contact Jerry Dethlefs or Joe Anders at 659- 5102. Sincerely, Problem Wells Specialist Attachments · , 0il & Gas Cons. Go~'~ss~;~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ,. Alter casing Change approved program Suspend Operation shutdown Re-enter suspended well Repair well, Plugging Time extension Pull tubing Variance X Perforate Stimulate Other Name of Operator ARCO Alaska, Inc Address P.O. Box 100360 Anchorage Ak 99510-0360 Type of Well Development Exploratory Stratigraphic Service X Location of well at surface 8. 1090' FS, 1125' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 9. 316' FSL, 75' FWL, Sec. 14, TION, R14E, UM At effective depth 10. At total depth 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM 6. Datum of Elevation (DF OR KB) 89' RKB 7. Unit or Property Prudhoe Bay Unit Well number 13-15 Permit number 82-157 APl number 50-029-20831 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition Summary Total depth: measured true vertical Effective depth: measured true vertical 10,642 feet Plugs (measured) 9,213 feet 10,445 feet 9,045 feet Junk (measured) ORIGINAL Casing Length Size Cemented Measured depth True veritical Depth Conductor 78.5' 20" 350 sx AS Set II Surface 2492' 13-3/8" 2700 sx Fondu & 400 sx PFC Production 10120' 9-5~8" 500 sx Cl G & 50 bbls PFC Liner 735' 7" 335 sx CIG 78.5' 78.5' 2581' 2581' 10209' 8847' 10369' 9211' Perforation depth: measured 10424-10434'; 10434-10442'; 10446-10456'; true vertical 8868-8885'; 8967-8992'; 8999-9007'; 9010-9018'; 9019-9028'; 9028-9036'; 9036-9043'; 9046-9055' Tubing (size, grade, and measured depth) 5-1/2" x 17#, L-80, PCT @ 9852' MD; 4-1/2" x 12.6#, N-80, PCT tail @ 9947' MD Packers and SSSV (type and measured depth) 9-5/8" x 5-1/2" BOT 3-H Packer @ 9841' MD. 5-1/2" Otis RQY SSSV Nipple @ 2205' MD 13. Attachments Description summary of proposal.. X Detailed operations program~ 10234-10254'; 10352-10382'; 10390,10400'; 10403-10413'; 10414-10424'; 14. Estimated date for commencing operation Approval of Sundry 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: OII Gas Service X Water injector only Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~__ ~"'FOR COMMISSION USE ONLY Problem Wells Specialist Condition of approval: Notify Commission so representative may witness Plug integrity BOP test Location clearance echanical Integrity Test Subsequent form required 10- IAppr°v=l -- 0ql ORIGINAL SIGNED BY Approved by order of the Commis-~rt N. Christenson Form 10-403 Rev06/15/88 J. Dethlefs / J. Anders - 659-5102 - PRB 24 Com mi~j'p,'t.'G[., ~..~ / Date ~ ~' ~ -771 DS 13-15 SUNDRY NOTICE 10-403 APPLICATION 05/22/99 DISCUSSION Well 13-15 is a WAG injection well that has tubing x 9-5/8" annulus communication. In June of 1996 a Leak Detect Log discovered leaks at 5480' and 4500' md in the 5-V2" L-80 tubing above the packer. A Kinley survey in July of 1996 showed the tubing in that area to be fair-to-poor condition. Based on the number of leaks the tubing is considered to not be a patch candidate. The well has remained shut-in since that time. The well does not have sufficient reserve potential to warrant a workover to replace the tubing. The importance of this well in the injection pattern has been apparent this last year, with several off-set producers' GORs climbing to point of being non-competitive. This waiver request is to allow produced water injection (PWI) into the well (no MI allowed). The request is supported by the following: · A passing combination MIT (T x IA) was performed on 03/30/99 to 3000 psi against a tubing tail plug showing 9-5/8" casing integrity. ° A previous passing combination MIT (T x IA) was performed on 05/26/96 to 3000 psi. · An MIT on the 13 3/8" passed to 2000 psi on. 03/31/99. · The maximum wellhead injection pressure was 1500 psi at 5,000 bwpd rate prior to shut-in. · The wellhead has integrity per packofftesting on 03/31/99. ACTION PLAN 1. Allow well to continue water-only injection. 2. Perform an annual CMIT T x IA to 3000 psi. 3. Record wellhead pressures and rates daily. 4. Submit monthly reports of daily rates and pressures. 5. Shut-in the well should MIT's or injection rates and pressures indicate further problems. Annular Communication Testing Mechanical Integrity Test DATE: 3/30/99 CMIT Tbg X IA. to 3000 pSi TYPE WELL: MIT: 13-15 PASS Well Status: Shut l.n TBG: VAC CONTROL: NA INITIAL PRESSURE DATA TYPE: Produced Water IA: 0 OA: 0 BALANCE: PRE-TEST PREPARATIONS BLED TBG and IA FROM NA SI TO PSI HRS MIN TYPE OF FLUID AND VOLUME BLED: NA TBG and IA FL both near surface TEST PRESSURES TIME TBG IA OA COMMENTS 15:00 VAC 0 0 START PUMPING TIM~ ' 15:23 1910 204(J 0 START TEST 15:38 1900 2030' 10 0 15:49 2850 3000 0 START TEST ., 16:04 2840 2970 30 0 16:19 2830 '2~7(J 0 0 START TEST START TEST .. TOTAL VOLUME PUMPED: 9 BBLs of diesel down the IA FINAL PRESSURES ~ TBG: 50 IA: 50 OA: 0 OBSERVATIONS / COMMENTS FINAL STEPS I-X I x · I x MUST BE COMPLETED AND CHECKED OFF!!! FLAG THE CASING VALVE. WITH LOAD AND TEST INFORMATION I - FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. I-. NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL Witness: Kevin Parks/Mike Eagling PLANNING PRUDHOE ID: 3UL 31'96 INJECTION WI~LL ANNULAJ~ COMMUNICATION ~ NOTIFICATION OF AOOCC P~Jt AR~A INJgCT/QN ORD~ #4 11:48 No.O0$ P.OS ' I $7' I IIII I D&?i~ ,June O~ ~ggo TIME: 9:15 A,M, NOTIFIED BY: David D. Smith LouG~maldi Injection Well 13-15 Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 DI84~U881ON: Well 13-15 is a WAG injection well that has tubing x 9-5/8" communication. This well failed an MITIA on 5/6~96 and was lmmcdlatly switched back to water rejection to flush the MI away. On 5/21/96 we set a q~P in the well and continued tl~e testing process. There is no indication of a wellhead leak per tests conducted 5/6/96 and no indication of 9-5/8" x 13-3/8" communication based on daily wellhead pressure information. A 3000 psi tubi~g x 9-5/8 combination MIT passed on 5/26/96 indicating competent 9-5/8 casing and packer. Leave the well SI and secured until a complete evaluation of the tubing leak can be completed and an action plan to repair the problem is developed, A State wih~essed MIT will be conducted upon completion of any form of repair, Wellt~ead pressures will continue to bc recorded on a dally basis until thc tubing x 9-5/8" communication problem is resolved, AOGCC ltlr~PONg~: Since thc well is SI and wc have no intent to bring thc well back on Injection, no verbal response was required, i iiiiiiii ii iiiiiii iiiiiiiiiii ii iii i Sundry Notice Req'd at this time? However, a Sundry Notice will be required to repair the well and return it to Injection service, Annular Communication En~tneer ' I II IIIIII I I I .......... Orig: Annular Communication Engineer cc: Wells Superintendent, Wells Operations Supervisor Area Field Eng. FS 3 DS Superv/sor FS 3 Superintendent DS 13 Engineer 0/30/92) Annular Communication HISTORICAL REPORT 6/4/96 FROM: 1/1/96 TO: WELL: 13-15 WELL TYPE: WAG PROBLEM: Possible T x IA Comm. 06/04/96 DATE 516196 5/8/96 5/18/96 5/21/96 5/22/96 DESCRIPTION OF WORK T/I/O=2950/1700/0+ AC EVAL; IA × OA test port @ 500 psi bled to 0 psi in 1 min (thick grey fluid). Flushed through and got good returns. Monitored for 4 hrs (during bleed and MITIA) with no increase in pressure. Initial IA FL @ 210' (9 bbls). Bled IA from 1700 psi to 440 psi in 3 hrs and 45 mins, gas and 0.5 bbls of meth/water. MITIA FAILED; MITIA to 3000 psi consistently lost ~250 psi everyl5 mins. Converted test to LLRT and established a leak rate of 1 GPM @ 2875 psi. Total test volume of 86 gal. Total test time was 85 min. Pumped 11 bbls of methanol total. Final WHP's =2950/1500/0+. T/I/O=1900/1400/150 Pressure on IA has stayed down since testing. DSM loaded well with 5 Bbls methanol and 150 Bbls of SW to assist switch to PWI injection. T/I/O=2500/1500/175 T/I/O= 1600/1600/750. MITIA FAILED; IA FL @ 522' (23 BBLs). Bled IA from 1600 psi to 150 psi in 2 hrs. Bled OA fro 750 psi to 150 psi in 5 min. Pressured IA to 3000 psi. IA lost 490 psi in 15 mins. LLRT; IA leak rate established @ 3 GPM. @ avg. pressure of 2725 psi. Test used. 4.5 BBLs in 60 mins. Pumped a total of 30 BBLs 60/40 methanol. Final WHPs=1600/1500/150. Will recommend a TTP for a Tbg x IA CMIT; will then notify AOGCC of results. WL ran a TTP and well is now ready for CMIT. DSO freeze protected prior to running TTP. T/I/O = 280/100/0. Attempted CMIT however FL's indicate a pump & 60 bbls will be required to test. IA FL @ 468' & the Tbg FL @ 1080'. WELL: 13-15 Annular Communication HISTORICAL REPORT 6/4/96 FROM: 1/1/96 TO: 06/04/96 WELL TYPE: WAG PROBLEM: Possible T x IA Comm. DATE 5/26/96 DESCRIPTION OF WORK T/I/O=200/50/0. CMIT to 3000 psi PASSED. TBG FL @ surface, IA FL @ 540' (24 bbls). Pumped down TBG while bleed IA. Bled IA from 50 psi to 0 psi Fluid level rose from 540' to surface, bled back 5 bbls of fluid. TBG LLR @ 2900 psi @ 0.8 BPM. Pumped 30 bbls of 60/40 meth/water down TBG. Shut in pumping down TBG switched to IA. Pumped 5.3 bbls down IA to pressure up to 3000 psi, TBG tracked IA pressure. Started CMIT. CMIT TBG lost 20 psi and IA lost 50 psi in 30 mins. Pumped 35.5 bbls of 60/40 methanol/water total. Final WHP's = 500/500/200. SENT BY:VECO OPERATIOi~i$, INC..; 6- 4-96 ' 7:41AI~t ; VECO WELL. SUPPORT--, PL,,~IN I Nfl PRUDHOE; # 1 / I DRILL si'rE HA~'TENANI~ PI.II~ REPOm' PUMP OPERATOR CREW NAMES Wi04 i3-15,,P ^' ~ ~ 0736 WELL 13-15 .WATER CYCLE- REC *"n ' My. AVG iNJ !NJ INJ VOLUME RATE PRES DATE TYPE BW DWD PSt 06-03 SI 0 0 0 06-02 c~ q~-nj oI 0 v n 0 qs-~! Sl n 0 0 05-30 Sl 0 0 0 05-2? S1 0 0 0 ~-~ -'-.-, ~.? . u,~-,'o .~,~ 0 0 ~ 05-27 S! 0 0 0 05-26 S! 0 0 0 J-~.~ Si n n 0 o:-~ Si 0 0 0 05-2~ Sl n 0 0 05-22 SI 0 0 0 ~ ~ ~ n 0 0 05-20 St 0 0 0 INJ TEMP DEGF 0 0 0 0 0 0 0 0 0 0 0 0 0 0 !59 !.57 156 u~-~ PW! 3i02 0 15Y? 05-18 PWI 461i 0 i578 05-i7 PWi 3950 0 1513 ~'=9 ~ 1523 n~ ~ PWi ~. 0~-1~ PWI 3203 05-14 PWI 25~2 0 !5~8 05-t3 PW! 2737 0 i627 05-i2 PWi 3i51 0 i6~8 vu-l~ PWI 1490 0 I~71 05-i0 PW! o,o- ~o~i 0 i742 153 157 !60 156 133 5t 0 0 0 TIME INJ ON INDEX IN,] BWD/PSI HRS 0,000 0.0 O,(KtO 0,0 0,000 0,0 0.000 0,0 0,000 0.0 0.000 0,0 0,000~.~ ^ ~' 0,000 0,0 0,000 0.0 O, (K~O 0,0 0,000 0.0 0,000 0.0 O. cX:O 0.0 0,000 0,0 0.000 0,0 3,0?? 15,2 2,~46 24,0 2,628 ~n 2. i18~,~ 6 2,070 ~ o 1,643 23.7 .7o~ ~Z.6 i,?07 23.4 1,134 ,o o I ~o~ 21,3 1.8SS'. ,o ? 1,46,2 2,5 0,000 0,0 0,000 0,0 0,000 0.0 O5-Oe PWi 1741 O '~: 05-08 PWi 252 0 1668 05-07 Mi 0 0 0 05-06 MI 0 0 0 05-05 M! 0 0 0 .GAS CYCLE ........... REC AVG AVG TiME INJ INJ INJ INJ n~ VOLUHE RATE PRES TEMP iNJ HSCF MSCFD PSI DEGF HRS 0 0 0 0 0.0 0 0 0 0 0,0 0 0 0 0 0,0 0 0 0 0 0,0 0 0 0 0 0.0 0 0 0 0 0.0 0 0 0 0 0.0 0 0 0 0 0,0 0 0 0 0 0,0 0 0 0 0 0.0 0 0 0 0 0.~'~ 0 0 0 0 0,0 0 0 0 0 0.0 0 0 ...r' 0 0.0 0 0 0 0 0,0 0 0 0 0 0.0 0 0 0 0 0.0 0 0 0 0 0.0 0 0 0 0 0.0 0 0 0 0 0.0 0 0 0 0 0.0 0 0 0 0 0,0 0 0 0 0 0,0 0 0 0 0 0.0 0 0 0 0 0,0 0 0 1277 5017 7819 0 0 0 0.0 0 0 0 0.0 150f~ oo~ 61 7,° i:Oor, 27~ 54 23,3 15000 ~' 45 o~o4 £4,0 $$ 06-04-96 0722 WELL ANNULUS HISTORY FOR ARCTIC PACKED WELL 13-15 04-01-96 TD 06-04-96 ~ PRESSURES ~ ~ 9 5?8 FLUID 13 3/8 FLUID ~ ~ BEF/AFT TYPE & BEF/AFT TYPE ~ ~ DATE TIME TYPE STATUS ~ FTP BLEEDING AMOUNT BLEEDING AMOUNT * TEMP 05-30-96 0000 WAG SI 05-22-96 0000 WAG SI 05-19-96 0000 WAG Si 05-12-96 1545 WAG 05-06-96 0900 WAG 04-29-96 0000 WAG 04-21-96 0000 WAG 04-14-96 0000 WAG 04-07-96 0000 WAG IW ~w~ 110 ~ *~ w~ 140 *~ ~ ~* ~ 500 w~ w*~ ~ 500 ~w~, ,~ w~ 1695 1600 ~ ~ ~ 150 w~w~ ~ ~ 1515 750 ~ ~ ~w~ 780 w~ ~, ~ 1518 550 **~* Kw, w,w 700 *~** ,wE ww, 1688 1500 ~*~* ~* ~ 100 ~w~ *~ w~* COMMENTS 160 PASSED MIT 160 PASSED MIT 160 PASSED MIT 158 FAILED MIT 110 DHD DOING MIT~POSSIBLE COMM 163 161 165 TYPES P - FREE FLOWING PRODUCER PAL - GAS LIFTED PRODUCER PWI - PRODUCED WATER INJECTOR SW! - SEA WATER !NdECTOR WAG - WATER AND GAS INJECTOR (ON WATER OR GAS) RGI - RESIDUE GAS INJECTOR (NGI/WGI/AGI) OBU - OBSERUATION WELL DIS - DISPOSAL WELL STATUS P - PRODUCING I - INJECTING IG - INJECTING GAS IW - INJECTING WATER SI - SHUTIN TROUBLED STATUS W - WAIUERED T - TROUBLED P - PROBLEM - SUSPECT N - NFTS WAIUERED FLUIDS A - ARCTIC PAk (GALLONS) D - DIESEL (GALLONS) N - NITROGEN (MINUTES) C -. CRUDE (GALLON~) O - GAS (MINUTES) W - WATER (GALLON~) We11:13-15 Spud Date:10/05/82 Original RKBE:89' Top of Formation: 10344' Annular Fluid:Diesel/9.6 NaCl Reference Log:BHCS ARCO Alask&, Inc. - Prudhoe API #: 50-029-20831-00 Contolet ion: 10/21/82 Hanger Type: Gray Max Hole Angle:43° @ MD: Date: 10/18/82 Tie In: Bay 6500' Type:~JECTOR Status:New Hanger:35' Angle @ TS:33° Angle @ TD:31° Date: 00/00/00 ALL DEPTHS ARE RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. J-1 C-1 J-2 J-3 J-4 Jewelry (J) De~th DescriDtion 1 2205' 2 9821' 3 9841' 4 9852' 5 9935' 6 9946' 7 9947' 9931' 11 10397' 5-1/2" Otis ~QY SSSV Nipple ID=4.562" 5-1/2" BCT PBR ~ly 9-5/8" x 5-1/2" BOT 3-H ~ Crossover 5-1/2" x 4-1/2" 4-1/2" Otis XN Nipple ID=3.725" 4-1/2" BO? ~ut Sub 4-1/2" TUbing Tail ELM Tubir~ Tail (Lo~ /2/31/82) FIS~: 27' 3-3/8" Perf 6~n 01/10/92 (SIM) Min ID: 4-1/2" Otis XN NiDDle ID=3.725" Casing andTubing (C) Size Weight Grade ToD Bottom DescriDtion 13-3/8" 729 L-80 0' 2581' Casir~ 9-5/8" 47# L-80 0' 10209' Casir~ 7" 29# L-80 9904' 10639' Lirm~ 5-1/2" 17# L-80 0' 9852' Tubir~-PC 4-1/2" 12.6# N-80 9852' 9947' Tubir~-PC J-5 J -6,7 C-2 Perforation Data (EIA~ I]EPTHS) (P) Interval Zone FT SPF Date Conm~-nts 1 10234-10254 SAG 20 4 01/13/92 APEF~ 10352-10382 4 30 8 12/11/85 RP~RF 10390-10400 4 10 4 /2/11/85 APERF 10403-10413 4 10 8 /2/11/85 RPERF 10414-10424 4 10 4 /2/11/85 APERF 10424-10434 4 10 8 12/11/85 RPERF 10434-10442 4 8 4 /2/11/85 APERF 10446-10456 4 10 8 12/11/85 RPERF P-1 Datum 8700' SS=10140' MD PBTD=10572' 8800' SS=10259' MD TD=10642' Revision Date: 05/23/93 by PTB/ENH Previous Reason: 01//2/92 Well 13-15 J-9 C-3 ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 July 31, 1996 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Recent Injection Weil failures. Dear Mr Wondzell: Attached are six documents, the last five are verbal notification reports which are made to document incidents on injection wells where we observed some form of pressure control failure. These reports are ARCO internal reports which identify the AOGCC contact and response. In all cases a failed MIT was the concluding data, and the problems were identified through other monitoring routines. The MIT's were run to confirm the extent of the problem, and none of these tests were routine MIT's that identified the problem. All five wells are SI at this time, and a summary of what we have found on each well is listed in the first attachment. If you require additional information or clarification, please feel free to contact either Richard Ortiz or Dave Smith at (907) 659-5102. Very Truly Yours, David D. Smith Annular Communication Engineer DDS/RAO Attachments cc: Marty Lemon Ron Bowden PRB-20 PRB-24 RECEIVED AUG 0 5 1996 Naska 011 & ~as Cons. Com~ RECEIVED 11-08: Injection Well Problem Summary AUG. 0,5 1996 Alaska Oil & Gas Cons. Commission Anchorage Initial indication of a problem was identified on 6/2/96. Since then we have determined that the PBR has unstung from the packer, leaving the Tbg in communication with the IA. It appears that the packer has failed and has slipped down hole and is resting on the liner top. We are unable to secure the well with a TI? or IBP due to the separation in pipe. However the well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$23,600.00 Current plans for the well: Keep the well SI until a RWO can be completed to effect the repair. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 12-23: Initial indication of a problem was identified on 5/30/96. Since then we have identified the problem as two holes in the tubing at -7,466' and 7,482'. We have been unable to confirm 9 5/8" casing integrity at this time due to a small (-1.6 GPM) leak at the TTP. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$56,600.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 13-15: Initial indication of a problem was identified on 5/5/96. Since then we have identified the problem as two holes in the tubing at-4,516" and 4,520". We have confirmed 9 5/8" casing integrity with a Combo MIT completed to 3000 psi on 5/26/96. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$45,300.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 17-08: Initial_ indication of a problem was identified on 6/22/96. Since then we have identified the problem as parted tubing or separation from the Tog hanger at or near surface. We are unable to secure the well with a TTP or IBP due to the separation in pipe. However the well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$3,300.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 17-10: Initial indication of a problem was identified on 7/1/96. Since then we have determined that we have competent Tubing with an MIlT to 3000 psi completed on 7/5/96. We have identified the problem as a hole in the 9 5/8" casing at -3,150'. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$15,100.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. INJECTION WELL ANNULAR COMMUNI~ TION VERBAL NOTIFICATION OF AOGCC PER AREA INJECT/ON ORDER #4 DATE: June 03 1996 TIME: 9:15 A.M. NOTIFIED BY: David D. Smith AOC~C CONTACT: Lou Grimaldi ~N: Injection Well 13-15 Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 DISCU~ION: Well 13-15 is a WAG injection well that has tubing x 9-5/8" communication. This well failed an MITIA on 5/6/96 and was immediatly switched back to water injection to flush the MI away. On 5/21/96 we set a TIP in the well and continued the testing process. There is no indication of a wellhead leak per tests conducted 5/6/96 and no indication of 9-5/8" x 13-3/8" communication based on daily wellhead pressure information. A 3000 psi tubing x 9-5/8 combination MIT passed on 5/26/96 indicating competent 9-5/8 casing and packer. ACTION PLAN: Leave the well $I and secured until a complete evaluation of the tubing leak can be completed and an action plan to repair the problem is developed. A State witnessed MIT will be conducted upon completion of any form of repair. Wellhead pressures will continue to be recorded on a daily basis until the tubing x 9-5/8" communication problem is resolved. ~ RF~PONSE: Since the well is SI and we have no intent to bring the well back on Injection, no verbal response was required. Sundry Notice Req'd at this time? YES NO X However, a Sundry Notice will be required to repair the well and return it to injection service. SIGNED: ~ Annular Communication Enginee. r Orig: Annular Communication Engineer cc: Wells Superintendent, Wells Operations Supervisor Area Field Eng. FS 3 DS Supervisor FS 3 Superintendent DS 13 Engineer (5/13/93) (Revised 10/30/92~ GeoQuest / ~(~500W. lnternational Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie RECEIVED JAN 1995 ~ 0il lAn~mgeGas Cons. Co~BJ0n NO. 9211 Company: 1/23/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description BL RR Sepia RF Sepia Mylar D.S. 1-3 POGLM SE'I'rING RECORD (12-23-94) ~1 .~'1 D.S. 1-3 POGLM RECORD (1-3-95) ~ vl D.S. 1-25 LEAK DETECTION (1-3-95) v'l ~' 1 D.S. 3-27 BAKER IBP RECORD (12-31-94) -,-1 ~"1 D.S. 4-7 ST I PERF RECORD (12-30-94) ~"1 ~,'1 D.S. 4-22A PROD PROFILE (12-26-94) , v,'l v' 1 D.S. 6-4 PERF RECORD (12-25-94) ,,1 -'1 D.S. 6-14A , PERF RECORD (12-26-94) ,,1 ,,'1 D.S. 9-4A PERF RECORD (12 23-94) ~ v-I D.S. 9-30 ST PERF RECORD (1-2-95) v/1 'D.s. 9-32 PERF RECORD (12-25-94) ./1 '-./1 D.S. 11-16 ST I ~ LEAK DETECTION (12-31-94) ,-1 ~,'1 D.S. 11-23A PERF RECORD (12-21-94) ,,'1 ~'1 ,o~ ~D.;S. .. 13-15 SBHPS & INJEC PROFILE (12-29-94) -1' .D.S. 13-33 LEAK DETECTION (12-30-94).. I 1 ,~~~ D.S. 13-33 BAKER INFLAT BRIDGE PLUG RECORD (1-3-95) '1 .p.S. 14-21 SBHPS & INJEC PROFILE (12-23-94) ~1 ' ' "'1 D.S. 15-7A DUAL BURST TDT-P (12-27-94) v,1 Y'l D.S. i5-30 LEAK DETECTION' (12-27-94) ~ v'l ,,-1 ' . .D..~S. 15-30 DUAL BURST TDT-P (CT/E-LINE) (12-30-94) ,/1 D.S. 18-9A DUAL BURST TDT-P (12-22-.94) ,,'1 ,/1 D.S. 18-27 DUAL BURST TDT-P (CT/E-LINE) (12:29-94) ~ v'l " ' 9q- 7 7 '-- SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Date: Feb 11, 1994 P.O. Box 100360, ,~chorage, AK Transmittal #: 94021 99510,~ ~k, Subject: From/Location: BHP Report John Degrey/ATO- 1529 Telephone: (907) 263-4310 To/Location: Distribution Well Log ~l Tool Type Run, Scale Contractor Number (M-D-Y) 1-9 12-17-92 BHP - Camco 1-14 8-11-92 BHP - Camco 1-14 8-11-92 BHP - Camco 2-2 1-10-93 BHP - Camco 2-13 2-12-93 BHP - Camco 2-35 5-21-92 BHP - Camco 3-15A 3-20-93 BHP - Camco 3-20 12-18-92 BHP - Camco 4-7ST 5-17-92 BHP - Camco 4-14 1-9-93 BHP - Camco 4-29 12-28-92 BHP Camco 4-42 4-27-92 BHP - Camco 5-9 2-21-93 BHP - Camco 5-16 2-21-93 BHP - Camco 5-25 2-21-93 BHP - Camco 5-31 2-21-93 BHP - Camco 5-33 1-29-93 BHP - Camco 5-35 1-29-93 BHP - Camco 5-36 1-29-93 BHP - Camco 9-24 2-15-93 BHP - Camco 9-40 1-25-93 BHP - Camco 9-51 3-20-93 BH P Camco 12-7A 12-6-92 BHP - Camco 12-7A 12-10-92 BHP - Camco 12-9 12-10-92 BHP - Camco 12-29 12-14-92 BHP - Camco 13-15 7-3-92 BH P - Camco 13-20 7-4-92 BHP - Camco 13-23A 7-4-92 BH P - Camco 13-32 7-3-92 BHP - Camco 14-11 11-23-92 BHP - Camco 16-19 10-19-92 BHP - Camco 16-21 10-19-92 BHP - Camco 16-30 9-28-92 BH P - Camco 17-3 12-12-92 BHP - Camco 17-10 11-8-92 BHP - Camco 17-11 2-8-93 BHP - Camco 17-20 12-21-92 BHP - Camco 17-21 12-21-92 BHP - Camco 18-15 6-14-92 BHP - Camco RECEIVED FEp, / z, I994 Alaska O# & Sas Cons. Anchorage C°rr~i$$!on STATE OF ALASKA ' ALASKA?'''~'~. AND GAS CONSERVATION C¢"~",/IISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdOwn Stimulate X Plugging Perforate ... Pull tubing Alter casing Repair well Other 5. Type of Well 6. Datum of elevation(DF or KB) 89 RKB fee~ I 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1090' FS, 1125' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM At effective depth At total depth 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM Development Exploratory Stratigraphic Service X 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-15i 9. Permit number/approval number 82-157 10. APl number 50 - 029-20831 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10642 feet 9213 feet Plugs(measured) Fill @ 10445' MD (4/20/92) Effective depth: measured 10445 feet true vertical 9045 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 78.5' 20" 350 sx AS Set II 78.5' 78.5' Surface 2492' 13-3/8" 2700 sx Fondu & 400 sx PFC 2581' 2581' Production 10120' 9-5/8" 500 sx CIG & 50 bbls PFC 10209' 8847' Liner 735' 7" 335 sx CIG 10639' 9211' Perforation depth: measured 10234-10254'; 10352-10382'; 10390-10400'; 10403-10413'; 10414-10424'; 10424-10434'; 10434-10442'; 10446-10456' true vertical 8868-8885'; 8967-8992'; 8999-9007'; 9010-9018'; 9019-9028'; 9028-9036'; 9036-9043'; 9046-9055' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9852' MD; 4-1/2", 12.6#, N-80, PCT tail @ 9947' MD · Packers and SSSV (type and measured depth) BeT 3-H packer @ 9841' MD; 5-1/2" Otis RQY SSSV @ 2205' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation .... 6532 -- Subsequent to operation .... 6298 -- Tubing Pressure 1932 1838 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil.. Gas . Suspended.__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~-~ Form 10-404 Rev 06/15/88 1038/5 KRF cc: SW, JWP Title Engineering Supervisor SUBMIT IN DUPLICATE 13-15i DESCRIPTION OF WORK COMPLETED MUD ACID STIMULATION TREATMENT 816193: MIRU CT & PT equipment to 4000 psi. through the perforation intervals at: Pumped a fullbore Mud Acid Stimulation Treatment 10234 - 10254' MD (Sag) 10352 - 10382' MD (Z4) 10390 - 10400' MD (Z4) 10403 - 10413' MD (Z4) 10414 - 10424' MD (Z4) 10424 - 10434' MD (Z4) 10434 - 10442' MD (Z4) 10446 - 10456' MD (Z4) Ref. Log: BHCS 10/18/82. Pumped: a) 83 bbls 6% HCI - 1.5% HF @ 4.0 bpm, followed by b) 114 bbls 1% NH4Cl Flush. Rigged down. Returned well to produced water injection & obtained a valid injection rate. RECEIVED AU G 1 199 Alaska Oil & Gas Cons. Commissio~ Anchorage .~_ STATE OF ALASKA ALASKA~-~. AND GAS CONSERVATION C('~'"VIISSION 0 j~ REPORT SUNDRY WELL OPERATIONS Operations performed: Operation shutdown ----. Stimulate X Plugging Perforate ~ Pull tubing Alter casing .,...- Repair well -..... Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1090' FS, 1125' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM At effective depth At total depth 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM RECEIVED SEP 2 1 Aiask~ 0il & Gas Cons. 6. Datum of elevation(DF or KB) 89 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-15i feet 9. Permit number/approval number 82-157 10. APl number 50 - 029-20831 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10642 feet 9213 feet Plugs(measured) Fill @ 10445' MD (4/20/92) Effective depth: measured 10445 feet true vertical 9045 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 78.5' 20" 350 sx AS Set II 78.5' 78.5' Surface 2492' 13-3/8" 2700 sx Fondu & 400 sx PF "C" 2581' 2581' Production 10120' 9-5/8" 500 sx CI "G" & 50 bbls PF "C" 10209' 8847' Liner 735' 7" 335 sx CI "G" 10639' 9211' Perforation depth: measured 10234'-10254'; 10352-10382'; 10390-10400'; 10403-10413'; 10414-10424'; 10424-10434'; 10434-10442'; 10446-10456' true vertical 8868-8885'; 8967-8992'; 8999-9007'; 9010-9018'; 9019-9028'; 9028-9036'; 9036-9043'; 9046-9055' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9852' MD; 4-1/2", 12.68, N-80, PCT tail @ 9947' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 9841'; 5-1/2" Otis RQY SSSV @ 2205' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure .... 4715 -- 4877 Tubing Pressure 1640 1446 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas. Suspended.__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 885/11 MGC cc: SW, JWP SUBMIT IN DUPLICATE 13-15i DESCRIPTION OF WORK COMPLETED ACID WASH & MUD ACID STIMULATION TREATMENT 4/9/92: RIH & tagged top of fill at 10391' MD. 4/18/92: MIRU & PT equipment. RIH w/CT & jetted a nitrified fill cleanout from 10391 - 10457' MD, then reciprocated a perforation acid wash across the perforation intervals at: 10234 10352 10390 10403 10414 10424 10434 10446 - 10254' MD (Sag) - 10382' MD (Z4) - 10400' MD (Z4) - 10413' MD (Z4) - 10424' MD (Z4) - 10434' MD (Z4) - 10442' MD (Z4) - 10456' MD (Z4) Ref. Log: BHC$ 10/18/82. Pumped 5 bbls 2% NH4CI Water, followed by 68 bbls 15% Xylene/7.5% HCI, followed by 10 bbls 2% NH4Cl Water. Displaced acid to formation w/firewater. Shutdown for 1.5 hour soak. Surged well using nitrogen to flowback acid from perfs. POOH w/CT. Rigged down. 7/19/92: MIRU CT & PT equipment to 4000 psi. Pumped a fullbore Mud Acid Stimulation Treatment through the perforation intervals (listed above). Pumped: a) 120 bbls 2% NH4CI Water @ 6.6 bpm, followed by b) 146 bbls 6% HCL - 1.5% HF @ 6.7 bpm, followed by c) 90 bbls 2% NH4Cl Flush. Rigged down. Returned well to seawater water injection & obtained a valid injection rate. RECEIVED S E P 2 1 1992 Alaska 0il & 6as Cons. [;ommiSSio~ Ntchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 ~REFERENCE: ARCO CASED HOLE FINALS 2-32 ~/"//! 6-21-92 Prod Profile Run 1, 5" 3-10 ??-;~/ 6-20-92 Inj Profile Run 1, 5" 3-26o~_!~'/ 6-28-92 Prod Profile Run 1, 5" 4-14 7~y'3~ 6-28-92 Temperature Run 1, 5" 5-5 77'- ~/? 6-22-92 Prod Profile Run 1, 5" 7-5 6-23-92 Prod Profile Run 1, ~" 9-38 6-30-92 Inj Profile Run 1, 5" 9-39 6-30-92 Inj Profile Run 1, 5" 12-17 ~-~/ 6-29-92 Leak Detect Run 1, 5' 13-15~-/~' 6-27-92 Inj Profile Run 1, 5" 13-298~-{/~ 6-19-92 Prod Profile Run 1, 5" 13-32~2~/~ 6-27-92 Inj Profile Run 1, 5" 14-14~/o/~ 6-26-92 Inj Profile Run 1, 5" 14-36~$-'/~$ 6-26-92 Inj Profile Run 1, 5" 16-7 ~.~'--~/ 6-19-92 Prod Profile Run 1, 5" Please sign and return the attached copy as receipt of data. RECEIVED BY ~_~ Have A Nice Day! Sonya W~II~ce ATO-1529 APPROVED_ _fi_?_____ Trans# 92150 Canlco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO 1. Operations performed: STATE OF ALASKA ALASKA L AND GAS CONSERVATION C(. .vllSSION REPORT OF SUNDRY WELL OPERATIONS Stimulate Plugging ~ Perforate X~ Alter casing .-.- Operation shutdown Pull tubing ~ 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1090' FS, 1125' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM At effective depth Repair well 5. Type of Well Development .,-- Explorata3f Straligraphic At total depth 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical ORIGIN J. 6. Datum of elevation(DF or KB) 89 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-15 9. Permit number/approval number 82-157/8-398 10. APl number 50 - 029-20831 feet 11. Field/Pool Prudhoe Ba~/Oil Pool 10642 feet Plugs(measured) 9213 feet Effective depth: measured 10572 feet true vertical 9154 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Sudace 78.5' 20" 350 sx AS Set II 78.5' 78.5' Intermediate 2492' 13-3/8" 2700 sx Fondu & 400 sx PF 'C' 2581' 2581' Production 10120' 9-5/8" 500 sx Cl 'G' & 50 bbls PF 'C' 10209' 8847' Liner 735' 7" 335 sx CI 'G' 10639' 9211' Perforation depth: measured 10234'-10254';10352-10382'; 10390-10400'; 10403-10413'; 10414-10424'; 10424-10434'; 10434-10442'; 10446-10456' true vertical 8868'-8885'; 8967-8992'; 8999-9007'; 9010-9018'; 9019-9028'; 9028-9036'; 9036-9043'; 9046-9055' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9852' MD; 4-1/2", 12.6~, N-80, PCT tail @ 9947' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 9841'; 5-1/2" Otis 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14, MAR 11 1992 Alaska Oil & Gas Cons. Commission Anchorage Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 5500 -- 1500 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations ~X 0 6150 -- 1785 16. Status of well classification as: Oil..._ Gas..._ Suspended__ Service Injector 17. I hereby certify that the f°rego)~is true and correct to the best of my knowledge. Signed ~-~ ~-[/~ ..... Title Senior Operations Engineer Form 10-404 Rev 06/15/88 // CC: $. Wallace, DSE SUBMIT IN DUPLICATE WELL 13-15 PERFORATING PROCEDURE . . MIRU ELU and test lubricator. RIH with perforating guns and tied in to Reference Log. . Perforate the Sag River interval 10234'-10254' MD, (Ref. BHCS 10/18/82) at 4 SPF. 4. RD ELU and returned well to injection. RECEIVED MAR 1 1 1992. Alaska 0il & Gas Cons. (;ommissio~ Anchorage lI !m ~ ~. 5000 2. ~400 PSI Wl~EI. INl: RAMS (VAJ~IABI.[ SIZE) 4. 5000 P~I 4 l/e," Itl. OW TUBE PACK-OFF td!,R~L, z~ BOP, [~~.NT ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 2-21-02 2-25 .7 7~j 12-3-91 q~.-- Y7 12-3-91 c4-7 12-3-91 3~~1-~ Perforation l~m 1, ~' HLS Tmcer-Chek Temp l~m 1, ~' HLS ~ ~ 3, ~' Sch Leak Detect Bun 1, 1" Camco Please sign and return the attached cog as receipt of data. RECEIVED BY__~u _~_~_~ Have A Nice Day~ Sonya Wallace ATO-1529 # CENTRAL FILF~ # C~IEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PB WELL ~ R&D #BPX # STATE OF ALASKA TEXACO RECEIVED FEB 2.5 1997. Alaskm Oil & G~$ Cons. Commission Anchorage STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CC ,,IlSSIOI'II~ APPLICATION FOR SUNDRY APPROV/ ES' 1. Type of Request: Abandon , , Suspend , Operation shutdown Re-enter suspended well Alter casing ...--- Repair well Plugging ...-- Time extension Stimulate Change approved program "~ull tubing Variance Perfor~'~te X Other 5. Type of Well 6. Datum of elevation(DF or KB) Development ...__ RKB 89' Exploratory Stratigraphic Service X , 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1090' FSL, 1125' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM At effective depth At total depth 347' FSL, 78' FEL, Sec. 15, T10N, R15E, UM 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-15 9. Permit number 82-157 10. APl number 50 - 029-20831 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10642 feet Plugs(measured) 9213 feet Effective depth: measured 10572 feet true vertical 9154 feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Surface 78.5' 20" 350 sx AS Set II 78.5" 78.5' 2700 SX Fondu & 2581' 2581' Intermediate 2492' 13-3/8" 40o ,x PC ,c soo,x c~ ,~ & 10209' 8847' Production 10120' 9-5/8" 5o bbls PF 'C' Liner 735' 7" 335 sx CI 'C' 10639' 9211' Perforation depth: measured 10352-10382'; 10390-10400'; 10403-10413'; 10414-10424'; 10424-10434'; 10434-10442'; 10446-10456' true vertical 8967-8992'; 8999-9007'; 9010-9018'; 9019-9028'; 9028-9036'; 9036-9043'; 9046-9055' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9852' MD; 4-1/2", 12.6#, N-80, PCT tail @ 9947' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 9841' MD; 5-1/2" Otis RQY SSSV @ 2205' MD 13. Attachments Description summary of proposal Detailed operations program BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: December 1991 16. If proposal was verbally approved Oil Gas Suspended Name of approver Date approved Service Injector 17. I hereby certify that the foreg~r~ is true and correct to the best of my knowledge. Signed '~"~~ ~ ~-"~'~ Title Wellwork Coordinator Date '/~~ FOR COMMISSION USI= ONLY IAppr°val N°'4~/ COnditiOns of approval: Notif~.~ommission so representative may witness Plug integrity BOP Test Location clearance ~.: .... Mechanical Integrit~Test Subsequent form required 10- ~j'-~-~ ~ .....~"~ ~ l'";',.,: .'. ORIGINAL SIGNED BY /'~. Approved by order of the Commissioner LONNIE C. SMITH Commissioner Date / Form 10-403 Rev 06/15/88 c: SW SUBMIT IN TRIPLICATE WELL 13-15 PERFORATING PROCEDURE · · MIRU ELU and test lubricator. Perforate the Sag River interval 10238'-10252' MD, (Ref. BHCS 10/18/82) at 4 SPF. 3. RD ELU. 5 4 3 2 1 L CO~L~D TUSZNg UNIT 80P 1.SO00 PSI 7" WCLL~ COI4~CTOR 2.SO00 PSI 4 1/1&# PIPE: RAMS ~.SO00 PSI 4 I/E," ~IC: SLI~ 4.SO00 PSI 4 l/&" SIKAR RAMS S~-SO00 PSI 4 l/&- BLN) KnaS S. SO00 PSi 4 1/14' STUIrF~ BOX 2 ,HII~L ],NE BOP 1. S000 PSi 7' IKLLHr.4D CONN[¢tOR ri. ~ PSI ~[LIN[ ~ (V~~L[ SI; 3. ~ P~ 4 1/~" L~RI~T~ 4. ~ fg 4 1/l- rL~ TUB[ PACK-Or ARCO ALASKA, P.O. BOX t00360 ANCHORAGE, ALASKA DATE: 7-t2-9t REFERENCE: ARCO CASED HOLE FINALS t-tt t-tt t -2t 2-4 4-t %4-37 7-~5 9-i8 t t-5 -22 ~2-t2 t~-t5 **** t ~-t 6 i6-i6 t7-t iT-it 6-5-9i PROD F'ROFILE~" RUN i, 5' CAMCO 6-5-9t GR-COLLAR J RUN t , 5' CAMCO 6-7-9i F'ROD PROFILE/ RUN i, 5' CAMCO 6-30-9t CCL-PERF/ RUN t , 5" ATLAS 6-ii-9i GAS LIFT/ RUN t, 5 · CAMCO 6-t9-9i CBT/ RUN t , 5 · SCH 6-i9-9i CET--- RUN t , 5' $CH 6-2i-?i F'FC-GR (PACKER £ETTING)~ RUN t, 5" ATLAS 6-2i-9i CBTj RUN i, 2'&5' $CH 6-2i-9i CETJ RUN t, 2'&5 · $CH 6-24-~i PFC-GR (F'ACKER SETTING)~ RUN i, 5' ATLAS 6-28-9t GR-CCL-- RUN t , 5' ATLAS 7-2-9i COLLAR-F'ERF~ RUN i , 5' Al'LAS ?-2-9t PRODUCTION PACKER-- RUN t , 5 · ATLAS 6-30-9i SBL/GR/CCL- RUN t, 5" ATLAS' 6-30-9t CCL-PERF-- RUN t, 5" Al'LAS 6-i6-9i _ LEAK DETECTIONs' RUN t, 2 ·&5. CAMCO 6-5-9t PERFORATION BREAKDOWN~ RUN t, 5 · CAMCO 6-23-9i COLLAR-PERF-- RUN i, 5 · ATLAS' 4-t7-9t INJ PROFILE/ RUN t, 5 · CAMCO 6-i~-9i dEWELRY~ RUN t, 5' CAMCO 6-t4-9i LEAK DETECTION-- RUN t, 2" CAMCO 6-i2-9i INJ PROFILE-~ RUN i, 5' CAMCO 6-8-9t DATA FRAC TEMP--- RUN t, 5' CAMCO 4-t?-9t LEAK DETECTION--~ RUN t, 5" CAMCO 6-t2-9i- PROD PROFILE---. RUN t, 5' CAMCO 7-i-9i PDK--iOO/GR/CCL-BORAX-~ RUN i, 5' ATLAS 6-t6-9t LEAK DETECTION-- RUN t, 2'&5' CAMCO 6-i7-9i INJ PROFILE--- RUN i, 5' CAHCO 6-t7-9t INJ PROFILE--- RUN t, 5' CAMCO 6-i3-9i INJECTION/PRODUCTION-- RUN i, 5' CAMCO 6-i6-9i PRISM-- RUN t, 5' ATLAS 5-8-9i LEAK DETECTIOL RUN i, 2"&5' CAMCO RECEIVED BY HAVE A 'NICE DAY! SONYA WALLACE ATO-i 529 DISTRIBUTION CENTRAL FILES 'CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL BPX STATE OF ALASKA TEXACO * CORRECTED'LOC.INTERVAL FOR 9-6 IS 6700-7700 ** REFERENCE MIX UP ON TRANSMITTAL 9tt59 - POSSIBLE DUPLICATE LOtS *** CORRECTED LOGGED INTERVAL FOR 9-48 I£ i375t-~425i **** CORRECTED API~ FOR t3-t6 IS 58-829-2~823 ARCO ALASKA, INC, F',O, BOX t00360 ANCHORAGE, ALASKA 99.~t REFEF(FNCE' AF(CO CASED HOLE F'*INAI..,S'. ' "~ -"~"~;-. o n F' ITg '~ 3-',.6 t t ~.. ...... /4-2 t2 .... t2--'99 CNL./GR ~ 4-5 t '~ .... ,,. t 2-90 C:NI.../C;R ~4-.f 8 t 2..-1S-..90 CNL./GR .~--,.. t . .-. F:'DK -.. t ¢5-..'.S t t--t 4.--~G F'ROD F'ROFrlLE w5-.5 t2 .... t5 ~0 F'DK t ~ 7.- ''~ 2 '"""" ~3 tt/ 2&25/~0 FEKF BREEAI(POWN Z 7-.~ t t .-.'~ F' ~. ,;.t .-.~G I:~E-FRAC TEHP ~ 9.-..3 12-. t 4-..9G COI...I...AIr(/F'EF(F ~ 9--45 t 2.-.8-..~0 "I " ', ....," CO LI...AR/F EI.~F ~ 9-46 t 2-6.-.-98 COLL. AI~/F'EERF ~ t S ..- t 5 t 2 .-. 2-.. 90 I N J F:'R 0 F I I... E / t :~ -.. t 6 t 2 .... 2 -.-. 9 O I N,J F:' R 0 F I I... E ~ t4 .... t. tt .... t6.-.90 F'ROI) F'ROFILE F:' I..E A.'.9 E 5; I (; N A N D R E T U R N T' Fi E A T'I"A C I..I E D t.-IAVlii; A NICE DAY! ,S'AL.L..Y I-IOF:'F'Ii~C':I;..'.' ER A TO--. t 529 RUN R U N RLJN RbN RUN RUN RUN RUNS RLJN RUN RUN RUN R Y N R U N RUN OF:' DAT'A A I::: F:' R 0 V E. I) .~ 5" A'I I.. A,S' A'I'L.A,S' A T I_ A,5," Al'LAS CAMCO ATL. A,S' CAMCO CAMCO ATI..A£' Al'LAS ATI...Ag C A H C O C A M C O D I $ T R I B U T I 0 N · ~ C E N '¥ I'"(A !... F I I_ IF. ;~' 'il' '"' C H E V F:,' ,,. ON · ,,~'"' E',"T EN,S' I ON,, EXF'L. OF;:A T I Oi',~ ~: FXXON i'.f~ R ~"1" I.-I0 N · .- MOBIL F' H I I... I.. I F',t;' F'B WELl.. F'ILES R & D '"' B F:' ~' · Ir · · STA'I'EE OF' ALASKA -ir TEXACO .RECEIVED DEC 2 7 1990 .Alaska 011 & Gas Cons. Com~nigslorl Anchorage ARCO Alaska, Inc.~ Prudhoe Bay ,.ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June '28, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-15 Approval No. 8-398 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JCB/jp Attachment CC: T. B. Gray, BP J. Gruber, ATO-1478 PI(DS 13-15) W1-3 RECEIVED J U L '° ~ ]989 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK ,,~'"~",L AND GAS CONSERVATION Cr'"-'MISSION REPORT oF SUNDRY WELL OPIr..RATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging ,, Perforate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1090' FS, 1125' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM At effective depth At total depth 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service Other 6. Datum of elevation(DF or KB) 89 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-15 9. Permit number/approval number 82-157/8-398 10. APl number 50 - 029-20831 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Sudace 78.5' Intermediate 2492' Production 10120' Liner 735' 10642 feet Plugs(measured) 9213 feet 10572 feet 9154 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 350 sx AS Set II 78.5' 78.5' 13-3/8" 2700 sx Fondu & 400 sx PF 'C' 2581' 2581' 9-5/8" 500 sx CI 'G' & 50 bbls PF 'C' 10209' 8847' 7" 335 sx CI 'G' 10639' 9211' Perforation depth: measured 10352-10382'; 10390-10400'; 10403-10413'; 10414-10424'; 19424-10434'; 10434-10442'; 10446-10456' true vertical 8967-8992'; 8999-9007'; 9010-9018'; 9019-9028'; 9028-9036'; 9036-9043'; 9046-9055' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9852' MD; 4-1/2", 12.6~, N-80, PCT tail @ 9947' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9841'; 5-1/2" Otis RQY SS ~) 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached 14. J U L - 3 19 9 Treatment description including volumes used and final pressure /~l~sV, a 0il & Gas Cons. Commission Anchorage R..epresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1600 -- 1550 Subsequent to operation 0 0 4200 -- 1375 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended .. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /'1__ Signed '~,~-'~'Zj.,~,,~~,,,'"" Title Operations Engineering Manager Form 10-404 Rev 06/15/88 086 J.C. Bmden, 263-4536 SUBMIT IN DUPLICATE Drill Site 13-15i Selective Stimulation Procedure 7/6/88 ARCO Alaska performed the following stimulation treatment: 1. MIRU wireline unit. Tagged bottom and recorded PBTD at 10564'MD. 2. Loaded 4000 gal of 15% HCI acid and 8000 gal of 12% HCI-3% HF acid. 3. Loaded 5000 gal 2% NH4CI water containing a biocide. 4. Loaded 1000 gal. 2% NH4CI water gelled with 40 lb/gal HEC polymer and containing a foaming agent and a biocide. 5. Loaded 350 bbl seawater. 6. Loaded 200 MSCF Nitrogen (180 M for the job and 20 M for warm-up). 7. MIRU pump trucks and nitrogen truck. Installed a foaming aspirator (foaming tee or foaming orifice) in the injection manifold 8. Rolled all acid compartments before pumping fluids downhole. 9. Pumped the following fluids down the tubing' a. 2000 gal. b. 4000 gal. c. 4000 gal. d. 150 bbl. e. 2000 gal. f. 4000 gal. g. 1000 gal. h. 35O bbl. 15% HCI with additives, dispersed with 10% xylene 12% HCI-3% HF with additives, dispersed with 10% xylene 2% NH4CI water 85 Quality Foam consisting of 1000 gal of 2% NH4CI water with foaming agent and 40 Ib/Mgal HEC polymer, nitrified with 7560 SCF N2/bbl water (180 MSCF N2). 15% HCI with additives, dispersed with 10% xylene 12% HCI-3% HF with additives, dispersed with 10% xylene 2% NH4CI water seawater (filtered) 1 0. Resumed water injection at RIR. Recorded rate and wellhead pressure. 1 1. RD and released pump trucks and transports. RECEIVED JUL - 3 19 9 Alaska 0ii & Gas Cons. O0mmJssJo.q Anchorage ARCO Alaska, Inc. /~"~ Prudhoe Bay =.,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 18, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-15 Permit No. 82-157 ~j 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/JCB/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 PI(DS 13-15)W1-3 WELLS2/147 ARCO A~aska, ~.c. is a $.,b$idiary o! AtlanticRichfie~dOompamy AR3B--6132-C STATE OF ALASKA ALASk_. OIL AND GAS CONSERVATION COMI~ SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon f-; Suspend ~ Operation Shutdown ~ Re-enter suspended welt ~ Alter casing Time extension © Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska, [nc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1090' FSL, 1125' FEL, Sec. 14, TIN, R14E, UM At tOp of productive interval 316' FSL, 75' FWL, Sec. 14, Ti0N, R14E, UM At effective depth At total depth 347 ' FSL, 5. Datum elevation (DF or KB) 89' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 13-15 8. Permit number 82-157 9. APl number 50-- 029-20831 10. Pool 78' FEL, Sec. 15, T10N, R14E, UM feet Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 1-0642 feet 9213 feet Plugs (measured) Effective depth: measured 10572 'true vertical 9154 Casing Length Size Surface 78.5 ' 20" Intermediate 2492 ' 13-3/8" Production 10120 ' 9-5/8" Liner 735 ' 7" feet feet Junk (measured) Cemented 350 sx AS Set II 2700 sx Fondu & 400 sx PF 'C' 500 sx C1 'G' & 50 bbls PF 'C' 335 sx C1 'G' Measured depth Rue Verticaldepth 78.5' 78.5' 2581' 2581' 10209' 8847' 10639' 9211' Perforation depth: measured 10352-10382'; 10390-10400'; 10403-10413'; 10414-10424'; 19424-10434'; 10434-10442'; 10446-10456' true vertical 8967-8992'; 8999-9007'; 9010-9018'; 9019-9028'; 9028-9036' 9036-9043'; 9046-9055' Tubing(size, grade and measured depth) 5½" 17#, L-80,-PCT @ 9852' MD; 4½" 12 6# N-80 PCT tail @ 9947' MD Packers and SSSV(type and measured depth) BOT 3-H packer @ 9841' MD; 5½" Otis RQY SSSV @ 2205' MD 12.Attachments Description summa~ of proposal [] Detailed operations program 13. Estimated date for commencing operation May 1988 14. If proposal was verbally'approved Name of approver Date approved 15. I hereby, A:ertify that_the_foregoing is true and correct to the best of my knowledge signed ~)_~,._~.~~~~ . Title Operations Engineering Manager Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. m Plua intearity .--_ BOP Te~st,-_~Location clearanceI - ~ " Approveo,-,u~-: 0RIGINAI~' ~Cm~0 BY Returne -. LONNI~ C, SMiTH~ by order of APprOved by ' Commissioner the commission Date Form 10-403 Rev 12-1-85 Su~mit in triplicate WELLS2/147 J. C. Braden, 263-4536 Drill Site 13-15i Selective Stimulation Procedure ARCO Alaska, Inc., proposes to perform the following stimulation treatment: 1. MIRU wireline unit. Tag bottom and record PBTD. 2. If PBTD is above 10456'MD (bottom of perforations) then perform a FCO. 3. Load 4000 gal of 15% HCI acid, 8000 gal of 12% HCI-3% HF acid. 4. Load 5000 gal 2% NH4CI water. 5. Load 1000 gal 2% NH4CI water gelled with 40 lb/gal HEC polymer and foaming agent. 6. Load 350 bbl seawater. 7. MIRU pump trucks and nitrogen truck. 8. Roll all acid compartments before pumping fluid downhole. 9. Pump the following fluids down the tubing: NOTE: All fluids, except the foam diverter fluid, should be filtered to 2 microns. 2000 gal. 15% HCI with additives, dispersed with 10% xylene 4000 gal. 12% HCl-3% HF with additives, dispersed with 10% xylene 4000 gal. 2% NH4CI water 150 bbl. 85 Quality Foam consisting of 1000 gal of 2% NH4Cl water with foaming agent and 40 Ib/Mgal HEC polymer, nitrified with 7560 SCF N2/bbl water (180 MSCF N2). 2000 gal. 15% HCI with additives, dispersed with 10% xylene 4000 gal. 12% HCI-3% HF with additives, dispersed with 10% xylene 1000 gal. 2% NH4CI water 350 bbl. seawater (filtered) 1 0. Resume' water injection at RIR. Record rate and wellhead pressure. 1 1. RD and release pump truck and transports. 5 4 3 2 COILED TUBI.,NO UNIT BOP EOU]PHEN~ 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYD~LK~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PS1 4 1/~" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 2 HIREL]NE ,BOP E()UIPM. ENT 1. 5000 PSI 7" WELLHEAD CONNECIOR IrLANG! 2. 5000 PSI WIRELINE RAUS (VARI&BLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO AI...A,.~KA.. lINC~ I:'.. 0., BOX ~ O0..A. 60 ANCHORAGE ~ A I...A,.~K A 995j DA'rE: 4-26-819 F,'.F:FERF. iNCE: ARCO CASED FIOI_F FINAl... 2-.9 4- t 6..-.R..~ PRO!) ,. F'RFI..F.E/Fl..T) D .F..H,~ 'm /TF'HF' .:~ 4.-~ ',;)./t :'.~.--.RR HT.%'C.. [;A,.? IN..IFCTTOW PR'Or:TI. F · I :~ -.-. ,'..! ?; 4.--'1 :~....R!..I HT~f.';, ,. [;.A,.~ l:lg.lr-':C.l'Tl:lisl I::'F;~f]F'.'[I...F F'I,,IDI,J:'.z,,.- i .4'- 'J O.-.Rf!t I:':f":l...-I"F'.HF'FI'i'AI'I. IF';.'F I. f:lf'; 1.1' F C. F!' T V F I) ,E{ Y ............ i..I th '~! !!i: A H ]: fl; I:i: [) th Y F:' E". G G Y A T 0 .... t ':.~ 2 (:A RI.IN 'l, 5' 1.1'IiIN'~ . ~" RI.IN i: ~" I:;.,lllxl ,I . %' F ~;E..". '1: F:"F f'l F' D ¢~ l' A, A F:' F' 1.1' f) t/I!!~ D .................... ..~. ........................................................... ~) .T. ,% 'T' !~' 'r ¥:{ I, Il' T 0 KI [: ~ H F: Fl C A H C. 0 .,,.'"' CF..:N'T'RAI....F'T I...F.,.% :.":. CHI.'..'. VR 0 N "° II · ,.'"' IFX'FEN,~ T. ON . E:,XF l..OR'Al' I (.IN HAI.i'A'FHON :) HOB ,T.I... F'H I I...I... l' P,.~ F'R WFI...I.,. r:'r I.. ,.~'TAI'F...; OF ~I...A..~'FA TEXACO ARCO Al. as'l.,'a, Inc. I::' ,. 0. B o x t () (.) :3 6 (-) A n c h o ~- a g e, A I. o .,; I.,' o 99.;' ~ (.) D A ]" F.:: ' A p '," i I. 8, i 9 8'? F;,' Iii: F:' E F;,' ["' N C l-'i: · A R C 0 C a .'..; ecl I--Iol. e Final. Ca [~,::: o (:~a m c:: o F:' I. e a .'..; e .'.-..'.' i g n a n (:1 r' e !' u r' n -t: h e a t: !' a c h e d (:: o p y a ~; ~" e (:: e i I::' '? o 1"' F;,'ecei vecl By ...................................................................................... I.-I A V ii!: A N I C Iii: D A Y ! R o .'-;' a ;"~ ~'; e J::' e e I,'. A ]" 0 .... t 5 2 9 A p p I" o v ecl ...................... ~.l~ ........................................................... D I ;~' ')" R I B LI')" I [) N '"'.,.C e ~", 't' r' a L 1::' i L r..-._. _,¢. -,,. C h e v Y' 0 ~] I) & M ,11. -,. E x !' e ¥;.'.-!.' i o n E x p 1. o r' a t' i o n ,11, · ,. [il X X 0 M a r' a t' I'; o'n · ,'"'. M o t::, i l '"'...F:'hi I. Lip ..,~' PB We [ !. F'i 1. e.'.-:' '"' Zoh io · ,. ,.:. -t: a t: e o'f ALas'ka · ~r'"'T e X a C 0 Oil ~ {:~:,s Cons. commission ,lnch,m'a~e a..CO Alaska P.O. Bo× 1 Anchorage, Ala£ka 995f ¢., DATE' Augu~$. 11, !..°.86 REFERENCE' ARCO Cased RoLe Final ~-~ 6 7-3~ _o, Zr, jr-,c-'- i o'.r,. F .... ,.-) ,'f i I ,=. .q'ur~ ':-'i ~ I '-"~-'""=: " ,_.. -.--,_, c.,_, CET Lc, e, pr~-_:-.s,~.ueeze Ru.'n i'-,--z 12-1":'--E:_.s F'erfora~'i'nq Record ""u'n .'i "-" · .' ~,_, Per for8 f i ng Record Run I .- , ," i,~° t ,S'_.'. Comp L~+_.; oll ,q'~cor d,_. Null t°-°I t ~ 44_o=. ..'-, . ~.~ Comp [et ion Record · Run i · " 4- · ~,' I ,')_":,. o t ")-t ~-S~ Coi,~p Le"' ' ~ _. , Jot, Reef, rd Run t · t3-15 I°-t~.- ..--o~_:. F'~r¢orati;-~g_ Record Run 2_, 13-t? I?-?,:~-°=~,~ Perf and REF'erl= ,r';:,~n I q'" 16-7 i i-z_..~=.-Bq;_ CET log Ceinen~ Eva L log Run F'!.ease £i~nd~l~~a,' ~[/~~hed cor,~'~ 'r~,r__..~i, f. ,~ A NICE DA~ltska Oil & 6as Cons. C0mm[ssi0n L i ~da Hu TRAN$ -·-,",: of daCa, C ~ hi 2. (: h ~:ch ~,'c h ."-,'ch $ch ~'c h -v. en+raL , : [es' ;': I.. ,-. i i E'.'" V i- 0 i'i J'i Exi'e'n~fc...r., F:,:p Lo'.,-a¢ ior, E×xofi Hara +.hon i'*.' · ,ob i [ ~;,.7.' i. J. ~" ", ,=..-. F: /:.... ]_':, '~' State of ALa'_-.-ka ~l. ~, Taxaco ARCO Alaska, Inc.r'''~ Prudhoe Ba~ ~_ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 5, 1986 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re- DS 13-15 DS 13-25 DS 13-32 Permit No. 82-157 Permt No. 82-91 Permit No. 82-123 Enclosed is the revised Completion Report for work done on the above-menti onecl wel 1 s. very truly yours, D. F. Scheve DFS/SKAD/jj Enclosures cc: SOHIO Alaska Petroleum Co. File PI(DS 13-15)Wl-3 PI{DS 13-25)W1-3 PI(DS 13-32)W1-3 RECEIVED NAR 0 5 1986 Alaska Oil & Gas Cons. Com,missio~ Anchomge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfietdCompany STATE OF ALASKA ~ ALASKA( ,L AND GAS CONSERVATION C .:, ~MISSION · WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISED OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] NAG INOECTION 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. $2-1~7 3. Address 8. APl Number Post Office Box 100360, AnchoraKe, AK 99510 50- 029-2083] 4. Location of well at surface 9. Unit or Lease Name 1090' FSL, 1125' FEL, Sec. 14, T10N, RlbE, UM Prudho~ B~v Unit At Top Producing Interval 10. Well Number 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM DS At Total Depth 11. Field and Pool 347' FSL, 78' FEL, Sec. 15. TiON. R14E. UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 89' RKB] ADL 28315 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. ND. of Completions 10/04/82 10/18/82 10/26/82I I. N/A 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 10642'MD.9213'TVD 10572'MD,9%53'TVO YES [] X NO [] nippl~ fd?205 feet MD 22. Type Electric or Other Logs Run DTT,/RP/~R_ I')TT./RT1lq.q/~P / R~ T.TI'P/~MT./C'.P/~ 1 ~T./~/T~T./~P/~(~T. 23. ' .... CA'Si~ LINER AN'd~'E-~-NTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surf 78.5' 30" 350 sx AS Set II 13-3/8" 72.05A L-80 Surf 2581' 17%" 2700 sx Fondu & 400 sx PF "C" 9-5/8" 47.05~ L-80 Surf 10209' 12~" 500 sx Class "G" & 50 bbls PF "C" 7" 29.05~ L-80 9904' 10639' 8-~" 335 sx Class "G" 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) 5½" 9947 ' 9841' 10352-10382 'MD 10390-10400 ' MD 10403-10413'MD 26. ACID, FRACTURE, cEMENT sQuEEZE, ETC. 10414-10424'MD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10424-10434 'MD , 10434-1044 2 ' MD 10446-10456 'MD 8967- 9054'TVD ~^= ~,,~o ~,~o,o~ N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) I ' .{,-,,~ T1~11 - ~,,-, ~-,.~,..~- .... 41 .1- In3ect .... ~.~ .............. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I N/A TEST PERIOD Flow Tubing Casing Pressure cALCULATED.l~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cDr'r) Press. 24-HOUR RATE ~r 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7~1-80 CONTINUED ON REVERSE SIDE Submit in duplicate % - 29. ~' 30. GEQLOGIC MARKERS FORMATION TESTS """ NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10345 ' 8961' N/A O/W Contact 10492' 9085 ' Base Sadlerochit Not Reached 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/')--F'/_ ~/~,~~ ¢'~ Title Oper.En~r.M§r, Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Prudhoe Bay L..=~ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 9, 1986 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: DS 13-32 Permit 82-157 Permit 82-123 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SKAD/vh Enclosure CC: SOHIO Alaska Petroleum Co. File Pi(DS 13-15)W1-3 Pi(DS 13-32)W1-3 RECEIVED JAN 1 t986 ~mska 011 & Gas Cons. ~mmti~ioa ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA _ s^s 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. 82-157 ._ 3. Address 8. APl Number Post Office Box 100360, Anchorage, AK 99510 50- 029-20831 4. Location of well at surface 9. Unit or Lease Name 1090' FSL & 1125' FEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 316' FSL & 75' FWL, Sec. 14, T10N, RlhE, UM DS 13-15 At Total Depth il. Field and Pool 347' FSL & 78' FEL~ Sec.15~ T10N~ R14E~ UM Prudhoe Bay Field ~. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 89' RKBI ADL 28315 · ~2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 16. No. of Completions 10/04/82 10/18/82 10/26/82J N/A feet MSL I , 17. Total Depth (MD+TVD) 18. Plug Back Oepth (MD+TVD) 19. DirectionaISurvey i 20. Depth where SSSV set 121. Thickness of Permafrost 10642'MD 9213'TVD 10572'MD, 9153'TVD YES [~ NO [] nipple @ 220~et MD 1900' (aoorox. 22. Type Electric or Other Logs Run DIL/SP/GR, DIL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL/VDL/GR/¢¢L . . 33. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD 'AMOUNT PULLED 20" 91.5# H-~0 .~11~-¢~ 78; 5' ~O" 3~0- ex Arctic Set !! 13-3/8" 72.04~ L-80 Surf~ ~SRl' 17t~,, 77~ ~ ~nn~,, g /,~ ~w ~ "~." 9-5/8" 47.0~ L-80 R,r~n~ 10?_Oq' 17~." 5~ ~w C. 1~ ,,n" ~ ~ ~o ~' ,,~. 7" 29.0# L-80 9904' 10639' 8~" 33~ mx Clmq.~ C~ I , 24. Perforations open to Production (MD+TVD of Top and Boitom and 25. TUBING REcoRD interval, size and number) SIzE DEPTH SET (MD) PACKER sET (M6) ~ , , 10352-10382 ' MD 5~" 99~7 ' 98/:1 ' 10390-10400 'MD 10403-10413'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, E-FC. 10414-10424'MD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL uSED ... 10424-10434 'MD N/A 10434-10442 ' MD 10446-10456 'MD 27. PRODUCTION TEST r Date First ProductiOn Method of Operation (Flowing, gas lift, etc.) .IDj¢ction Well - nm ~m.~t.~ mvm{l~hl~, Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF ~-WA-TEF~-BBL CHOKE SIZE GAS-OIL RATIO N/A TEST PERIOO ~ Flow Tubing Casing Pressure CALCULATEDall OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APi' (corr~) - Press. 24-HOUR RATE "Ir , 28. CORE DATA ,. Brief description of lithology, Porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ~/A JAN 1 1986 Alms~ 011 & Gas Cons. Comm~ion An~:~rage Form 10-407 Submit in duplicate Rev. 7~1-80 ' CONTINUED ON REVERSE SIDE 29. 30. 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 Sadlerochit 10345' 8961' ~/A O/W Contact 10492' 9085 ' Base Sadlerochit Not Reached 31. LIST OF ATTACHMENTS 32. I here. by 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: ~'~t' supp~emen~a records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item .27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- ject~On,' ~as Injection; S~d~n; ~'t. her-expla~n. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. f Prudhoe Ba~ _~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 9, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-15 DS 13-32 Permit No. 82-157 Permit No. 82-123 Enclosed are the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SKAD/vh Enclosure CC: SOHIO Alaska Petroleum Co. File Pi(DS 13-15)W1-3 Pi(DS 13-32) W1-3 RECEIVED JAN 1 1986 Alaska Oil & t~ Oon~. gomml~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [J~× OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-157 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Slz~'_Fa~e. 1090' FSL & 1125' FEL, Sec. 14 T10N, R14E, OM At Top Producing Interval: 316' FSL & 75' FWL, Sec. 14, T10N, R14E, UM At Total Depth: 347' FSL & 78' FEL, Sec. 15, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 89' RKB I ADL 28315 12. 8. APl Number 50-- 029-20831 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-15 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil 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 [] Alter Casing [] Perforations [i~X Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] 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). Began perforating operation on 12-11-85. RU perforating unit and pressure tested equipment. RIH w/gun 9lA and ~iB, shot interval 10446-10456'MD (4 spf) and interval 10434-10442'MD (4 spf), flowed well to cleanup. SI well, POOH, all shots fired. RIH w/gun 92, shot interval 10414-10434'MD, (4 spf), flowed well to cleanup. SI well, POOH, all shots fired. RD. RU perforating unit 12-12-85. Pressure tested equipment. RIH w/gun 93A and gun #3B, shot interval 10403-10413'MD (4 spf) and interval 10390-10400'MD (4 spf), flowed well to cleanup. SI well, POOH, all shot fired. RIH w/gun 94, shot interval 10362-10382'MD (4 spf), flowed well to cleanup. SI well, POOH, all shots fired. RIH w/gun 95, shot interval 10352-10362'MD (4 spf), flowed well to clean up. SI well, POOH, all shots fired. Ran SSSV, secured well, RD. Ref: BHCS 10-18-82 JAN 1 ~ Z~86 ,Oil & 6as Cons. (~ommi#iofl 14. I hereby certify that the foreg_oing.j.S true,, and correct to the best of my knowledge. Signed ¢' Title Operations Engineering Mgr. The space below for Commission use Date Conditions of APproval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO ALaska, P.O. Box Anchorage, Alaska 995i £) REFERENCE' ARCO Cased HoLe T:, ~' i S- © -'.4 i2 i4 8= I)S i S-32 i 2-i ~' 8~ O-- ,..> ]Z r, j e r_ t.. i c,'n F' ;- c) f i L e / S p i n r, e r Rtl l'l i .,':~ ' Sp.;r~ner/'In] F'rofi /e L. og Rur~ i ._~'='" Ir, ject'ior, Pre, fi [e/Spir, r, er Ru.r, i Ca hiC 0 C B hi C 0 C ~ii hi C 0 F'Lea_,~e sign and ret'urr~ i'he a'ti',_=~ched copy Received By HAVE A NICE DAY! <el. Ly McF:'arLa~,..~ ATO-i 429F TRANS '"'"'" .... '-' ... ~r C:, 0 ~.~ L¢ ~. i) ]: ."i."F R ]: .B U ]" ]: [) N. · ~.'Ce'n't'ra [ Fi Le.s ':.Ch evr o'n. D & H ,E,×'t:er~.s'ior~ Exp Lo'Fa!'io'n. Ex xon Mob i l. Phil. Lips F:'B WeLL F"i Lc:-.' R & D ::'LS' o h i o ¢t'a~e of ALm~I<a , 'J"e x 8 c: o ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-15 Permit No. 82-157 13-19 81-180 13-20 82-09 13-21 82-53 13-23A 82-23 13-24 82-65 13-25 82-91 13-32 82-123 Attached are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:JEB:dp Attachment CC: SOHIO Alaska Petroleum Co. File Pi(DS 13-15)Wl-3 P1 (DS 13-19)W1-3 PI(DS 13-20) W1-3 P1 (DS 13-21)W1-3 PI(DS 13-23A)W1-3 Pl (DS 13-24) W1-3 Pi(DS 13-25)W1-3 P1 (DS 13-32) W1-3 ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-157 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20831 4. Location of Well 1090' FSL, 1125, FEL, Sec. 14, T10N, R14E, DM (surf) 9. Unit or Lease Name Prudhoe Bay Unit 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM (Top Prod) 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 89' RKB 6. Lease Designation and Serial No. ADL 28315 10. Well Number DS 13-15 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~X Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation 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.) 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 perforate well 13-15 at selected intervals within the Sadlerochit sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10390-10400'MD 10352-10382'MD (reperf) 10414-10424'MD 10403-10413'MD (reperf) 10434-10442'MD 10424-10434'MD (reperf) 10446-10456'MD (reperf) Ref: BHCS 10-18-82 RECEIVED o ? Alaska Oi~ & Gas Cons. C0mmissJ0~ Anchorage 14. i hereby~tify that t~fo~oin,~ true and correct to the best of my knowledge. // Signed ...~_.~~~. '~ Title Operations Engineering Mgr. The space below for Commission use Date Conditions of APproval, if any: COMMISSIONER ~proved Co~y 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 x 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Pressure Data D.S. 3-19f D.S. 3-22/ D.S. 3-23 D.S. 4-1/ D.S. 6-4/ D.S. 6-7~' D.S. 6-18 D.S. 6-23 D.S. 7-20 D.S. 7-21 D.S. 7-22 D. S. 7-24 D.S. D.S. D.S. 7,25/ 7- 26' 12-7A/ -D.S. 12-15" D.S. 12-18 m.so D.S. D.S. D.S. D.S. ~se 13-13 13-15 13-16 13-33 18-7 j 4-9-84 4-9-84 4-9-84 3-17-84 1-25-84 1-25-84 1-15-84 1-15-84 12-27-83 8-11-83 4-18-84 4-29-84 4~20-84 4-20-84 4-20-84 4-21-84 4-22-84 4-28-84 4-14-84 4-14-84 4-13-84 4-13-84 4-15-84 4-16-84 4-12-84 4'13-84 4-12-84 41-5-84' 3-14-84 3-14-84 sign and Static Static Static Static PBU Common Data Base Report PBU Common Data Base Report Horner Plots w/listing Horner Plots w/listing PBU PBU PBU Common Data Base Report PBU r. Common Data Base Report PBU PBU PBU Common Data Base Report ~BU Common Data Base Report PBU Common Data Base Report Static PBU Pressure Draw-Down Static PBU Common Data Base Report Camco Camco Camco Camco GO GO Sch Sch Camco DA Camco Camco Camco DA Otis Camco Camco DA DA Camco DA DA return the attached copy as receipt of data. Kelly McFarland · ATO-1429F Chevron D&M Trans. # 187 Drilling Expo Have A' Nice Day! Mobil Mobil E & P Phi 11 i p s Services Prudhoe Bay Well Files Ext. Exploration R & D Exxon Carolyn Smith Getty Sohio Marathon State of Alaska ARCO Alaska, Inc.: Post Office B-ox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Cased Hole Finals D.S. 1-24 4-18-84 D.S. 6-23 / 4-23-84 D S. 12-28'~ 4-24-84 D.S. 13 15 '~ 4-13-84 D.S. 13-98"(Monitor Well D.S. 13-98 f 11-12-8 D.S. 13-98' 2-12-84 D.,S. 15-11/ 4-18-84 nGI #11/ 4-22-84 CFS/Spinner CH CNL CH CNL PLS 11-11-83 DIFL/GR Carbon/Oxygen Log Ca r bon/Oxyg e n/GR CFS/Diff Temp Log Collar/Per f Log (CH) Run i 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" DA Run 2 5" DA Run 3 5" DA Run 4 5" DA Run 1 5" GO Run 1 2" GO ~gn and return the attached copy Have A Nice Day.' as receipt of data. Kelly McFarland ATO-1429F Trans. # 183 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1. Mobil E & P Phillips Prudhoe g/a~_-Well Fi-le-~ Carolyn Smith -,, ~ ,:..:~~ Sohio "" :' ":"';~ .... ARCO Alaska, Inc''''''''~' Prudhoe Ba~, .~ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 29, 1984 Mr. C. V. Chatterton State of Alaska Division of Oil & Gas · 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 13-6 Permit No. 81-121 DS 13-9 Permit No. 81-158 ~iDS!i3~I5 Permit No. 82-157 DS 13-16 Permit No. 82-148 DS 13-17 Permit No. 82-26 DS 13-18 Permit No. 82-35 DS 13-19 Permit No. 81-180 DS 13-20 Permit No. 82-9 DS 13-21 Permit No. 82-53 DS 13-22 Permit No. 82-77 DS 13-23A Permit No. 82-23 DS 13-24 Permit No. 82-65 DS 13-25 Permit No. 82-91 DS 13-32 Permit No. 82-123 In 1983, several Prudhoe Bay Unit producing wells were converted to injection as part of the Flow Station 3 Injection Project. By review of our records, we have found that intent sundry notices for these conversions were submitted, but no subsequent sundry notices were filed to confirm the conversions. Attached are subsequent sundry notices which provide formal notification of the completed injection well conversions. The dates of the first injection included for each well correspond with data previously submitted in the semiannual progress reports for the Flow Station 3 Injection Project. Very truly yours, D. F. Scheve DFS/RSS/STATE/lmi cc: Sohio Petroleum Company File 100.0 RECEIVED MAR 0 1984 Oil "'' Gas Cons. ARCO Alaska, Inc. Is a Subsidiary of AliantlcRIchfleldCompeny STATE OF ALASKA .~-,, ALASK. iILAND GAS CONSERVATION (, !~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-157 3. Address 8. APINumber P.O. Box 360, Anchorage, Alaska 99510 50- 029-20831 4. Location of Well 1090' FSL, 1125' FEL, Sec. 14, T10N, R14E, UM (surf) 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM (Top Prod) 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 89' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-15 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 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 [] 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.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other ~X 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. has converted DS 13-15 to a Water-Alternating-Gas Injection well. Th date of first injection was 11/8/83. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .....,~. ~')//~__/.~~ Title Regional Engineer The space below for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir¥ Post Offic% ox 360 Anchorage. Alaska 99510 'rei~,ohc,'",,-~0.'7 ,:,, :'3.:: July 20,1983 Reference: Arco Pressure Data D.S. 1-21 7-2-83 7-2-83 D.S. 7-7A 7-3-83 'D.S. 13-15 7-1-83 D.S. 13-7 7-1-8'3 Pressure Build-up Camco Pressure Build-up Su.rvey Report Pressure Build-up Static Survey Static Survey GO Otis Otis ~se sign and return the attached copy as receipt of data. Kelly McFarl.and ATO-1429D Trans. # 432 Chevron D & M Dallas Drilling Exxon Getty -Marathon Mobil DISTRIBUTION North Geolo~ , Phillips Prudhoe Bay R& D Caroling Smith Sohio State of Alaska ARCO Alaska, Inc, Post Office Box 350 Anchorage. Alaska 99510 Teleonone ~07 277 5637 June 10, 1983 Reference: Arco Directional Data ~- D.S. 1-22~' 10-23-82 ~- D.S. 6-23 10-3-82 ~ D.S. 13-15~'~ 10-7-82 13-28 /5-25-83 /- 18-7 9-14-82 18-10 -~0-5-82 Magnetic Survey Teleco 'Magnetic Survey Teleco Magnetic Survey Teleco Teleco/DSS EW Magnetic Survey Teleco Magnetic Survey Teleco Please sign and Kelly McFarland ATO-1429D Trans. % 379 return the attached copy as receipt of data. f' DISTRIBUTION R&D DRILLING PHILLIPS MARATHON' CHEVRON GETTY D&M DALLAS ARCO Alaska, Inc. Post Office E~~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 31, 1983 Reference: Arco Pressure Survey D.S. 13-15 1-1-83 BHP Survey DA 1-1-83 Static Pressure Survey Data D.S. 13-16 1-1-83 Static Survey Otis 1-1-83 Static Pressure Survey Data ~Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-4 03 Trans. # 105 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOB I L GETTY D&M STATE OF ALASKA ~. ~ ~ ~ '..0 DALLAS ~. , ,~ -~ ., ~< ~ . . ~.,, .~ ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldC~JmD,~n .. ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage,. Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 25, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-15 DS 13-16 Permit No. 82-157 Permit No. 82-148 Enclosed are Completion Reports for work done on the above- mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/TKKW/lmi Enclosures cc: Sohio Petroleum Co. ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ' '~ ' /~'" STATE OF ALASKA ~ ALAS:, ;,,~¢.~AND GAS CONSERVATION ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well (~¥u;~ GAS [] SUSPENDED [] ABANDONED [] SERVICE I~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-157 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50- 029-20831 4. Location of well at surface 9. Unit or Lease Name 1090' FSL, 1125' FEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Unit ,,, At Top Producing Interval 10. Well Number 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM DS 13-15 At Total Depth 11. Field and Pool 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 89' RKB ADL 28315 , 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 10/4/82 10/18/82 10/26/82I N/A feet MSL 1 17. Total Depth (M D~TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey / 20. Depth where SSSV set 2i. Thickness of Permafrost 10642'MD, 9213'TVD 10597'MD,9175'TVD YES~ NO[~] ~ipple@2205feetMD 1900' approx. 22. Type Electric or Other Logs Run DIL/SP/GR, DIL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WI. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf. 78.5' 30" 350ex AS II 13-3/8" 72.0# L-80 Surf. 2581' 17~" 2700sx Fondu & 400.~x Permafrost C 9-5/8" 47.09 L-80 Surf 10209' 12¼" 500ex Cla$8 G & 50 bbls Permafrost C! 7" 29.09 L-80 9904' 10639' 8%" 335sx Class G 24. PerfOrations open to Production (MD+TVD of TOp and Bottom and 25. T'UBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Ref: BHCS 10/18/82 5~" 9947' 9R41' 10352-10382' MD 10403-10413 ' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . .. 10424-10434' MD ': DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10446-10456 ' MD N/A 8967-9054' TVD ~1 , 27. PRODUCTION TEST ... Date First prOductiOn : ' I Method of Operation (FlOwing[ gas lift, etc.) I Injection WelI - no tests available Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST pERIOD I~ - FioW'Tubing Casing Pressure CALCULATED --~ OIE-BBL GAS-MCF WATER-BBL OIL GRAVIT'Y-AP"i (c~'r) Press. 24-HOUR RATE 28. CORE DATA ,.. ..... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED . FEB-21983 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 cONTINUED ON REVERSE SIDE Submit in duplicate -,. 29. 30. 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. ~op Sadlerochit 10345 ' 8961' N/A ". ,- D/W Contact 10492 ' 9085 ' ~ase Sadlerochit Not reache ~ . i - ,' 31. LIST OF ATTACHMENTS 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- lng 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. Form 10-407 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 25, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS13-i5 DS 13-16 Permit No. 82-157 Permit No. 82-148 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc: Sohio Petroleum ! E£EI VED FEB ... 2 983 Alaska Oil & Gas Cons, ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C'O,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of Well 1090' FSL, 1125' FEL, Sec. 14, T10N, R14E, OM Bottomhole location to be submitted upon receipt of approved gyro survey. 7. Permit No. 82-157 8. APl Number 50- 029-20831 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-15 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 89' RKB I ADL 28315 12. Check Appropriate Box lo Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stimulation 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.) 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool (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 12/30/82. RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot select-fire 10443-10453' MD and 10421-10431' MD, 4 spf (20' Ref: CBL 10/21/82). Flowed some diesel to tank with low FTP. POH - all shots fired. RIH with gun #2, shot select-fire 10400-10410' MD and 10369-10379' MD, 4 spf (20' Ref: CBL 10/21/82). Flowed to tank for clean-up, monitored rate and took shakeouts. POH - all shots fired. RIH with gun #3, shot 10349-10369' MD, 4 spf (20' Ref: CBL 10/21/82), flowed to tank. POH - all shots fired. RD. Ran SSSV and secured well 1/3/83. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. gECEIVED Alaska Oil & Gas Cons. ConlmiSsior~ Anchorage Signed The space below for Commission use Title Regional Engineer 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 A~RCO AI;ska, Inc. Post Officet."_ : 360 Anchorage, ,.,aska 99510 Telephone 907 277 5637 December 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 300! Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton- Enclosed are monthly reports for'Nov'ember on these drill sites- 1-22 13-6 1-23 13-11 1-24 13-13 6-24 13-14 7-15 1C-9GI 7-16 1C-iOGI 12-19 1E-24 12-20 1E-25 WSW-6 WSW-7 WSW-8 Also enclosed are well completion reports for' 1-21 1G-4 6-23 WSW-4 13-15 WSW-5 18-10 WS.24 1F-7 ' The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including a subsequent Sundry Report for WS 24. Since the information on the WS 24 well is of a confidential nature, we would appreciate it if you could store it in a secure area. ~. Sincerely, P. A. VanDusen District Drilling Engineer PAV:JG'sm Attachments GRU1/L3 ARCO Alaska, Inc. is a subsidiary of AllanticRtchlteldCompany STATE OF ALASKA 0 RIG IN A L ALASI~" . ,_AND GAS CONSERVATION( ,vlISSION WELL COMI LETION OR RECOMI:I'LETION RE ORT AND LOO 1. Status of Well Classification of Service Well OIL¥~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-157 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20831 4. Location of well at surface LOCATIONS 9. Unit or Lease Name 1090' FSL, 1125' FEL, Sec 14, T10N, R14E, UN VE.~IFIED Prudhoe Bay Unit At Top Producing Interval Surt:. ~- 10. Well Number 316' FSL, 75' FWL, Sec. 14, T10N, R14E, UM ~,H, ~ 13-15 . ,., ,, At Total Depth 11. Field and Pool 347' FSL, 78' FEL, Sec. 15, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 89' RKBI ADL 28315 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore I16. No. of Completions 1 0/04/82 10/18/82 10/26/82 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set ] 21.Thickness of Permafrost 10642'ND,9213'TVD 10597'MD,9175'TVD YES ~ NO [] nipple 8 2205 feet MD 1900' (approx) 2';2. Type Electric or Other Logs Run D IL/SP/GR, D I L/BHCS/GR/SP, LDT/CNL/GR/Cal , CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD ,,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20" 91.5# H-40 Surf 78.5' 30" 350 sx AS II 13-3/8" 72.0# L-80 Surf 2581' 17-1/2" 2700 sx Fondu & 400 sx Permafrost C 9-5/8" 47.0# L-80 Surf 10209' 12-1/4" 500 sx Class G & 50 bbls Permafrost C 7" 29.0# L-80 9904' 10639' 8-1/2" 335 sx Class G 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) None 5-1/2" 9947 ' 9841 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A ..... 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRQDUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO . TEST PERIOD I~ : Flow Tubing Casing Pressure CALCULATED. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. ' 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water, Submit core chips.None ~C~! Y~D ~l/aska Oit ,~ ~as. co~s , Form 10-407 Submit in duplicate Rev. 7-1-80 GRU2/WC28 CONTINUED ON REVERSE SIDE 29. 30. 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 10345' 8961' N/A 0/W Contact 10492 ' 9085 ' Base Sad]erochit Not Reache~ 31. LIST OF ATTACHMENTS Drilling Hist__ory~ Gyroscopic Surve), (2 copies) 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 andin 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 DS 13-15 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1700 hrs, 10/04/82. Drld 17-1/2" hole to 2603'. Ran 64 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2581'. Cmtd 13-3/8" csg w/2700 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10215'. Run DIL/SP/GR f/10,212'-7700'. Cont drlg to 10,219'. Ran 245 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 10209'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8"packoff & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10626'. Rap DIL/BHCS/GR/SP,, f/10620'-10207'and LDT/CNL/GR/Cal f/10620'-10202'. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 50 bbls. Permafrost C & 130 bbls Arctic Pack. Cont drlg 8-1/2" hole to 10,642' TD (10/18/82). Ran 18 jts 7" 29#/ft, L-80, BTC csg f/9904'-10639'. Cmtd 7" lnr w/335 sx Class G. Drld cmt to 10,597' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL/VDL/GR/CCL. Ran 5-1/2" completion assy w/tail @ 9947' & pkr @ 9841'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Nipple for SSSV @ 2205'. Secured well & released rig @ 1200 hrs, 10/22/82. Gyroscopic survey ran 10/26/82. jG:sm 11/04/82 GRU2/DH18 DEC ,i 5 t982 Alaska Oil & ~as C~ns. C°mmls~iot, /'tnChorage , T L EO Teleco Oilfield Services Inc. 220 A Center Court Anchorage, Alaska 99502 October 27, 1982 JOHN RALL DS #13, WELL #15 ROWAN 41 Dear John, Attached please find a copy. of the computer calculated survey for the above mentioned well. On behalf of Teleco, I would like to thank you for the opportunity to serve you. We at Teleco realize the importance of good service and hope that you will continue to use our MWD services in the future. Please feel free [o contact me if you have any questions. Enclosures SB-ck Sincerely, .~.x. ? ~.,.~. . ~ .-'" Steve Billeaud Field Service Supervisor T L EO Teleco Oilfield Services Inc. 220 A Center Court Anchorage, Alaska 99502 Job #172AK ARCO D.S. 13 #15 ROWAN 41 FSE A1Kavaliauskas Starting date 10-6-82. Tools used 263-26, 271-21, S.G. 182 Proposed direction S75°18'W. Inc. 38°34'. From 7:30 on 10-7 to 0800 on 10-8 1698' were drilled. Jetting kick-off, from 2800'. Casing shoe set at 2581'. Starting direction was a S to E, with 1° of drift angle Ending direction was S74.8°W, with 35.5° . of inclination. From 0800 on 10-8 to 0800 on 10-9, 1128' were drilled. Starting direction was a254.8 to a 262.6. Inclination went from a 35.5to 37.4. From 0800 on 10-9 to 0800 on 10-10 693' were drilled. A 100' correction 2° run was made with a dyna-drill 500 and a bent sub. Estimated turn was between 7° and 8°. Direction went from 262.6 to a 255.9. Showing desired turn from dyna-drill. Inclination went from 37.4° to 40.O°. Tool 263-26 @ 6297 42.7 255.9° SS @ 6275 42 o 257° From 0800 on 10-10 to 0800 on 10-11 1OOO' were drilled. Direction went from 255.9 to 255.9. Inclination from ~O° to 42.5°. From 0800 on 10-11 to 0800 on 10-12, 750' were drilled. Tool 263-26 would not pulse under any flow rates attainable, 425 to 525 gallons/minute. S.S. on dull bit was a 41.2 @ $76W, 7607'. Picked up tool 271-21 @ 0600 on 10-12. From 0800 on lO-12to 0800 on 10-13, 850' were drilled. S.S. direction of S76W at'41.2° . Inc. went to 260.8~ 35.9° inc. Tool 263-26 @ 5955' 40° @ 256.2° Tool 271-21 @ 5955' 40.1° @ 256.9° Co-man and direction driller satisfied with tool comparisons. S.S. and tool checks have been with-in 1°. From 0800 on 10-13 to 0800 on 10-14, 900' were drilled. Inclination went from 35.9 to 35.2. Direction went from 260.8 to 269.9. Job #172AK cont. From 0800 on 10-14 to 0800 on 10-15, 615' were drilled. Inclination from 35.2 to 33.3. Directionfrom 269.9 to 278.9. S.S. @ 9636 35.5 @ 274.5° Tool 271-21 9671 35.6 273.8 Tool 271-21 35.6 @ 273.4 Tool 271-21 35.7 @ 272.7 Tool 271-21 35.7 @ 272.7 Tool not repeating two days in a row, but it was 08:30 on both days. Possible interference. Check for storms. Total depth 10,215', circulate tripped out of hole and lay 271-21 down. DIREGTIONAL SURVEY REPORT ¢ PAGE t CUSTOMER 8 ARCO LOCATION 8 PRUDHOE BAY, ALASKA WELL PAD t Dii-15 WELL NO. t DRILL[NO CO. ~ RO14AN CUSTOMER JOB NO. ~ TELECO JOB NO. J 172-RK RIG NO. I 41 TELECQ OILFIELD IIERVICEII OF ALASKA, INC. 228 CENTER CT., ANCHORAGE, ALASKA, 99582 TEL ~ (987) 279-8651 DATA REDUCED BY RADIUII OF CURVATURE METHOD TYPE OF SURVEY 8 MAGNETIC MAGNETIC DECLINATION a 58.58 E PLANE OF PROPOSED DIREC[ION I8 t 75.18 IITART DATE 8 18/87/82 FINIIIH DATE I 18/i5/82 REPORT PREPARED BY t AL KAVALIAUIIKAII MEASURED DRIFT TRUE DEPTH ANGLE VERTICAL DEO MIN DEPTH 2854 5.24 2892.79 2988 6.56 2986.45 5058 8,88 5847.95 5205 11.86 5288,78 5518 12.54 5311,51 5409 14.12 5599.78 5504 1G. 42 5491,55 5~96 19,12 5578.87 5782 25.88 3752.58 5875 25.18 5857.56 5969 28,42 5921.12 &8~2 51,42 4827,42 4216 55,38 4138.78 &58~ 56,2& &~28.~1 &~54 56.48 4725,~5 5526 57,24 5822.56 55~5 56,42 519~.5~ 57~1 58.&8 55~7.92 5~55 48.88 5517.85 6297 42.42 5774.5E 656~ 45.12 5969.99 7681 ~1.12 ~757.58 VERTICAL IIECTION 18.15 25.85 31.72 ~9.45 88.51 189.79. 1E5.28 195.48 229.72 267.71 518.58 $72.84 448.63 658.66 876,83 1899.92 1258,29 1565.74' 1486.87 1712.79 2187.78 2592.05 DRIFT DIRECTION DEGREE8 8 78 E 8 87 W 8 78 W ii 72 W ii 71 W ii 71 W ii 72 W S 72 W S 71 W 8 72 W ii 75 W 8 77 W S 85 W ii 76 W ii 76 W S 76 W ii 76 W ii 76 W B 76 W ii 76 W TOTAL 7.55 ~ 19.£~ 8 19.58 N 28.85 8, 23.85 ii 29.93 76.87 87.83 181.57 121.~ 1a8.49 192.76 236.74 269.98 295.73 526.82 418.47 454.48 E25,28 COORDINATEII 28.75 E 18. B7 W 9.8ii W 2.{{2 W 23,41 W 46. it 1 66.33 98.26 116.98 l&7. ~6 179.97 216.16 256.6.] 381.1~ 886.98 1828.93 1157.39 128E. 88 1486.36 1625.68 1882.12 2886. ~2 2478. E~ CLOSURES D 1 STANCE ANGLE DD MM Sii 8.88 26.69 ii 12 36 48 W 21.86 N 26 51 55 W 28.15 8 5 45 81 W 35.42 8 44 28 18 W 54.97 8 57 88 58 W 75.88 8 61 82 45 W 188.82 ii E5 ~1 58 W 129.81 8 ~5 85 37 W 161.12 ii EE 88 48 W 195.39 8 67 85 15 W 233.32 S 67 55 16 W 275.92 $ 68 26 46 W 537.7~ S 69 88 19 W ~8E. 17 ii 69 ~5 58 W E21.SB S 71 55 42 W 1527.54 8 75 4~ 81 W 1458. E8 S 75 48 87 W 1676.62 S 75 49 43 W ;858.54 S 75 58 44 W 2555.97 S 75 55 15 W DOG - LEG SEVERITY DEG/188 FT. 1,867 5.476 2.295 2.152 1.956 1.452 2.632 2.758 1.845 2.518 2, 475 5, 6549 2. 475 5.545 8.512 8.619 8. 789 8. 187 8. 162 8.215 DIRECTIONRL DR ILI._ I NO SURVEY REPORT PAGE 2 JOB HUMBER I 172-AK CUSTOMER a ARCO PAD ~ DS-15 WELL NO. ~ 15 ~ MEASURED DRIFT TRUE VERTICAL DRIFT TOTAL COORDINATE8 C L 0 8 U R E 8 DOG - LEG DEPTH ANGLE VERTICAL SECTION ~IRECTION DISTANCE ANGLE SEVERITY DEG MIN DEPTH DEGREE8 DD MM SS D80/188 FT. 7918 37.~8 ' 6975.81 2788.58 S 76 W 678.75 S 2689.5& W 2752.52 B 75 53 44 W 1.188 8065 36.38 7899.35 2882.16 8 77 W 692.68 S 2768.56 W 2846.12 S 75 54 56 W 8.925 8285 35.38 7277.34 3811.37 8 78 W 728.59 8 2886.88 W 2975.38 8 75 59 84 W 8.527 8872 55.12 775~.61 3351.66 8 82 W 778.86 8 3223.68 W 3316.17 8 76 25 49 W 8.421 9057 34.38 7988.43 3456.26 8 85 W 798.83 8 3328.64 W 3~21.11 8 76 38 53 W 1.081 9289 54.24 8831.77 35~8.72 8 87 W 796.83 5 3414.~1 W 3585.98 B 76 52 35 W 8.747 9363 3~.88 8158.51 3628.~1 8 89 W 799.89 $ 3582.1t~W 3592.15 $ 77 88 ~8 W 8.869 9517 55.12 828~.23 3712.22 8 98 W 799.87 ~ 3598.88 W 5678.81 8 77 28 51 W 8.379 g~78 35.~2 8533.92 37&S. 34 N 88 W 799.56 N 5628. i18 W 3715.28 N 77 3~ 55 W 1.255 9S71 ~5.42 8489.~4 3798.29 N 87 W 797.~S N 3~88.i~1W 37£5.86 N 77 &S 16 W 1.255 9928 35.88 8618.93 3938.78 N 84 W 785.~8 N 3828.1~3 W 3988.~7 N 78 2~ 58 W 8.715 18129 33.18 878~.17 &842.91 N 88 W 778.26 N 3~48.,71W 4815.28 N 78 58 24 W 1.432 BOTTOM HOLE CLOSUREa ~815.28 FEET AT N 78 58 24 W 1 PREPARED BY ABACUS COMPUTER SERVICE 828 W. 718T. AVE~ ANCHORAGE. ALASKA ! (987) 344-87~1 ENTIRE CONTENTS COPYRIGHT 1982 ABACUS COMPUTER 8ERVI~E ARCO ALASKA INE:, DS 13~ WELL NO: 1.5, GMS dOB NO: AlO82RO325~..yG PRUDHOE BAY, NORTH SLOPE, ALASKA DATE RUN: 26-0CT-82 GMS 0--105°.-7,'5 MD '-E:URVEYOR: MILLER/ClONES GYRO NO: 626, CAMERA NO: 1507, 5-90 DEG A/U NO: 14._.'-. FORESIGHT: N!6 44W :3URVEY TAKEN FROM WELLHEAD VEF;,'T I CAI_ '.Ei;ECT I ON C:ALCULA~ED;~,~I N F'Lt ~il ~'ill ~D I R E C T I 0 N: RECOR1'~ OF SuRvEY R A D I I.J S O F C U R V A"I-U R F 1'-1E T H 0 D ARCO ALA'.E;KA INC,, D'.:::_1:7.::. WELL NO: 1 ._, -'= GM PRUDHOE BAY-. NORTH SLOPE, ALA'.-]:KA DATE RUN: 2/:.-0CT-:::2 COMF'UTA]' I ~"'~h.! T I PIE DATE 1 o ,-. :.54 ' 2' 0 2/I .... N A V- E: 2 'TRUE MEA:---:URED DRIF:T DRIFT COURSE VERTICAL VERTICAL SUB'._;EA R E C T A N G U L A R C L 0 S U R E DOGLEG DEP]-H ANGLE DIRECTIOhl LENG]'H DEPTH SECTION TVD C ~-~ ~-~ R D I N A T E '.7.; DISTANC:E DIF::~EC'TION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D N r,3,/10C)F'f O. 0 0 0 0 O. 0.00 O. 00 -89. O0 0,, O0 0.00 O. 00 () 0 0.00 ! 00. 0 0 C) 0 100. 100.00 0.00 I 1.00 O. 00 0.00 0.00 '.'} 0 0 ,. ':])'::) 2300. 0 0 0 0 2200. 2300. O0 O. O0 2211 · 00 0. O0 O. 00 0,, 00 0 ,:"~ O. O0 ';:'400. 0 15 '.-]; 83 0 E 100. 2400.00 -0.20 2:311 ,. 00 0.0:3 '._=; O. 22 E-" 0.22 S r:::.7, 0 E:' 0.25 '-';/500. 1 :'::0N /:,9 0 E lO0. 2497.'P9 -1.70 2410.99 0. 1/:, N 1.72 E 1.7'2 N 8,.'1. ,q. 5E 1.2:-} 2/:,00. 1. 0 N 57 0 E 100. 2599.96 -3.r.-:::':-: 2510.96 1.15 N 3./:,/:, E.] 2700. ! 0 N 47 0 E 100. 2699.95 -5.43 2610,95 2.2:.3 N 5.03 E 2800. 1:7.',0 N 55 0 W 100. 27'.:;".::,'. 92 -5.78 2710.92 4. 12 N 4. '.-7.,'0 E 2'P00. 4- ,4.!5 N 89 0 W 1 O0. 28'P'.-.-,'. '76 - 1.26 2810. 76 115.78 N 0.21 W :'::C) C)('). 8 ¢) L:; ':'° ':.') W ! 00, '::2999. 13 :.:.:1(')0. 1(') 15 S 84 0 W 1 :32. 00. !1 5:(') S :'::1 0 W 1 :3:'::0 C). 14- (') F; 7 :"'1 0 W :34. 00. 14- 1 .=.ii '.E; 7:':: (") W 1 ! :3!500. 1,_,/- 45 ,.5; '71 c). W 1 C)('). :5 /-'::' N 11:31 W .1:7.: W 83 W .4-1 W .8/:. W .28 W 2_'~)', 51 N 80 25 4. 5,::-::8 N 87 22 W 67.4!:'5 ti:: 07 54 W 91.:3:3 '.B 84 1:3 W 117.58 S 81 2:3 W 14:'-:: :31 c- 7 o --:,-:, 14 182.::::9 S '7'7 59 W 2'7-,~ 1. C) 4 S 77 7 0, 56 (1). 1 '7 1.9'7 :7.:, 61 ':' 27 · ~, u ~. ""' :'-':'.'1. ,, ..2' / '":' ::':::ii: .l:,.. c), 2:.'. 56 q- 10,:}. :2:':.2 1 !5 S 74 0 W 100. 4(.')32.27 3/:,2.37 3943,, :27 4 2 c) O, :':: 5 15 '.:; 7'7 0 W 100, 4115,41 417. '.:;' 1 4. 026, 41 4. :7.: C)(), :2:6 4 !.:]i; S 77 0 W ! (')0. 4196. :31 4. 76, 66 4107, :2:1 44.00~ :2:6 :.30 :.7.; 77 0 W 10C). 4276,5,"_-. 5:"::/:,,:30 41L:7.5/:, ./I. 500 .....:2:7 C) S 78 o t') 100 4 "'" "='.:,.:, 6 ....../-, 9 S'-7,'/-,, 08 4 '-'/,. :,-7,/:,'? :5:'7, "= :35 ,, 6'7 · _, 1 S 1 W 1 (') i. 4. 2 '.:.'; 4. O."fi, ,,-t. 5 W 114..64 S 4./:,2.72 W 12:::: 0../:. '.E; ~'::'C) '-'"= W 141, (} 1 ~::: 5'75:', :2/:. W /.I. 6OO,. 3/:, 15 F; 78 0 W 47'":)'::), 36 · ':-- · 4...,7::: (') W 48,:.')0, ,_,_'::/-. ]..~5_ '.'.-i; -;' :::, _ (').. W 49 C) C). :7:/.-:, :7(:) ::_'-; '7'? (:) W 5 c) 00 :36' 4."":; S ! 0 W t. 0(). 44:36, 95 6."";."-";, 6:::4:::47,9.'.-'5 1 .""";:::, 4 1 S /:,37,/:,2 W /:,.55,8 :t :iii; 7/:. 28 W 10(),, 4.5.:'; .1. 7.._,.:,-:,._, ' 71 .'5.5, C)'i..':,.. 4428 . :5:>._, ._, 1/': .... '= .' -7:5- :~-: A':'"'-'_ ,.._. ::h (:). W. "71 ...,"::' . :2 F: '.:.'-': '7./-,_ ._,,..,"::' ,- I.,...I 100, 4. 5'F..' 7,72 774,51 4- 5 (') 8.72 178, 15 S 75 :'::, 98 W 774,. 7 '..1- S 7 6 45:t,4 1 (') () 4,5. 78 ":' ":' ':' ":' ":' '72 , ':5 ,:,,:;. .. :::: :':: 4- 7/-, . . .- .............. ..I ........ 23 1 ::::9 ,. 5:'7 ..Z: :E: I 2' 10 W .02 :L:: _ ] o(.-~ ..... ~.7=ic:,' 4,:'/ qo..:, 1 ':: 2[/-'/-,0 41'-.",' :':.!; i:'i ¢) -'::':':.: ;:: :::7% ,',,:=-.: .... W :::: c:, --::.. .i ..... 5:i9 ::_': 7'7 3 f') %:, - & ! 0.5() 0, 50 0./:,4. I '#:" F'RUDHF'IE B-(')Y, hlFq.R'r'H '.E:I_OF'E :, ALAC-;KA ,_lOB NO: AlO:E:2R0:325-YG DATE RUN: 26-OCT-F-:2 C r:lMF'lJ T A'T' I r'jhi -f'I ME DATE 10: .':.5,ti-: 20 24 ..... I',.!0 V--- :":', 2 F:',A G E h. lr 'j: ;2: TRUE MEASURED DRIFT DRIFT C£1URL=:E VERTICAL VERTICAL '.":;UBSEA R E C T A N G U L A R C: L 0 S U R E 'r'u3GLEG DEF'TH AI:IGLE DIREC'I'IOr,! LEr',IG"rH DEPTH SECTION 'rv[i c.' o El R D I N A T E S DISTAI',ICE DIF:ECTION :::;EVERI"I'Y FEET D M D M FEET FEET FEET FEET FEET FEET D I'fi DG/100FT '=;100. :37 0 '.2; ':'":' 0 W 1('DO 4.83::2_-': 48 ,:)5.:,.o-:, 4749 48 209.20 ,:, 9:::(] 19 W ':' .... ' ...... = ................... '-' . _ _. ;..~.:.. 43 '.B '77 20 W 5200. 36 15 S 81 O'W 100. 4.91:E:.74 1012.14 4-829.74 218.02 S 'P89.20 14 ].01-2 94 'S 77 34- W N:qC}O :q/-, ~ = . . . . 4910 '-' 2'26 S 47 W ....... 4 .... S 82 0 W 10C) 4999 12 1071 28 . 1= .81 S 1048.03 W 1072.29 77 %40c) 37 15 S ':'1 0 14 100. =;c e, . 4989.99 ]~::::5.70 ':' .55 . ?= ..... ,_, . ._ .17,:,. 99 1131 10 "- ~, 1107 14 1132 .- .... S 77 59 W 5500. :37 45 S 75 (]. 14 100 ._~lSfq_ _.._,°""= 1191 :=:';*_. 50'69'32 248:2:5_ ''='._.1167 ()/*_ _ W 11°'::....... ....... 20 S 77 ~:;9 W . ._ ....:,7 ':-:9 1 11 5148.39 264.20 S 122/:,. 20 W :1. 254. :2:.'-.'1 '.:!; '7"7 50 14 5600,. :2:7 4. 5 '.2; 75 0 W 100 .=';'-"-' .... 25:2:,, . 7._, 0 W l oo .=,:2:1 .~ 92 1:2:1 S 01 ._ ,~e.~ G1" IT! ~'~' 2::[{'} .l 2'2~' S; 1 "::":'/: P('! I,,.I 1:31../..-, 1 :F-: '::' '77 o..'::, W !?:; ::: O CD . 3'.:.?15 '.-E; 75 0 W 'I. OCD. 539:3.64 1.'2:77.94. 5304.64 '7.-7.--;6.:.'-'.;1 '.?.; 1.34.,./:.,.7'F,' 1.4 :1.:7.:7'F'. 0:!.'.E: 7'7:35 t;..l !590 o.. 40 0 S '7':::;._ o_ W l o_ 0. 5470.66 1441 .7 :.2 ...... '=";":' '='_, 1.66 :L:: 1:2: ........ 0:2.' S 1408 :":':'::;' 1,4 144- 2 '7:5 '.2; 77 28 W /:i. OeD'O,"41 e-~ S "-'; '' ~"='" "=' .=;,' = '"c~ .-,,-,o ,-,.-, ,=. ' ,.::-.---., 7o 0 14 1- 00. ._,._,4e,, 70 1.-,0/--,, 66 ._ 4o7, 7. .:,-..-.. ,:,.: ....147:1.: 12 W 1 ._,0/,/:,.0,. '.E; 77 22 W /_-, 1 o O. ..41. ('D :2:() ?':; 7:2: 0 W 1 6200. 4-:1. 4.5 S 75 () W 1 /-,:-..:()0, ,.'.1.::? .:,L '.:; / :5 0 la i 64.() ('D. 42 Z[ f'-:'; :iii; 75 0 14 1 /::,!5,::i0, 45:1 !5 Si; 7.b; 0 W :1. 0 O, (-) o/. . · ... :2: /-':; (). O0 1. O. 50 (}. 7!:i:.; ].., 0() /-,/-,(])CD ....... 4:2': 0 S 75 0 W 1-00, 59'F; 1.65 19C)'F;, L'r-'z. 559c)'2 ,65 ... ,,:= /.:, 5'2 . ..... _, ,.'1.4 &7e)(). zl.:2.'.1'..il:~]~ l'' ' t '1' (]} i4 1 ¢:;) (]), /:, (? /:., zl. '" 04 1'P'77, ()6 r:'."; 9 '7 !5 , 94 4 .... -,,. 79 ':"I1 '724, '.:::,:2.: 14 i'P77,, ./':;t:3 S ';'/. ,:.':. :.=.: C) CD . 42. 15 S 7.'5 0 W 1()o. /-.1:38.67 2044./:.,2 ./:.049.67 471.2'7 S .1.990. 17 14 2,:)Zl..5,,2:i. S 69 o (). 4. 2:30 '.2; ''?':''' 0 14 1 o O. /- '-'::' 12. !54.211 '--' 02 61 '.';' I::, ':::, 4 4. 88 ...... ' .... ','.'"'i = :::J.'; :37 , ..................... ; .,::. 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W 4176.9' 7 :!:;; 7 ':.;.' 2 ::"": ~,.; ,:1-2(')2,, 67 :":']: 79':32 t,'.! ~~ l Eastman t ', Whipstock 1)) A PETROLANE COMFY REPORT of SUB-SURFACE DIREC TI ONA L SURVEY ARCO ALASKA, INC. COMPANY DS 13r Well Number: 15 WELL NAME ?rudhQe Bay, North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY Directional Single Shot ~ --. ~ ~ATE DEC 0 7 ;1982 SURVEY BY American Directional Drilling OFFICE (G. Thibodeaux) ARCCI ALASI<A~ INC. DS i:B~ WELl_ NO. 15 D._,.:, (AMERICAN DIRECTIONAl_ DRILLING) DSS~ 0-.10626 MB~ DRILLER: C~ THIBOBEALIX ..........................................................................................................................................SLIRVEY F'ROVIBEB BY AMERICAN £1IREC. rILNAI_ ARCO ALA'.==;KA INC: COMPI rI"AT iON PAGE NO, 1 DS 1:2:, WELL NO: 1.ti DSS (AMER I;-:Ai',i DIRECT I ONAL DR ILL INR) T I ME DATE PRU1]FIOE BAY., NORTH '-'.:,LC'~'"F E, ALASKA 15: ":"=,../: 4-2 22-NOV-:E:2 TRUE MEA".=;LIREI] DRIFT. DRIFT L. 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FINAL CLOL:;URE ..- D I RECTI ON: D I STANCE: 4.:._,7 · 0(:, FEET A/-')fi: rRol ANL' (.'.;(),VI~' .~INY D'.=; 13, WELL NO: 15 I.;=,.=, (AMERICAN DIRECTIONAL DRILLING) PRUDHOE BAy, NORTH .=,I_JFE, AI_ASKA SLIRVEY FILE: NUMBER 1437 BOTTOM HOLE A~,;=,EM£LY ...................................................................................................VALJE.:,! ............ '_"_' U'.=;ED FOR DEPTH ARE I"111 ..) DEI":'TH D E.:-.,I_.R I PT I ON 4279. ('>0 LOF:KED ASSEMB~ / ~, ,-, . A PE'IROLANE C'~ ~M/:~4/'iY =,.:,7,=,. 00 LOCKED ASSEMBLY 7917. O0 LOCKED ~S".3E~BLY 97:37'. O0 LOCKED ~SSENBLY DRILLING DAYS VALUES USF~ FOR DEPTH ARE MD [,AY DEPTH 1 '13'F~5.00 · ~ o "-' ')¢ ~ o. 544'F~. O0 B . 6 6024. O0 7 7076.00 8 7917.00 . 10 "75 41.0 () ) · · · WEIGHT ON BIT WEIGHT IS GIVEN PER 1000 POUND.C_: VALUE:=: IJSliED FOR DEF'TH ARE MD I]EPTH WE I GHT 125.00 75. O0 2603. O0 65. O0 ......... Zl.279-::"O~rj,' ................................................. 7i:i'ZO 5449. O0 .0. 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' ---4:. ; ~," _s]'.~;~.~ .H_T: ~ O.EE. I ~" I · · ;..: -'.'/'l .ASSEMBb¥-S---,.'h ' | -'' '--:: i I '. · . [ ." ' . I ' ' .~..-..: ! ..... .,,.-. ~. FiT----jF-TT-TN~--~;SSE~BEyr-7,. ~ .,,..,,, ,, -~ ,' ' ,' . '' I' ~: ..,~.''' [ --~-~-:-~I: ~,--uoo..~,~^ss~.u~--! + ...... ~.--~,~1' ~~~'.~'---~! ;' ' I , ' ' ! --'--~ .... ~- -- ,,~?-t--r--.~ ....... i--" "--t-----------I--'"---- t--'-'---"--"l ' ' Suggested form to be inserfed in 'each "Active" well folder to d~eck for timely compliance with our regulations. '' O'pe. rator Reports and Materials to be received by: I /'Q,°Q'5- 'Date ,.Required Date Received Remarks .. Ccmpletion Report Yes' / . Well .History Yes -. _Samples, , ,~ -- p l ~- , ,, . ~ . · , ,. . ~ ,.. core Descripti°n _ Registered Survey Plat Ve,._~ ?"~1 ~ ! . Inclination Survey ~/~ s , , , , Directional Survey Drill Stun Test Reports .4/?; X/~---- Prod~ctidn Test Reports .-~/. Digitized Data y~5 I STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX ARCO Alaska, Inc. Prudhoe Bay ~,ineering Post Office B~. J60 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations. Engineer November 22, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupi.ne Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D~S. 13-6 Permit No. 81-121 D.S. 13-9 Permit No. 81-158 D.S. 13-15 Permit No. 82-157 D.S. 13-16 Permit No. 82-148 D.S. 13-19 Permit No. 81-180 D.S. 13-21 Permit No. 82-53 D.S. 13-22 Permit No. 82-77 D.S. 13-23A Permit No. 82-23 D.S. 13-24 Permit No. 82-65 D.S. 13-25 Permit No. 82-91 D.S. 13-32 Permit No. 82-123 Attached are "Notice of Intention" Sundry Notices work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc: Sohio Petroleum RECEIVEo DEC 0 8 1 82 /tlaska Oil & Gas , ,' _ Cons. Ccmn~i$$ioa /~chorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA "-"~ ALASKA L,,- AND GAS CONSERVATION COw, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E]XX OTHER [] 7. Permit No. 2. Na,~0O,~rf~O~ka, Inc. 82-157 3'Ad~rest~ .... BOX 360, Anchorage, Alaska 99510 8. AP~Number50_ 029-20831 4'L°c~)(~no°~fW~g, 1125' FEE, Sec. 14, TiON, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 89' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-15 11, Field and Pool Prudhoe Bay Field 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 [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~X 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 2© AAC 25.105-170). ARCO Alaska, Inc. proposes to convert this well to Water-Alternating-Gas Injection service. Injection will be into the Sadlerochit; surface piping and instrumentation have been installed as necessary for injection. A downhole safety valve will remain in service in this well following the initiation of injection. A non-freezing fluid was left in all uncemented annuli within the permafrost interval. 14. I hereby~rtify that the foregoing is true and correct to;the best of my knowledge. Signed~.~.'~~~t~_~:;)~ Title Regional The space below for Commission use Engineer Date Conditions of Approval, if any: ORiG'HAL SIGHED BY I~'~ W. KUGLER Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Anchorage. Alaska 99510 Telephone~''~ 277 5637 December 3, 1982 RE: ARCO Directional Surveys /~D.S. 1-21 10-22-82 Single Shot · ~D[.S. 6-24 10-22-82 Single Shot fD.S. 7-15 10-28-82 Single Shot ~-~D. S. 12-4A 11-15-82 Si ngl e Shot -D.S. 12-7A 11-15-82 Single Shot ~-.S. 12-8B 11-15-82 Single Shot fD.S. 12-14'-11-15-82 Single Shot -'D.S. 13-14 11-15-82 Single Shot fD.S, 13-15 11-22-82 Single Shot -J).S. 13-16 11-15-82 Single Shot ~D,.s. 13-17 11-15-82 Single Shot ~'D.S. 13-18 11-15-82 Single Shot ~D.S. 13-23 11-15-82 Single Shot ~q~.S. 13-23A 11-22-82 Single Shot /D.,S. 13-24 11-15-82 Single Shot ~D.S. 13-25 11-15-82 Single Shot 11-15-82 Single Shot 11-15-82 Single 11-15-82 Single Shot 11-15-82 Single Shot and return the attached ~.S. 13-26 ~D.S. 13~30 ~q) S./~3-32 ~4~. 13-34 ,..~Please sign copy as of data. rece i pt E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W BeCky Benedi ct AFA- 403 Trans. #638 NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION ~. ~.t ~i/~_'' ' - GEl-FY N~sk~ 0i~ ~ G~S Co~s. Commission D&M STATE OF ALASKA DALLAS ARCO Ala&l~. Int.. is a Sub~i~lia~f of AtlanticRichfleldCompany ARCO Alaska, Inc. Post Office B .{60 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1982 RE' ARCO Cased Hole Finals D.S. 1-8 '~' 1.0-24-82 CH .CNL D.S. 1-22~ 11-6-82 CBL/VD o D.S. 4- l'~ 10-30-82 CH ~CNL D'.S. 5-7'~. _ 10-26/5-14/10-22-82 CNL Gas Monitor Log D.S. 5-7~ 10-22/5-14-82 'CNL Gas Monitor Log D.S. 5-7~ 10-22-82 D.S 5-14J 10-30-82 D.S. 5-12~--~ .10-23-82 D.S. 6-23 f 10-21-82 D.S. 6-24~' 11-4-82 D.S. 13-5f 8-20/11-1-82 .~ i(~--/~ D.S. 13-15" 10-21-82 D.S. 1~-'~ 10-3-82 ' i(:/~~b''~'- ~;-S-.--t-6--~3--) 7-22-82 /'~'--?. J -~ D.SC 18~10 ~ 10-21-82 Run 5 SCH Run 1 SCH Run 6 SCH Run 3, 10, & 11 SCH -Run l0 & l l SCH CH CNL RUn ll SCH CH CNL Run 3 SCH CH CNL Run 7 SCH ACBL Run 1 D/A CBL/VD Run 1 SCH CH CNL (CNL Monitor Overlay) Run 1 & 2 SCH CBL/VD Run 1 SCH ACBL Run 1 D/A Spinner Camco ACBL Run 1 D/A Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Trans. #625 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON · CHEVRON EXXON MOBIL GETTY D&M STATE OF ALAS DALLAS ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 22, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re' D.S. 13-15 D.S. 13-16 D.S. 13-32 Permit No. 82-157 Permit No. 81-148 Permit No. 82-123 Attached are "Notice of Intention" Sundry Notices work proposed on the above-mentioned wel 1 s. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc' Sohio Petroleum Oil & Gas GoDs. Gommissio~ ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ~ ALASKA [..~ AND GAS CONSERVATION C( MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] 2. Na~(~p~r~O~ka, Inc. COMPLETED WELL [~(X 7. Permit No. OTHER [] 3. Ad~r:s~). BOX 360, Anchorage, Alaska 99510 4'e°c~)~"o°'fWl~L, 1125' FEL, Sec. 14, TIOB, R14E, UN Bottom hole location to be submitted upon receipt of approved g.vro survey. 5. Elevation in feet (indicate KB, DF, etc.) RKB 89' 12. 6. Lease Designation and Serial No. ADL 28315 82-157 8. APl Number s0- 029-20831 9. Unit or Lease Name Prudh0e Bay Unit .l~O~--Well" Ndm'ber- D.S. 13-15 Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~X Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation 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.) 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 perforate selected intervals within the Sadlerochit Sand in this Prudhoe Bay Unit well. Upon perforating, the well will be flowed to a tank for clean-up and evaluation. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals' 10352.=10382' MD 10403-10413' MD 10424-10434' MD 1 0446-10456' MD Ref' BHCS 10/18/82 RECEIVED NOV 2 ]982 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby c~ea[tify that the fj;~egoing_[s true and correct to the best of my knowledge. Signed ,- ._ , _., .... _ Title Regional The space below for Commission use Engineer Date Approved Conditions of Approval, if any: ORIGiHA[ SIGNED Approved by BY L0~t{IE IL SglTlt COMMISSIONER By Order of the Commission Returned .... Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~' 360 Anchorage,~,_~ka 99510 Telephone 907 277 5637 November 16, 1982 RE: ARCO Magnetic Tapes with Listings D.S. 14-7 10-27-82 D.S. 14-26 12-30-81 *D.S. 13-24 5-17-82 *D.S. 6-17 7'1-82 · CNL (10570- 11600) Tape #ECC 1505 CN-GR, CDL, DIFL, BHC/AC Tape #ECC 1191 D.S. 13-14 11-5-82 Open Hole Logs Run'l & 2 Tape # 66023 ~ Open Hole Logs Run 1 Tape #65124 (Corrected) DIL/BHC/FDC-CNL/CH CNL/GR · Tape #65256 (Corrected)Run 1 D.S. 13-15' 10-18-82 Open Hole Logs Run 1 & 2 Tape #65747 Open H°le Logs Run 1 Tape #66017 D.S. 6-24 10-31-82 D/A D/A SCH SCH SCH SCH SCH * Please see attached letters regarding the replacement tapes for wells 13-24 and 6-17. .]~lease sign and return the attached copy as receipt of data. Becky Benedict AFA .- 4O3 Trans. #623 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE ARCO Alaska, Inc. Post Office B"'~360 Anchorage. ,k .,ka 99510 Telephone 907 277 5637 November 15, 1982 RE' ARCO Open Hole Finals D.S. 13,15 10-18-82 BHCS - GR SCH 2" & 5" 10-15/18-82 DIL - SFL SCH 2" & 5" 10-18-82 CPL/Cyberlook SCH 2" & 5" 10-18-82 LDT-CNL-GR (Poro) SCH 5" 10-18-82 LDT-CNL-GR (Raw) SCH 5" 10-18-82 Fracturd Iden. Log SCH 10" 10-18-82 BHCS Waveforms SCH 10" 10-18-82 High Res. Dipmeter SCH 5" D.S. 18-10 10-14/18-82 DIL- SFL SCH 2" & 5" 10-18-82 CPL/Cyberl ook SCH 5" 10-18-82 BHCS'- GR SCH 2" & 5" 10-18-82 Dual Laterolog SCH 2"& 5" 1 O- 18-82 FDC-CNL-GR (Poro) SCH 5" 10-18-82 FDC-CNL-GR (Raw) SCH '5" D.S. 6-23 10-17-82 BHCS - GR SCH 2" & 5" ! 10-17-82 DIE-- SFL - GR SCH 2" & 5" 10-17-82 -FDC-CNL (Poro) SCH 5" 10,17-82 FDC-CNL (Raw) SCH 5" P~'l eal 10,17-82 CPL/Cyberl ook S'CH 5" e sign and return the attached copy as receipt of data. Run 2 Run 1 & 2 Run 2 Run 2 Run 2 Run 2 Run 2 Run 2 Run 1 & 2 Run 2 Run 2 Run 2 Run 2 Run 2 Run 1 Run 1 Run 1 Run 1 Run 1 Becky Benedi ct AFA - 403 Trans. #613 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS r~Ct~orage' C°mr~iSs/oo ARCO Alaska. Inc. is a Sul~sidiary of AtlanticRichfieldCompany -.~,RCO,Alaska, Inc. Post Office £ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 12, 1982 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3.001 Porcupine Drive Anchorage, Alaska 99501' Subject' State Reports. Dear Mr. Chatterton' Enclosed are monthly reports for October on these drill sites' 1-21 18-7 1-22 18-I0 6-23 1E-26 6-24 1E-27 7-15 1F-7 13-14 1F-8 13-15 1G-4 WSW-4 WSW-5 WSW-6 Also enclosed are well completion reports for' 1-20 1G-2 6-22 1G-3 13-16 WSW-3 1E-30 The survey for 2-22 needs to be reran; a completion report for this well will be submitted.when an approved survey is received. We also are including subsequent Sundry Reports for 1-20 and 13-16. P. A. VanDusen D.istrict Drilling Engineer PAV'JGOI'ltc Attachments ECEIVED NOV i a i 82 AJaska 0ii & Gas Cons. Ccn~l~ission /tnchorage ARCO Alaska, lnc, is a subsidiary of AtlanticRichfieldCompany ,. . , STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO'-'~AISSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-157 3. Address 8. APl Number P. 0, Box 360, Anchorage, AK 99510 50- 029-20831 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well atsurface 1090' FSL, 1125' FEL, Sec. 14, T10N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial N°. 89' RKB ADL 28315 10. Well No. 13-15 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of. 0ctober ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1700 hfs, 10/04/82. Drld 17-1/2" hole to 2603'; ran,cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 10215'; ran logs; cont drlg to 10219'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 10626'; ran logs; cont drlg to 10642'. Ran & cmtd 7" liner. Drld cmt to 10597' PBTD. Ran CBL. Ran 5-1/2" completion assy. Secured well & released rig ~ 1200 hfs, 10/22/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, U-40, weld conductor set @ 78 5' Cmtd w/350 sx AS II , · · · · 13-3/8",72#/ft,L-80,BTC csg w/shoe @ 2581'. Cmtd w/2700 sx Fondu & 400 sx Permafrost C. 9-5/8",47.0/#ft,L-80,BTC csg w/shoe ~ 10209'. Cmtd w/500 sx Class G & 50 bbls Permafrost C. 7" 29 0 #/ft, L-80, BTC csg f/9904'-10639' Cmtd w/335 sx Class G , · · · SEE DRILLING HISTORY 14. Coring resume and brief description none 15. Logs runand depth where run D I L/SP/GR f/10,212'-7700' DIL/BHCS/GR/SP f/10620'-10207' LDT/CNL/GR/Cal f/10620'-10202' CBL/VDL/GR/CCL 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~~-~ Area Drilling Engineer SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 G R U 2 / H R 1 6 Submit in duplicate Rev. 7-1-80 DS 13-15 DRILLING HISTORY NU 20" Hydril .& diverter. Spudded well @ 1700 hrs, 10/04/82. Drld 17-1/2" hole to 2603'. Ran 64 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2581'. Cmtd 13-3/8" csg w/2700 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter.. Instld 13-3/8" packoff & tstd to '2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10215'. Run DIL/SP/GR f/10,212'-7700'. Cont drlg to 10,219'. Ran 245 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 10209'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8"packoff & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10626'. Ran DIL/BHCS/GR/SP f/10620'-10207'and LDT/CNL/GR/Cal f/10620'-10202'. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20,~~ermafrost C & 130 bbls Arctic Pack. Cont drlg 8-1/2" hole to 10,642' TD (10/18/82). Ran 18 jts 7" 29#/ft, L-80, BTC csg f/9904'-10639'. Cmtd 7" lnr w/335 sx Class G. Drld cmt to 10,597' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL/VDL/GR/CCL. Ran 5-1/2" completion assy w/tail @ 9947' & pkr @ 9841'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Nipple for SSSV @ 2205'. Secured well & released rig @ 1200 hrs, 10/22/82. JG'sm 11/04/82 GRU2/DH18 ARCO Alaska, Inc. Post Office ~:~ 360 Anchorage, ,ska 99510 Telephone 907 277 5637 November 6, 1982 Reference: ARCO Open Hole Final s D.S. 1-21 10-15-82' FDC/CNL 10-15-82 DIL 10-15-82 BHCS-GR 10-15-82. CNL :' ' 10-15-82 FDC 10-15-82 Prolog-Field Analysis Run 1 2" & 5" D/A Run 1 2" & 5" D/A Run 1 2" & 5" D/A Run 1 2" & 5" D/A Run 1 2" & 5" D/A Run 1 5" D/A D.S. 13-15- 10-18-82 Arrow Plot w/ listing Run 1 5" SCH D.S. 13-16 9-30-82 .4-arm Continuous Dipmeter Run 1 5" SCH 9-30-82 LDT/CNL/GR** (Poro) Run 1 5" SCH 9-30-82 LDT/CNL/GR** (Raw) Run 1 5" SCH 9-30-82 CPL/Cyberl ook Run 1 5" SCH 9-30-82 BHCS Waveforms Run 1 5" SCH 9-30-82 DIL-SFL Run 1 2"& 5" SCH 9-30-82 BHCS Run 1 2"& 5" SCH *The date on the log is listed ~-1-15-82, however the correct date is 10-15-82. **These are also the corrected copies, the field prints for these are incorrect. Please sign and return the attached copy as receipt of material. Becky Benedict AFA- 403 Trans. #600 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL D&M STATE OF ALASKA DALLAS Thru: Lonnie C. Smith Commi s sione r MEMORANDUM Stale of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION DA/E: Octo~r 11, 1982 FILE NO: 108/0 TELEPHONE NO: FROM: ]~ro,]~ R~ ]~wki~ ' Petr~eum InsPector ~~ Witness BOPE Test ARCO DS 13-15 Sec. 14, T10N, R14E, UN Permit No. 82-157 ThursdaY, Oct~r_ ?,_.~ 1982- I left ARCO's DS 18-10 after witnessi~ the' BOPE test, subject of another report, to ARCO's DS 13-15 well to witness another BOPE test. When I arrived on the' location, pressuring up on the BOPE stack and getting ready to test BOPE was in process. I witnessed the BOPE test on well No. 13-15, there w~re no failures° In ~ammary, I witnessed the BOPE test on well No. 13-15 that Rowan performed fur ARCO. Tests were performed satisfactorily. 02-00IA(Rev.10/7.9) O&G ~ 4 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION, COMMISSION B.O.P.E. Inspection Report " Date Inspector Well Operator ,~ ~ l":O /~'JA~ff~4-- J,(2, Z- Representative Well ~-5' / -~ 7If Permit Location: Sec /y T/~R/~:DM .!,:~Casing Set Drilling Contractor ~f~~ ...Rig ~ ~/ Representative. Location, General . Well Sign .. . General Housekeeping ,-. Reserve pit Rig W/~ BOPE Stack Test Pres sure ACCUMULATOR S'YSTEF1 Fuli Charge Pressure ~/ ~' ~ .ps.ig Pressure After Closure..?ff ~ ~ psig... 200 psig Above. Precharge Attained: mit ,362 sec Full Charge Pressure Attained: ~ min~_~sec · [ · Controls: Master. Remote' z~Z%~"_.___B._l_inds switch cove_r~ Kelly a'nd Floor Safety Valves Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kilt Line Valves - Check Valve Upper Keliy Lower Kelly Ball Type Ins ide BOP Choke Manifold No. Valves /~ No. flanges 3 X Test Pressure Test Pres sure , ,, Test Pressure - Test Pres sure Test Pressure .. .. Adjus,table Chokes zf~//-r~J- · {~ / i[ydrauically operated choke ~7/~ : :~%'~.d-Y _-- ........................ · ~. " / Test Results: Failures ~~'Test Time ~_ hrs._ ~t: Repair or Replacement of failed equipment to be made within' ~ days and:" Inspector/Commission office notified. Remarks:. z.4 ,7/.:,.,£4£ / Distribution orig.' - AC&GCC c c Ope ra to r cc - Supervisor Inspector., September 15, 1982 Area Dri I I lng Ent~ineer AR~ Alaska, lne. P. O. Box 369 Anchorage, Alaska 9~10 .Prudhoe Bay Unit DS 13-15 ~ Alaska, .Ineo Penni t lqo. Sur. ~e. 1090*FSL, II2S*FEL, Sec, 14, TION, R141~, BtmhOle Lee- 44traIL, 168'FILL, See. ZZ, T10N, RI4K, U~. Dear Mr. Enclosed Js the. al~proved application for pe~lt to drill a~ve referene~ well, ~ell s~pies and 8'~d Io~ ere no~ F~uiFed, A continuous directional 8u~ i8 required as per 20 AAC 15.0S0(b)(S). If available, a tape eontaintn~ the digitized 1o~ info~ation shall ~ su~itt~. ~ all logs for eopyin~ exempt experi~ntal logs, ~loeity ~rveys ~d di~ete~ su~eys. ~ny rivers in Alaska and their drainage system have been classified as Jm~rtant for the spawnin~ or migration of anad~us fish. ~atton8 in these areas are subject to AS 16.05.870 and the r~ulation8 pr~lKated thereunder (Title 5. Alaska A~tntetrative ~e). P~ior to e~neing operations ~u my ~ contacted by the .Habitat ~ordinator'$ Office. Depart~nt of Fish and Pollution of any ~ters of the State is prohibited by AS 46, ~apter 3, Article ~ ~d the radiations pr~u!Kated thereunder (Title 18, Alaska A~tntstrative ~de. ~apter 70) and by the Federal Water Pollution ~ntrol Act, as amnded. Prior to c~nein~ operations you My be e-onta, cted ~ a.repFesentative of the DepartMnt of ~viFo~ntal ~neervation. To aid us in 8ehedulin~ field ~k, please notify this office 24 hours prior to c~ncin~ installation of the bi.out prevent ion equi~nt so that a representative of the ~ission ~y be present to witness testin~ of the equip~nt ~fore the Mr. ~t-rk A. Major . PFudhoe Bay Unit ~ -2- September IS, 1982 surface casing .shoe iS drilled. V~heFe a diverter system is required, please alE notify this office t4 hours prio~ to ewneing ~quipment instal lati~ ~ that the ~ission may withes testing ~fo~ d-~illtq ~i~ the Shoe of the ~onduetor ptpe~ In the ~ent of ~sp~iion o~ abando~nt, please Wive this office adequate ad~e notification so that ~ may have a ~ enema present-. / Vez~ truly you~s~ AlaSka Oil' and Gao ~ee' ~ Ene'losure OCt ~ Dmpa~tm~nt of-Fish & Game, Habitat Section w/o e. ncl, D~partmmnt of g~tvi~onmmntal ~onsm~vation w/o encl. CVC ~ be ARCO Alaska, Inc. Post Office B.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Ak, September 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 13-15, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 13-15 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; an as-built location plat; and a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we estimate spudding this well October 1, 1982, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG: 1 lm Enclosures GRU1/L90 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ."" STATE OF ALASKA ~ ALASKA('~.,~L AND GAS CONSERVATION C ,viMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC I--] REDRILL [] DEVELOPMENT OIL [~( SINGLE ZONE DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. -- 3. Address P. O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 1090' FSL, 1125' FEL, Sec. 14, TION, R14E, UM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 0' FNL, 0' FWL, Sec. 23, T10N, R14E, UM DS 13-15 At total depth 11. Field and pool 44' FNL, 168' FEL, Sec. 22, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) ~--- 6. Lease designation and serial no. Prudhoe Bay 0i 1 Pool RKB 89' PAD 49'1__. ADL 28315 12. Bond information (see 20 AAC 25.025) Fe~lera I Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500',000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 5-1/2 Mi. NW Deadhorse miles 0' feet 13-16 well 120' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10709' MD, 9206' TVD feet 2560 10/01/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3600 psig@ .... Surface KICK OFF POINT 2800 feet. MAXIMUM HOLE ANGLE 39 Ol (see 20 AAC 25.035 (c) (2) 4500 psig@9206 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) ~0~ 20~r-' 9T.-5'-~-- H-40 Welded 80' 35' I 35' 110'1 110' 275sx PF to surf 1/-1/:/,, 13-3/8,, 72# L-80 BUTT 2566' 34' 34, 2600,I 12600' 2300sx Fondu + 400 sx PF z-1/4~" 9-5/8" 47# L-80 BUTT 10228' 33' i 33' 10261' [8856' 500sx G 1st Stage Ii I 300sx PFI 2nd Stage 8-'i/2~ /" 29# L-80 BUTT 748' 9961' 18622' 10709' !9206' 400sx Class G Cmt T 22. Describe proposed program: ARCO Alaska, Inc., proposes to directionally drill this well to 10709' MD (9206' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well. The distance to the nearest completed well will be 1.20' at the surface; the proposed well will not have a closer poif~t- to another wellbore anywhere downhole. -- 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ,? ili:.'.!:'.)' 'iii!:!;' i "..';t :;:': i,ng ............. ,. The space below for Commission use .?.'.::.:~ti'!,:.:~. i",.~i ?. i.~:: ~ t~'~"-~ ~'~',:':' ~'"""~'"" . ' ' '" "'. ',. ':'." ')'i'? CONDITIONS OF APPROVAL Samples required ...... Mud log required Directional Survey required I APl number DYES ~]~IN O . DYES ~.:NO ,~.Y E S •NO I 50- 'P~-F~i~--fi~-~-b-~-F- _ __ ' ........ A~'~lI'fJat--~---- / E · . _ ~ _ __._L / by order of the Commission Form 10-401 GRU1/PD29- -- Submit in triplicate Rev. 7-1-80 i · ' I = 5,93! ,246.6~ = _686,O85. O0 \ ~,. LAT - 70~13'01.62~" ~ ~.~.~ LONG- 148P29'55.856',. ' i I - 7o~t 3'oo.~76" , ',, ' ','~':',., :~", ,',~:.,::,:',.;; ~',".':. ?s,:,?~::,,, .~," ' :'"' , T lONr R14E~ U.M. I~ = tOO' ' I HEREBY CERTI~ THAT I AH PROPERLY REGISTERED AHD LICEHSED TO PRACTICE LANn SURVEY I,G IN ~'~-." THE STATE OF ALASKA AND ~HAT ~'" T,,s ~T ~S~,~S ~ ~S- ~,,~ s,,~v~ ~.~ ~ ,~. ~,~_....__. ~~~/~~~.~~ THAT ALL DIMEHSIONS AHD OTHER DETAILS ARE CORRECT, AS OF: ~~_ ..~.-, .~ I .SEP ~ ~ i982 ~ Oil & Gas Cons. Commi~l~ ~chorage AtlanticR~hfie~Com~ny ~ DATE: DRAWING N0: NORTH AMERICAN PRODUCING DIVISION ~=/l~/So ALASKA DISTRICT- PRUDHOE BAY ANNULAR PREVENTER BLIND RAMS PIPE RAMS DRILLING SPOOL PIPE RAMS 13-5/8" BOP STACK DIAGRAM Accumulator Capacit~ Test 1. Check and -fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. · 13-5/8" BOP Stack Test 1. Fill BOP stack .and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a, 250 psi low pressure test for a minimum of 3i minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed Pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. 'Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. RECEIVED'. · , ,, SEP 1 1982 ~ Oil & ~as Cons. Anchorage Rev. ~/~3/8~ /,-'/""./,- SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM IN(;'. SCHEMATZC ,~~ I0" HYDo OPR. BALL VALVE WE,L,L BORE (SEE BETAIL) I0' HYD. OPR. BALL VALVE ALLcusHION90'" TURNS ARE "TEE" ! I I~LL QBORE - I I RESERVE PIT AREA NOTE' FLOWI_INE DRILLING RISER 20" 2000 PSI WP ANNULAR PREVENTOR [, J IO" HYDRAULIC OPERATED BALL VALVES Valves on diverter lines open automati- cally when the annular preventer is closed. 2~O" CONDUCTOR PIPE "DETAIL" 2026010203 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc ~ (/9v thru 11) (4) Casg (12 thru 20) .. (21 thru 24) . Is the permit fee attached ..®..®............®....®...®.®........®. 2. Is well to be located in a defined pool' . ......... ,. 3. Is well located proper.distance from property, line .iiiiiiiiiiiiii 4. Is well located proper distance from other wells ... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bOre plat included-- 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait ............. . ,10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES Does operator have a bond in force ........ ~/~ Is a conservation order needed ... iii''iiiiiiiiiii'iiiiii{iii'ii .... ,~ Is administrative approval needed [ ........ Is conductor string provided ........................... . ............ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..... Will surface casing protect fresh water zones ..~.~[.~[~[[~.~..~ Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... NO R~2~ARKS Is a diverter system required .... ' ' Are necessary diagrams of diver;g~ Does BOPE have sufficient pressure rating - Test to ~-~-~ psig .. Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. /V~T ~/~7~ Additional requirements ............................................. Additional Remarks: Geology: Engineering: WVA~ JKT'-~ RAD JAL .-MTM /~ HJH ~ / rev{ 08/19/82 INITIAL GEO. UNIT ON/OFF' POOL CLASS STATUS AREA NO. SHORE 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 APPENDIXl ,, No 'special'effort has been made to chronologically organize this category of information. RECEIVED NOV 1. o .1982 :;:, , · ::.: :, :':- ' Anchorage L~j'~ ~ iII I Jli]:-] I~_I [~ i ' ' -~ .~.: & ~ · 1o~0. o ~, ~ ~ )t:'0 25.0 r D & A ' ,, ************************************************************************************** ~ G G. GO LYP OIOoHO1 YERIFICAI'IO~ I, iSTING PA{';F~ ** REEL HEADER SERVfCE NAME DATE :82/11/ 8 OR[GIN:~ REEL NAME :REEL ID CONTINUATION ~ PREVIDU$ REEL COMMENTS ~REEb COMMENTS ** TAPE HEADER ** SERVICE NAME ~SERV~C DATE ~82/11/ 8 ORIGIN :657,4 TAPE NAME ~ CONTINUATION # :01 PREVIOUS TAPE ~ COMMENTS ~'APECOMHENT~ ** FIbE HEADER SERVICE NAME DATE FILE MN~ R $ ST LVP 010,H01 VERIFICATION LISTING PAGe; 2 RECDRD TYPE 04[7 ** RECORD TYPE 047 ** ** COMMENTS ** SCHLUMBERGER A~ASKA COMPUTING CENTE. COMPANY = ATLANTIC RICHFIELD COMPANY WELL = DRILL SITE 13-15 FIELD COUNTY BOROUGH STATE = AbASKA JOB NUMBER AT ACC= 65716 RUN #1~ DATE LOGGED: 15 OCT 82 bOP: HGH BOTTOM DEPTH TYPE FLUID bVP 010.H01. VERIFICATION LISTING PAGE DENSITY = 10,2 LB/G VISCOSITY = 39'0 8 PH - FLUID bOSS g 11 2 R~F ~ 2,400' g 68,0'DF R~C =2.090 ~ 68,0 DF RM AT 6MT = 0,830' 8 189,0 THIS PRODUCT REPRESENTS A MERGE OF RU,.$ 1 AND 2 CONPANY FIELD COUNTY AT] ~ICHFIEbD COMPANY PRUDHOE-~.BA¥ NORTH SLOPE BOROUGH =========================================~ ~ _- ===================================== :::i:::~:i: iii~::'::::: :::::: :::::: ::::: ::::: ::::::::::::::: ~::::: ::::: ::::::: :~, i::: :::: :::i~:: ~ :~'.i ~i::~:::!i:Z~::i:::~:i :~ ~: %.i~ :::::::: :i'~:~'::.:?.?:::;.::'i::i~i::/:::::::::::::::::::::::::: ::::::::::::: :::::::: :::: : :::~i:::.. :: ::~::i.:i:.::" :: :? :::':::::::::: :~i: :::::::. ::: ::::.:: :::: :~::::::::::::: ,.:::: :::: ::: :::: :::::::::: ::: :::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::: ::::: ::: ::::::::: ::::::::::::::: ::::: :::: ::::::: :: ::::::::::::::::::::::::::::::::::::: :::::::??: ::::::: :::: ::: :: ~,..:::::: ::: ,:::::::::::': ::: :: ::.::: :::::::::~.:: ::::~:::: ::::::: ::: :::: :::::::::~: :::::::: :::::::::';:::::::::~::: :::::::::::::::: :::::::::::: :::::::: ::::::::: ::::::::'::::::::::::::::::.::? :::: ~.::::: ::::::::: :::: ::: ::::'~::: ::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::?::::::::::::::::: ::: ::::::::: :::::::: ::::::: ::: : ?::: ::::::: :::::::::::: ::::::::::::::::: ::::::::::::::~::::::::::: :::::: :::::::: ::::::~:::: ::::: :::::::::::::~::::::::: ::: ::::::::::::::: :??:::: :: :::::'::: ~:::::: :~:: ~. ':i'i:::~i!::: :~i: !i!::~:::: :~i: ::: !!:.i~::!:: ~i'!: :!i:~!::::::::!.::ii::! ?:::!!:::: ?~:::ii::~:;::::i~:"::::i?.::::::::::::::::::: ?:::~:? :::!.::: ?:? ::: ::: :::: ::::: :::~::'i::: :::::::::~ ::::: ::: :::::::::::::::.::??::!i:: ::::::::::::~:::~::::::: ~::::::::::: :: :::::::::::::::: ::::: ::: ::::::: :::.:: ::: :::::: ::: :: ::::::::::::::::?: ::: ::::: ::: :: :: ::::::::: :::::::::: ~::::::::::::::: :::::::::: ::::::::::: ::::::::::::::::::::::: :: ::~:::::::::: ::::::::::::: :::::::: :: :~::~::: :::::::::::::::::'::::::::::~::::::::: ::::: ?':~: :: ::::::::::::::: :::::::: :::: ::::~:~:: :: ?~::::: :: ::::::::::::: ::: ::: :::::::::::::::::::::::: ?:::::~::::::::::::::: ::: ::: :::::::::: ::::::::: ::::::::: ::::~::::~::::::::::::: ::::::::::::::::: ?::: :::::::: :::::: ::~: ~: ::::::::::::: ::: :::: ::: :::: ::::::::: :::?:::::::::::: :::: :: :: ::: :::: :::::: :::::~ :: :::: :::::: ::::::~ ::::::: ~: :: ::::: ::::::::::? ::: ::: :: ::: :: ::: :: ::: :::: :: :::: i~i.: :::::::::: ::: :i:'i :: :!:: ::: ?:: ::~: :;::::i::~!:~ ~!?~ :i ::: :i :~: :~ ?: :i ::: :/i !' :'!~: :,i:~ ~i:: :!i::::i 'i::::?.: :ii::?': !!::: '::;?~: :::::':: :~: ::~: :::::: i :: :: :::~ ?i: ::.::',:::: :::: ::: :: :~::: :::,::: ::~: :::: :: :::: :: :::: :::: ::::'::: ': :: :::: ::: :::::: ::?: ::: ::: ::: :: ::::::: :: ::: :::: ::: :: :: :: ::: ::: ::: :: :: ::: ::: :::: : :: ::: :: ::::: ::: :::: ::: :: :::: ::: :: ::: ::: :: :::::: :::: ?::: :::: :::::::::::: ::: ::: ::::: ::::: ::: :: :: ::::::?: ::::: :::: :::: ::::: ::::: :::: ::: :::::: ::: ::: ::: :::: ::: ::: ::' :::: ::: ::: :::::: ::::: ::: :::: ::: ::: ::: :::: :: ::::: :: ::::::: ::: ::::: :: ::::: :::::: :::: ::: ::: :::::: ::::::::::: ::::::: ::::::: ::::::: ::: ::::: ::::::::: ?:::: :::: :: ::::? :::: :: :::: :: ::::::: ::::: ::::::: ::::: :::: ::::: ::::::: :::::: ::: ::::: ::: :::::: ::::::: ::::? ?:::: ?:: :?:~:::: :::::: ~::~: ::: ::::: ::::::: ::: :::::::: :::::::::: ~:?:: ::::'i: ::?:::::::: :: ~,~ ::::: ::: ::::::? ::::: ::: :::: :::::: :::: ::: ::::: ::~:::: :::: ::::: :::::::: :: ::: :?::::::::::::: ::::':: ~:: ::':::~:.::::::::::: ::: :::: ::: :.: :::'?::: ~:::;::::i :?: : ::!.::~!:: ? :::::::::::::::::::::::::: ::: : ::i::!. :!~!i :::i!/: ::?, :?::::: :!'i:::'.::: :: ::":::::' ??.?.:': ?.::::~:. :?::::: ::: :: ::::: :':: :~<:::::::::: '?::::::: :: :::::::::::::::::::::::::::: :::"!':: :: ::: :::i.:::::::::::::::::' :::::::: ::::: ::: :::::'::::'.:::::?:::~'::::::: ??:::::::: :::::' ::::::: :: ::::::: ::::::::::: :::::::::: :: :::::: ::::::: :::: ::: :::::::::: ::::::::::::: :::::::::: ::::::: :::::::::::::: ::::::::: ~ :::::::::::::: ::: :: :::::::::::::::::::: :::::::::::: ::: ::?::::::::::: :::::::: :::::?:::: :::::::::::::: ::: ?::::::::: ::::::::::":::::::::::::?:::':::: ::: :: :::: ?::: ::: ? :: :::::::: :::: :: ::::::: ::::::: :::: :::::?:::::::::':::::' ::' :::: ::: ::::?:::: ::::::::::?::: :::: ::::::::::: :~::::: :~: :: :::::::::: :: ::::::::::: :::::::::: :::::::::::::::'~::::::: ::::::::: ::::::::::: ::::::::::::::::::': :::: ::: :: :::: :::::::: ::::::: :: LVP OIO,HO1 VERIFICATION [,ISTING PAGE 4 BOT~O~ DEPTH TOP DEPTM CASING 8~T SIZE TYPE FLUID DENSITY VISCOSITY PH 1061'O FT, 10202 FT. 9 5/8 IN, 10202 FTo 8,5 IN, ~IGNO,MU~FO, NATE 10,0 ~B/G 7,0 ~ 11,2 5 C3 2,100 ~ 62,0 Df' 1,750 @ ~2,0 P~ 1,540 ~ 62,0 D~ 0.754 ~,~ 185, DF ~ATRIX SANDSTONE .... . . . , =================================== ============================================== ENTRY BLOCKS ,lin 6:0 hVP 010oH01 V~;~IFICATIO~; LI$~I~G PAGg 5 DIL DT BHC GR BHC NPHI LDT RHOB ~D? DRHO LOT CAbI LOT GR RNRA bDT PEF LOT NCN~ FCN~ NR&T 0 0 0 GAPI 0 0 0 0 0 0 0 0 0 4 0 1 0 0 0 4 0 31 32 0 0 4 0 52 32 0 0 4 0 &! 32 0 0 4 0 68 2 0 0 4 o 35 1 0 0 4 0 44 0 0 0 4 0 28 ~ 0 0 4 0 3i 3.. o o 4 o 0 0 0 0 4 0 0 0 0 0 4 0 34 92 0 0 4 0 34 93 0 0 4 0 42 I 0 0 4 0 1 66 1 66 1 68 1 68 I 68 1 68 1 6B I 68. ** DATA ** DEPT 10648 ' 999 '999 DEPT 5000 SFbU -999 2500 IhD -999. 2500 IbM 2500 , PT "999, 2500 GR 5500 DRHO '999,2500 CALl 250:0 -999,2500 NCNb 2'5'00 -999.2500 ..999,~500 -999.2500 -999,2500 DEPT DEPT D~ LVP O!O,HO! VERIFICATION LISTING PAGF b 0100.0000 SFbU 2 -31,9219 GR 102 -999.2500 RHOB -999 -999,2500 RNRA 999 -999;2500 NRg'I' '-999 1426 IbV 1.8535 iLM 23125 D' 59,25~,38 GR 500 DRHO -999, O0 CAbI 500 PEF -999.2500 NCNb 500 0000 0000 -33 3750 -999 2500 -999 2500 -999 2500 SFbU 2 GR 105 RHOB -999 RNRR -999 NRAT -999 ,6914 IbD 2,3750 ,5000 DT 71,7500 GR 2500 ORHO -999'2500 CALl 500 PEF -999,2500 NCNb 5O0 9.00,0000 SFbU 1 999,2500 RHOB -999~2,500, RNRA -999 -999,2500 NRAT -999 5137 ILD 1,2715 IL~ 6.8,75 DT -999,2500 GR 2500 DRHO -999,2500 CALl -9.99,2500 NCNb 0000 SFbU 1,8047 IbD 1,4248 156:2 GR-::i;'-:i ~:I6~562'5 .DT. -999,2500 GR 2500 R'HOB -999,2500 DRHO '999'2500 CALl :-:999,2500 NCNL 2500 NRAT '999;2500 0000 DEPT m DEPT 1.9316 55,~81~ -999. 500 -999.2500 ,392b 5 ,5625 '999.2500 '999,2500 1.3320 9 2500 -999 2500 1.4824 -999,2500 -999~2500 ~"'999,2500 LVP 010,H01 VERIFICATION LISTING PAGE. 7 OEPT 9~00 8P '53 NPHI -999 GR -999 FCN5 -999 DEPT 9100 SP -48 ~PHI -999 OR '999 FCNL -999 OEPT 9000, SP ..$I. NPHI -999, GR FCNL -999; DEPT 8900 Sp. NPHI CNL DEPT NPHI 8 8 0 0 0000 SFLU 375 GR 500 RHUB 2500 RNRA 2500 ~RAT 0000 SFLU 9375 250O 2500 RNRA 2500 NRA~ 0000 SFbU 6875 GR 2500 RHOB ' 0 2510 R~RA 2500 N~AT OOoo. sr u 7 0078 II.,D 3.4180 Ib~ 3.4746 104 2500 UT -999,2500 GR -999,2500 -999 2500 DRHO -999'2500 C~LI -999.2500 '999 2500 PEF -999.2500 NCNL -999.2500 -999 2500 2.3750 ILD 1 4990 IL~ 1,5859 ,!~5,~250 DT -999:2500 GR -999,2500 '999; 2500 2.7539 ILD 1,4424 lb~ 1.6250 :~.5000 DT -999.~500 GR 999,2500 2500 DRHO -999. 500 CALl :999,2500 999,:25.00 ,PEF -999.2500 NCNb -999,2500 "999.2500 ! 7539 ILD 1,2432 InN 1.300~ -999,2500 GR -999,2500 ~= 9' ;2'500~ ~ DRHO '999.2500 CAbI -999,2500 99'9:'~0:0: .P,~F -999,2500 NCNb -999,2500 ~ 0::::::::;::::::::::::::::::??:/ ::.:: :: :,:: ~9:9~ 2:5 O0 NC:NL ,999 ~ 2::5:0.0 'g'9,2500 2', 27~3 ........... ILD l, 8994 ~L~ 2,0i'! 7 O E P T 8'5'00 ': 00:00 $FLU . D EPT 8400,0'0"0"0 ......... SFLU i" 70'6I I'L"D 2,24'22 999 ~ 99'9'~ 2'SUG ::NC Nb -99:9 ~:25:'00 .~: GVP 010,H01 VERIFICATION LI:'ro IN,C PAGE DEPT 8300 SP -61 NPH! -999 GR -999 FCNL -999 NPHI GR FCNL 0000 SFLO 5000 GR 2500 RH00 2500 RNRA 2500 NRAT 820o,0000 SFLU ~61,7813 GR - 99,2500 RH00 -999,2500 RNRA -999,2500 NRAT DEPT 8100 NPHI -999 GR '99,9 FCNL -999 FCNL -999 DEPT 7900 N CNL DEPT 0000 SFLU 0000 SFLU 2.4512 ILD 9'7,9375 DT '999.2500 £)RHO '999,2500 PEF -999,2500 1.8818 ILD 82,125o DX -999~,2500 DRHO '999,2500 PEF '999,2500 2 3926 ZLD 93 1250 D? -999 2500 DRHO '999 -999 0000 SFLU 5 5i6~.~,~5 ........ '::GR~::~:i: 3965 ILD 2.4414 ILR '999,~500 GR '999. 500 CAbI '999.2500 NCNL ! 5332 '999~2500 GR -999.2500 CALl -999,2500 NCNL 2.4395 IbM GR CALl NCNb 2,4980 G -999,2500 '999,2500 CALl -999,2500: NCNb 2.4961 999'2500 '999,2500 1.,632~ :999,2500 999.250U -999,2500 2.4570 '999,2500 -999,2500 -999.2500 2. 502 o -g99,2500 -999,2500 -999,2500 's LVP OIO,HO1 VERIFICATION LI,~TING PAGE 9 DEPT 7400 SP -'30 NPHI -999 OR -999 FCNb -999 DEPT 7300, SP -33, NPHI -999, GR -999' FCNL -999, DEPT !200 SP -4! NPH! 999 GR DEPT GR FCNL 0000 SFLU 35,94 2500 RHOB 2500 RN:R~ 2500 0000 SFbU 1250 GR 2500 RHU~ 2500 RNRA 2500 NRAT 0000 SF[,U 9062 GE 2500 RHOB 2500 · R N 2500!~RAT 3,3555 ILD 108,87750 DT -999,2500 DRH~ -.999,2500 PEF 999 * 2500 2.9082 ILD 10!:.9375 DT -999'2500 DRHO '999,~500 PEF '999, 500 7100 0000 SFbU 2 -999, .... · :.~99'9 2500 NRAT '999 25'0'0 9922 3,8145 IL~I -999,2500 GR -999.2500 CAbI -999,2500 NCNb 3.~340 IL~ -999,2500 GR '999,2500 CALI '999,2500 NCNb 3,9355 IbM '999,2500 GR '999.2500 CAb! '999,2500 NCNb 4,0469 IbM -9:99 2500 999 21500 ,:' :N'CN:b 3.7695 -999,~50Q -999, 500 -999,2500 3.6582 -99 2500 - :2soo -999.2500 4,1797 :999 2500 999."*2500 '999,2500 '999,2500 -999,2500 '999,2500 4.4805 '999,2500 ., 999,250'0 DEPT NPHI F( b DEPT NPHI bVP OIO,H01 VERIFICATION LISTING PAGE 10 DEPT 6500,0000 8FLU MB -67,1875 GR- NPHI -999~2500 RHOB GR -999;2500 RNRA FCNL -999,2500 NRAT DEPT 6400 SP -120 NPHI -999 GR -999 FCNL -999 D£PT 6.,~)00 SP I28 NPHI -999 GR FCNL DEPT 0000 SFLU 6250 GR 25O0 RHOB 2500 RNRA 2500 ~RAT 0000 8FLU 2500 RHOB 2500, RNRA 2500 ~!RAT 6200 o000 5FLU FCNL -999 DBPT 6100 6875 999,2500 DRHO 500 999;~ 999. 500 6 7344 "999 2500 '999 2500 '99 5 793O 3 -999 -999, ILD DT DRHO PEF ltd 3.4512 ILB 3,4277 -999,2500 GR -999,2500 '999.2500 CABI -999,2500 -999,2§00 NCNb -999.2500 1,5674 IL~ 1,9375 -999,2500 GR -999,2500 -999.2500 CALl -999.2500 -999,2500 NCNL -999,2500 1.1328 Ib~ i,4219 '999'2500 ~b '999, ~500 '999.2500 I -999, 500 '999'2500 NCNb '999,2500 -999,2500 NPHI LVP 010,HO! VERIFICATION LISTING PhGE 11 DEPT SP NPHI GR FCNL DEPT SP NPH! FCNb DEPT SP NPHI GR FCNb DEP? SP. FCNb 600.0000 SFLO '39.43?5 OR!: 999.2500 RHOB -999.2500 RNRA -999.2500 NRAT 5500.0000 SFLU -55'1562 OR: -999,2500 RH06 -999'25:00 RNRA -999,2500 NRAT 5400,0000 SFbU 437 R -45,~ O -999, 500 RHOB -999,2500 NRA 5300 0000 SFLU -125:12':50 -999.2500RHOB '999,~500' 'NRAT 3.1289 ILO 74,5625 DT -999.2500 DRHO '999,2500 PEF -999,2500. 3.2324 II.,D 78,6875 DT :999,2'500 ORHO 999~ 2500 PEF -999;2500 3.7637 IL, D 78.6250 DT :999,2500 DRHO 99,9,2500 PEF -999.25'00 . 3,6934 999'2500 -999~2500 CALl -999.2500 NCNb 3,~23 -999e oo GE -999,2~00 CAb! -999,2500 NCNb 3.2949 I5~ '999,2500 GR -999,2500 CA. bi -999,2500 NCNb 0996 ILO ,, 25'00' DRHO ~999, o. 3916 ILM 2500 ,R 2500 CALI 2500 NCNb 390'6 ILD 2 7129 IL~ ;t25~0:0:.:.: ,: :NCNb 3.4121 '999,2500 -999"250~ '999,2500 3.5098 '999,2500 '999.2500 '999,2500 3,205! -999,2500 -999,2500 '999,2500 1.5781 '999,2500 -999,25'00 -999,2500 3 0645 -99:9 -999 -99:9 2:'1500 DEPT 5101 0'0'00 ...... $'FLU 4 'X562 .... ILD 4 2:92'58 ....... lbD . 3'9922 IbM 3,773A :~:!~:¥:.?i~! ;?<:;, :::~.~?~t~ :: ~:9~9 ~ 2500 NCNb' :~::: :.: ,R! 4800 ,U 5 'X'4'4 5 .... X'SD -9' 343'8 IbM 2,6270 '~' 9'99, "'~N NC :::::: !~::":9:9942500 3'9'84 I'LD I, 6475 I'L~ . 1,8'838 ~;;~'~0'~~ ~"~:'H ~'9'99: ~:500 CALl 999' ~'500 2'50'0 DVP 010,[t01 VERIFICATION bi,. fIND PAGE', 12 DEPT 4700,0000 SFLb SP -62.4'375 GR NPHI :999,2500 RHOB GR 999~2500 RNRA FOND -999,2500 NRAT DEPT 4600,0000 SFLU SP "54~7188 Ga NPHI -999~2500 RHOB OR "999.2500 RNBA ~¢Nb '999~2500 NRAT D£PT 4500 0000 SFLU SP 9'375 GR NP.! -;9 2500 R.00 OR FCNL O0 NRA~ o°°o SP NPHI 'NPH! '9'99,250'0 R~OB ~ .;.. ~ ':,~ .?:: ,, ;: ~ : FCNb 999~ 2500 NAA'. 36,343~ IbP .999'25oo :999.2500 PEF 999.2500 4.1016 71.6250 DT -999,2500 DRHO 999,2500 PEF 999.2500 5 9141 IbD -999 · -999 -999,2500 GR -999 2500 -99~ ~5oo CA~,I -V992~ 4.4609 Ib~ 3,9883 ' -999.2500 GR -999,25 0 -999.2500 CADI -999.2500 '999.2500 NCNb '999,2500 3.5039 IbM ,_3 B047 '999,2500 GR '999'_2500 '999,2500 CALl '999 2. 500 · '"999.:2500 NCN5 '999,,250 5,2500 IbD 4.5117 ~999,2500 GR '999~ 2500 5 6406' ILD 5 8~28 4' ;D 5 61'3'3 1b[~ 4.5391 -999,2500 -99912500 -999~..2500 5,48.83 -999,~5'~0 ,-9:9..9: ~ 21500 5 5586 bVP OlO,HO! VfiRIFICA'rIO~'~ LISTING PAGE DEPT 3~00,0000 SFLU SP 63*4375 GR NPHI -999,2500 RHO6 GR -999,2500 RNRA FCNL -999.2500 NRA~ DEPT (;JR FCNE DEPT SP NPH! GR FCNb DE:PT DEP? FC b PT F{ 3700 0000 '84 -999 999 2500 SFLU RNRA NRAT 3600 0000 SFbU -999 B 3500 0000 sFLu 99 999, ,4875 500 DRHO -99:9,2500 PEF -999,2500 7.4688 1L~ '999,2500 GR -999,2500 CALf -999,2500 NCNB 7 63 '999 '999 '999 3086 lbo 5000 T 2500 ~RHO 500 PEF 50O 8.1797 lbt,~ -99~:22500 GR -99 500 CALI -999,2500 NCNb 7,0117 ILD 6':53!3 DT -90~' ,2500 DRHO 7.3398 -999 ~500 -999 500 -999 2500 GE CADI 8.9687 ILD .~ 8,5859 Ihl~ . :6~,:7:500: :DF 999, 2500 GR 999,2500DRHO 2999;2500 CALl ~9:99 '2500:. ' 999,2500 NCNb '999,2500 6,0430 0 500CA~I 6,7852 -999,2500 -999,2500 -999,2500 7.789~ -999,2500 -999.2500 -999,2500 7,5938 .-999,2500 999.2500 -999,2500 8.5076 -999,2500 -999~2500 -999~2500 5.2070 bVP 010,HO! VERIFICA?ION LI6T.[NG PAGk 16 DEPT 2300 0 00.~0., SFL~ 90 '.z-~5 GR SP NPHI -999-250. 0 RHOB GR -999,~500 RNRA FCNL -999.2500 NRAT DEPT 2800 0000 SFbU : ooo NPHI .,.99 , 500 GR -999,2500 RNRA FCNb -999,2500 NRAT DEPT NPH! GR FCNb DEPT 2700.0000 SFLU -999 2600,0000 BFbU GR. i , ,999 FCNL -999 3,4238 65,3750 DT -999.2500 DRHO '999,2500 PEF -999;2500 5.2422 ~5,437,5 DT -999.2500 DRHO ,,999,2,5,00 PEF -999.2500 3,3496 50 · b250 DT -999,2500 DRHD -999,~500 P:EF '999.2500 2.9473 IL~ -999,250U GR -999.2500 CALl -999.2500 NCNb 3.2168 -999,2500 -999.2500 -999.2500 2.3750 IL~ -999,Z500 GR -999'2500 CALl -999.2500 NCNb 3.1289 '999,2500 -999.2500 -999.2500 . 2,9805 IbM 999,2500 GR -999,2500 CALI -999,2500 NCNb 3,3125 -999,2500 -999,2500 -999,250U 3,5703 :.7:4'4 3.75 :': D':T ': -999.2500 DRHO ~:999.2 510 0 '9'99,250 0 4.0234 ILM -9.99,2500 GR · -999,2500 CALi -999,2500 NCNb 4375 999: 2500 -999.2500 DEP~ 2545 6:~6"6"0:~':'::' ~:"~'U 4,5'~':6'9 IbD 2000,0000 I~N 2000,0000 ,':i:!~'/: ~ 9~0!62~,:~i 'D~:? :: "99:9,: '500 OR :"999 ' 2500 :::: :::::::: :::] :::::::::::::::::::::: : :: :: :: :::; :::::,:::: ::: :::::::: :::::: :: :: ::: :: :: :::::: ::::::: :::: ::: :: :::: ::,:: ::::::: ::::: : ::: :: :::: :::: bVP OIO,HO1 VERIFICA'rlO~ i,.,1STI~G PAGE~ 15 SERVICE NAME :SERVIC DATE 182/11/ ORIGIN : REEL NAME ~REEBo~D CONTINUATION # NEXT R£Eb NAME COM~ENI$ IREEL COMMENTS
