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213-140
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This well was not fractured. I can re-send the 10-407 with the proper box checked, or please hand correct. Let me know at your convenience. I apologize for the confusion. Thanks, Joe From: Ciolkosz, Ryan R Sent: Monday, May 09, 2016 2:07 PM To: Lastufka, Joseph N Subject: FW: PBU 15-45C (PTD # 213-140) - Completion Report Question Ryan Ciolkosz Drilling Engineer MEED f 2 1206 HP Exploration Alaska %/ G Office: (907)564-5977 Cell: (907)244-4357 From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Monday, May 09, 2016 12:54 PM To: Ciolkosz, Ryan R Subject: PBU 15-45C (PTD # 213-140) - Completion Report Question Ryan, While reviewing the Well Completion or Recompletion Report and Log for PBU 15-45C (PTD#213-140), I noticed that in the lower right portion of page 1 of the form the box next to the question: "Was hydraulic fracturing used during completion?" is checked "Yes". I read through the well history file and I do not see any evidence that this well has been hydraulically fractured. Could you please confirm that this well has not been hydraulically fractured? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7`h Avenue,Suite 100 Anchorage,AK 99501 1 RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMM! APR 2 5 2016 WEL COMPLETION OR RECOMPLETION REPO AND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned IZJ • Suspended 0 lb.Well CIaAOGi VVV�C 20AAC 25.105 20AAC 25.110 Development p Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero • Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 3/29/2016 - 213-140. 316-037 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 12/17/2013 50-029-22671-03-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 1/1/2014 PBU 15-45C ' Surface: 4749'FSL,5180'FEL,Sec.22,T11N,R14E,UM • 9 Ref Elevations KB 68.06 17. Field/Pool(s): Top of Productive Interval: 3265'FSL,1501'FEL,Sec.16,T11N,R14E,UM GL 32.7 • BF 34.76 PRUDHOE BAY,PRUDHOE OIL • Total Depth: 3602'FSL,4109'FEL,Sec.16,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9620'/8602' ADL 028306 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD(TVD): 19. Land Use Permit: Surface:x- 676014 • y- 5960952 • Zone - ASP 4 • 12750'/8808' ' 78-084 TPI: x- 674318 y- 5964710 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 671701 y- 5964986 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9286'/8313' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD DIR/GR,GR/CCL/RPM 23. CASING,LINER AND CEMENTING RECORD CASING Wr.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT FT. CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 36' 116' 36' 116' 30" 260 sx Arctic Set(Approx.) 9-5/8" 40# L-80 36' 3831' 36' 3556' 12-1/4" 305 sx Class'G',1085 sx CS III,200 sx CS I 7" 26# L-80 33' 9260' 33' 8289' 8-1/2" 230 sx Class'G' 4-1/2" 12.6# L-80 9090' 9286' 8128' 8313' 6" 220 sx Class'G' 3-1/2'x 3-1/4" 9.3#/6.6A L-80 9003' 12750' 8046' 8808' 4-1/4" 235 sx Class'G' x 2-7/8" /6.5# 24. Open to production or injection'? Yes 0 No IZI 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom:Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80/L-80 9092' 8946'/7993' 9057'/8097' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. �`� (6' AGAN190 NES COMPLETIOIv Was hydraulic fracturing used during completion? `/ DAT Per 20 AAC 25.283(i)(2)attach electronic and printed Yes 4 No L(�' 3/ �14, f, information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LA- 10150' Set CIBP 9620' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for 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 ""(1 Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only la vn 573/ie. 537 RBDMS L� APR 2 6 2016 . 4� 28. CORE DATA • Conventional Core(s) Yes 0 No lI Sidewall Cores Yes 0 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 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No E1 Permafrost-Base If yes,list intervals and formations tested.briefly summarizing test results.Attach Top of Productive Interval 9933' 8735' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. • CGL-Zone 3 9456' 8466' Base of CGL-Zone 2C 9525' 8524' 23SB 9587' 8575' 22TS 9637' 8615' 21 TS-Zone 2A 9748' 8682' Zone 1B 9933' 8735' TDF-Zone lA 10721' 8751' Zone 1B(Invert) 11025' 8755' TDF-Zone 1A 12000' 8769' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ciolkosz,Ryan Email: Ryan.Ciolkosz@bp.com Printed Name: Joe Lastufka Title: Drilling Technologist Signature: hone: +1 907 564 4091 Date: +0Sh 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection.Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations 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 15.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 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records 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 MC 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 MC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • vr • 15-45C, Well History (Pre-Rig Sidetrack) CTU #3. 1.75" Coil (33.1 bbl). Objective: Set CI BP. Set Baker 3.25`"CSP @ 1 s ". 7 �T per program. POOH pumping 30 bbl coil displacement freeze protect. Begin partial rig down then go on 2/4/2016 weather hold. 2/5/2016 CTU #3. 1.75" Coil (33.1 bbls). Continued weather hold; wind finally below 25 mph, lower mast. T/I/O =980/230/0. Temp= SI. TBG FL(FB request). No AL. T FL @ 2580' (39.2 bbls). 3/1/2016 SV, 2nd SV, WV, SSV= C. MV= O. IA, OA= OTG. 0400 T/I/O= 965/182/4 TEMP= S/I MIT-T to 2500 psi FAILED Pumped 3 bbls of neat methanol down F/L for freeze protect. Pumped 60 bbls Diesel down Tubing in attempt to MIT-T to 2500 psi. Max pressure reached at 2 bpm was 1713 psi once fluid packed TBG, ran out of fluid. Pumped an additional 48 bbls of DSL down TBG at 5 bpm, max pressure reached of 2310 psi. FWHP=538/64/- 3/2/2016 3 SV,SV,WV,SSV=C MV=O IA,OA=OTG DSO notified upon departure Tag hung on MV T/I/O=995/240/0. Removed 2nd SV(Crown) & Installed CTD TS#02 &torqued to API Spec; PT down on SV/Test Spool PT to 300 psi-low, 3500 psi-medium &5000 psi-high (passed); Set 4"CIW 3/17/2016 TWC#431 @ 140"; Performed LTT on TWC (passed); RDMO FWP=TWC/240/0. 3/20/2016 T/I/O=TWC/0/0 Removed tree cap bonnet, installed blind flange with jewelry. FWP's TWC/0/0. • T/I/O=TWC/240/0+. Temp= SI. Bleed WHPs (Pre CTD). No AL, wellhouse, flowline or swab platform handrails. Initial IA FL @ surface. Initial OA FL= near surface. Bled the OAP from 0+ psi. to 0 pi in 5 seconds(all gas). Bled the IAP from 240 psi to 0 psi in 1 hour(gas&fluid, -1 bbl, BT) IAP increased to positive pressure during the 30 minute monitor. FWPs=TWC/0+/0. .� 3/21/2016 SV, WV= ?. SSV=C. MV= O. IA, OA= OTG. 1100 hrs. T/I/O =TWC/60/0. Temp = SI. WHPs (post bleed). No wellhouse, flowline or swab platform hand 3/22/2016 rails. IAP increased 60 psi since 3/21/16. SV, WV= ?. SSV= C. MV= O. IA, OA= OTG. 17:10. T/I/O=TWC/70/0. Temp= SI. WHPs (post bleed). No wellhouse, flowline or swab platform hand 3/23/2016 rails. IAP increased 10 psi since 3/22/16. SV, WV= ?. SSV=C. MV= O. IA, OA= OTG. 13:30. T/I/O =TWC/90/2. Temp = SI. Bleed WHPs to 0 psi (pre CTD). Wellhouse, flowline, and scaffold disconnected. IA&OA FL near surface. Bled IAP from 90 psi to 0+ in 3 min &OAP to 0 psi in < 1 min (all gas). Held open bleed on IA for 1 hr 30 min. Monitored for 30 min. IAP increased 4 psi. 3/26/2016 Final WHPs =TWC/4/0. SSV= C. MV= O. IA, OA= OTG. 09:30. • 1111 • North America-ALASKA-BP �� Page 1 cep, Operation Summary Repo Common Well Name:15-45 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/26/2016 End Date.4/7/2016 X3-017P2-C:(3,846,961.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:4/8/1996 12.00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292267100 Active datum:Kelly Bushing/Rotary Table©68.O6usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 3/26/2016 10:00 - 10:30 0.50 MOB P PRE RIG RELEASED FROM C-21. PREP RIG FOR JACKING UP AND MOVING OFF WELL. 10:30 - 12:30 2.00 MOB P PRE CONDUCT PJSM FOR MOVING OFF WELL. REVIEW RISK MITIGATIONS WITH CREW FOR MOVING OFF WITH NO TWC IN PLACE, INCLUDING: -USE OF CHOCK BLOCKS TESTING AND MANNING THE ESD USE OF THE STOP COMMAND -RADIO CHECKS BY ALL CREW PULL OFF WELL AND MOVE TO SIDE OF PAD. PICK UP RIG MATS AND CLEAN UP AREA. 12:30 - 13:00 0.50 MOB P PRE GET WWT PERMIT SIGNED OFF SO CTU CAN BEGIN RtG UP. RIG MOVES OFF PAD TO TWIN TOWERS ROAD. 13:00 - 17:30 4.50 MOB P PRE MOVE FROM C-PAD TO DS-15. ROUTE IS C PAD ACCESS ROAD,LEFT ON TWIN TOWERS ROAD,LEFT ON SPINE ROAD,LEFT ON OXBOW TO DS-15. RIG BLEW TIRE. 17:30 - 00:00 6.50 MOB N RREP PRE MOBILIZE EQUIPMENT TO REPAIR TIRE PRIOR TO MOVING RIG REMAINDER OF WAY TO DS15. CONTINUE WITH TIRE REPAIR 3/27/2016 00:00 - 05:00 5.00'" MOB N RREP PRE CONTINUE TO WORK ON TIRE REPLACEMENT. 05.00 - 07.00 2.00 MOB P PRE FINISH FIXING TIRE AND REPLACING STEERING LINKAGE. CONTINUE MOVING TOWARDS DS-15._ 07:00 - 08:30 1.50 MOB P PRE TURN OFF OXBOW ROAD ONTO DS-15 ACCESS ROAD. RIG ARRIVES ON PAD. BLEED DOWN S-RISER ON ADJACENT WELLS TO HEADER PRESSURE. LO/TO LATERAL,ANNULUS VALVES AND WING VALVES ON ALL ADJACENT WELLS WITH WELLHOUSES OFF AS PER"CLOSE PROXIMITY FOR WORKOVER/DRILLING"SOP. 08:30 - 11:00 2.50 MOB P PRE PLACE RIG MATS AROUND 15-45D,PREP RIG TO MOVE OVER WELL. PJSM WITH RIG CREW,DISCUSS HAZARDS AND MITIGATIONS FOR PULLING OVER, DISCUSS EXPOSURE RISKAND WARMING UP IF NECESSARY. PULL OVER WELL WITH NO ISSUES, WITNESSED BY WSL AND PAD OPERATOR. AFTER PULL OVER,REMOVE LO/TO FROM ADJACENT WELLS WITH WELLHOUSES REMOVED. 11:00 - 13:00 2.00 MOB P PRE ACCEPT RIG AT 11:00. LEVEL AND SHIM RIG. MOVE ANCILLIARY EQUIPMENT INTO PLACE, START RIGGING UP. OPEN SSV,INSTALL FUSIBLE CAP, WITNESSED BY WSL. 13:00 - 16:00 3.00 MOB P PRE GET GOOD LEAK TIGHT TEST. REMOVE TREE CAP,INSTALL BOPS. Printed 4/11/2016 1.39:46PM "Ail depths reported in Drillers Depths* North Amenaa ALASKA Bi Page 2 gfQO • Operation Summary Report ` ' Common Well Name:15-45 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/26/2016 End Date:4/7/2016 X3-017P2-C:(3,846,961 00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:4/8/1996 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292267100 Active datum:Kelly Bushing/Rotary Table @68.06usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 16:20 0.33 MOB P PRE RIG EVAC EXERCISE WITH ELLINGTON CREW. ALL PERSONS MUSTER AND ACCOUNTED FOR IN 2 MIN. CONDUCT MR. 16:20 - 23:00 6.67 BOPSUR P PRE TEST GAS ALARMS,INSTALL TEST PLUG. FILL STACK WITH WATER TO BEGIN BOP 'TEST.WITNESS WAIVED BY BOB NOBLE (AOGCC) TEST COMPONENTS PER BP/AOGCC/ NORDIC PROCEDURES LOW 250/HIGH 3500 ON ALL COMPONENTS. 23:00 - 00:00 1.00 BOPSUR P PRE PJSM,PICKUP INJECTOR. CIRCULATE DIESEL OUT OF COIL TO TIGER TANK PREPARE FOR INNER REEL VALVE / PACKOFF 3/28/2016 00:00 - 00:30 0.50 BOPSUR P I PRE FINISH CIRCULATING DIESEL OUT OF COIL. POP OFF TAKE NOZZLE OFF STAB INJECTOR BACK ON 00:30 - 01:00 0.50 BOPSUR P PRE ESTABLISH REVERSE CIRCULATION. CLOSE INNER REEL VALVE AND CM#14. TEST INNER REEL VALVE AND PACKOFF TO -LOW 300/3500 HIGH. GOOD TEST. BLEED DOWN 01:00 - 01:20 0.33 BOPSUR.. P PRE LINE UP TO REVERSE CIRCULATE COME ONLINE @ 2.5 BPM. E-LINE MOVING FOR ABOUT 5 BBLS. COME OFFLINE ONCE WIRE STOPPED MOVING. BLOW BACK WITH AIR WHILE PJSM FOR CUTTING COIL. 01:20 - 02:30 1.17 BOPSUR P PRE POP OFF. RIG UP COIL CUTTER. CUT 230'OF COIL TO GIVE 1.67%SLACK. RIG DOWN COIL CUTTER. 02:30 - 04:15 1.75 BOPSUR P PRE INSTALL NIGHT CAP. OPEN HOT WORK. PREP COIL FOR COIL CONNECTOR. INSTALL COIL CONNECTOR. PULL TEST TO 35K, GOOD PULL TEST. PRESSURE TEST 300 LOW/4450# GOOD TEST 04:15 - 05:00 0.75 BOPSUR P PRE MAKE UP NOZZLE. STAB ON WELL. PUMP E-LINE FORWARD. 05:00 - 05:30 0.50 BOPSUR P PRE PERFORM RIG EVAC DRILL WITH MEINHOLD CREW. PERFORM MR 05:30 - 06:30 1.00 BOPSUR P PRE TAKE INJECTOR OFF PJSM, PREPARE TO TEST E-LINE/MAKE UP BHI. 06:30 - 08:00 1.50 BOPSUR P PRE PRESSURE TEST CT CONNECTOR AND CABLE HEAD TO 300/3500 PSI,GOOD. MOVE INJECTOR OFF TO SIDE. INSTALL LUBRICATOR CONNECTION. VALVE CREW TESTS TORQUE ON TREE BOLTS. Printed 4/11/2016 1.39:46PM *All depths reported in Drillers Depths* • • F North America-ALASKA-BR;, Page 3 ate --//,/ r ° " Operation Summary Report d Common Well Name:15-45 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/26/2016 End Date:4/7/2016 X3-017P2-C:(3,846,961.00) Project:Prudhoe Bay i Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:4/8/1996 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA I UWI:500292267100 Active datum:Kelly Bushing/Rotary Table @68.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT j NPT Depth Phase Description of Operations - 10:30 2.50 BOPSUR P (usft) (hr) 08:00 PRE PJSM THEN LIFT BPV LUBRICATOR TO RIG FLOOR. PRESSURE TEST 300/3500 PSI IS GOOD. VALVE CREW VERIFIES FUSIBLE CAP INSTALLATION. OPEN UP WELL AND RETRIEVE TWC,ABOUT 1800 PSI ON WELL. BLEED OFF PRESSURE,REMOVE BPV LUBRICATOR AND OFFLOAD FROM RIG. 10:30 - 11:30 1.00 BOPSUR P PRE PJSM THEN M/U NOZZLE,GET ON WELL FOR PT OF CHECK VALVES AND RISER BREAK LOW PRESSURE TEST SHOWS RISING PRESSURE,LIKELY SWAB AND MASTER LEAKING WITH 1800 PSI BELOW. CALL GREASE CREW OUT TO GREASE VALVES. 11:30 - 12:00 0.50 BOPSUR N WAIT PRE WAIT ON GREASE CREW. KEEP COIL WARM WHILE WAITING. 12:00 - 13:00 1.00 BOPSUR P PRE GREASE CREWARRIVES,PJSM THEN GREASE TREE VALVES. PT CHECK VALVES AND RISER CONNECTION 300/3500 PSI,GOOD. 13:00 - 14:20 1.33 CONDHL P PRE PJSM FOR BULLHEAD KILLING WELL. GET ON WELL WITH INJECTOR,STINGER, CHECKS,NOZZLE. SPLIT PUMPS,KILL WELL WITH 3.3 BPM DOWN KILL LINE,1.7 BPM DOWN CT. LEAD WITH 5 BBLS MEOH FOLLOWED BY 290 BBLS 1%KCL. WHP IS 1800 PSI TO START. 10 MIN,69 BBLS AWAY,WHP=1827 PSI 20 MIN,107 BBLS AWAY,WHP=967 PSI 30 MIN,157 BBLS AWAY,WHP=1802 PSI 40 MIN,209 BBLS AWAY,WHP=1732 PSI 50 MIN,259 BBLS AWAY,WHP=1725 PSI 58 MIN,290 BBLS AWAY,WHP=1666 PSI. BLED IAAND OA ONCE DURING THE BULLHEAD,FROM 600 PSI TO 100 PSI. 14:20 - 15:00 0.67 STWHIP WEXIT SHUT DOWN AND WATCH WELL. FLOWS IIIII BACK ABOUT 1 BBL THEN ON VAC. ASSESS LOSS RATE,ABOUT 15-20 BBLS/HR. MOBILISE BTT TOOLS TO FLOOR,HIGH SIDE WHIPSTOCK. 15:00 - 16:10 1.17 STWHIP P WEXIT PJSM FOR M/U WHIPSTOCK BHA. M/U BHA#2,WHIPSTOCK AND MODELJ SETTING TOOL. BHA OAL=67.86 FT. INJECTOR ON AT 16:10. 16:10 - 19:05 2.92 STWHIP P WEXIT SET PUMP TRIPS TO 1000 PSI,OPEN EDC I AND START FILLING WELL THROUGH CT. ZERO COUNTERS,TEST TOOL AND QTS,RIH. LINE UP RETURNS THROUGH THE MGS FOR !THE FIRST TRIP IN. ORIENT 135°TFO. RIH THROUGH LINER TOP WITHOUT ISSUE 119:05 - 20:01 0.93 STWHIP P WEXIT LOG TIE IN TO FORMATION +2'CORRECTION LOG CCL LOG ACROSS SETTING AREA. COLLARS CAME IN WERE THEY SHOULD Printed 4/11/2016 1 39 46PM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 4.pt.QQ •• Operation Summary Report Common Well Name. 15-45 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:3/26/2016 End Date:4/7/2016 X3-017P2-C:(3,846,961.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time.4/8/1996 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292267100 Active datum:Kelly Bushing/Rotary Table @68.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:01 - 20:15 0.23 STWHIP P WEXIT PU TO SETTING DEPTH OF 9628.75(BOTTOM OF WHIPSTOCK) NEUTRAL WEIGHT CLOSE EDC. PRESSURE UP AND SET WHIPSTOCK AT 9620'TOP OF WHIPSTOCK VERIFY SET BY STACKING 4K. PICK OFF CLEAN 20:15 - 00:00 3.75 STWHIP P WEXIT SWAP WELL OVER TO 9.5 PPG MUD DYNAMIC LOSSES 50-60 BPH ONCE MUD AROUND. DISCUSS WITH ODE AND GET MORE FLUID COMING. DECISION TO PUMP POLYSWELL PRIOR TO MILLING WINDOW. MOBILIZE MUD ENGINEER FOR PREPARING POLYWELL POOH 3/29/2016 00:00 - 00:45 0.75 STWHIP P WEXIT PERFORM 10 MIN FLOW CHECK. WELL LOSING ABOUT 3 BPH AT SURFACE. 00:45 - 01:45 1.00 STWHIP P WEXIT FLUSH BHA WITH WATER. LAY DOWN BHA. 01:45 - 02:30 0.75 STWHIP P WEXIT STAB NIGHT CAP. PERFORM INJECTIVITY TEST -2 BPM @ 620# -3 BPM @ 1100# -4 BPM @ 1340# -5 BPM @ 1500# 02:30 - 08:30 6.00 STWHIP N DPRB WEXIT PREPARE PITS/PULL SCREENS OUT OF 1PUMP TOOL SERVICE BRINGING OUT POLYSWELL FROM MI PLANT. DISCUSS WITH ODE. VERBAL TO GO FORWARD. PULL PUMP SCREEN OUT OF PUMP 2 PIT#4, 20 BBLS FRESHWATER. 2 BKTS POWERVIS L, 4(50#SACKS)KCL AGITATE. -PIT#5, 20 BBLS FRESHWATER SPACER. 08:30 - 10:00 1.50 STWHIP N :DPRB WEXIT 1 PJSM WITH CREWS FOR PUMPING POLYSWELL. PUMP 22 BBLS POLYSWELL AT 11#/BBL FOLLOW WITH 20 BBLS FRESH WATER AND 105 BBLS MUD. THIS LEAVES 10 BBLS OF POLYSWELL ABOVE THE LINER LAP. POLYSWELL MIXED AT 0844 IN PLACE AT 0930. AFTER PUMPING ALLOW WHP TO BLEED DOWN FOR 30 MIN TO LET POLYSWELL WORK. Printed 4/11/2016 1.39:46PM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 5 - • Operation Summary Report Common Well Name:15-45 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.3/26/2016 End Date:4/7/2016 X3-017P2-C:(3,846,961.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:4/8/1996 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI.500292267100 Active datum:Kelly Bushing/Rotary Table @68.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:10 1.17 STWHIP N DPRB WEXIT AFTER 30 MIN WHP HAS BLED DOWN TO 70 PSI. SLOWLY PUMP DOWN CTA TOTAL OF 3.2 BBLS,7 BBLS REMAINING ABOVE LINER TOP. GET TO 820 PSI WHP LEVELLING OFF. SHUT DOWN AND LET IT SWELL,WHP SLOWLY BLEEDING OFF. BLEEDS OFF TO 240 PSI AFTER 20 MIN. PUMP IT BACK UP 950 PSI,TOTAL OF 6 BBLS SQUEEZED 4 BBLS REMAINING ABOVE LINER LAP. ALLOW WHP TO BLEED DOWN SLOWLY. AFTER 20 MIN WHP HAS BLED DOWN TO 460 PSI. PUMP 1 BBLS OUT,BUILD TO 1000 PSI WHP. LEAVES 3 BBLS REMAINING ABOVE LINER TOP. SHUT DOWN AND ALLOW PRESSURE TO BLEED OFF. AFTER 15 MIN PRESSURE HAS BLED OFF TO 604 PSI. 11:10 12:00 0.83 STWHIP P WEXIT BLEED OFF WHP SLOWLY FROM 604 PSI TO ZERO,CIRC THROUGH OPEN CHOKE AND ASSESS LOSS RATE. NO LOSSES. DISCUSS WITH ODE,WILL P/U MILLING BHA. 10 MIN PUMPS OFF FLOWCHECK IS GOOD, NO FLOW. PJSM THEN M/U BHA#4,WINDOW MILL. MILL AND STRING REAMER ARE 2.74 GO,2.73 NO-GO. WHILE M/U BHA,CONDUCT KICK DRILL WITH MEINHOLD CREW. BOP HORN SOUNDS WITH BHI TOOLS IN THE STACK. BHA IS TOO LONG TO PICK ABOVE THE STACK,CREW PICKS UP SAFETY JOINT AND STABS IT,MAKES IT UP. CONDUCT AAR. 12:00 - 14:30 2.50 STWHIP P WEXIT INJECTOR ON AT 12:30. ZERO COUNTERS,TEST QTS AND BHI TOOL, OPEN EDC. RIH. 14:30 - 15:30 1.00 STWHIP P WEXIT TIE-IN DEPTH FROM 9460 FT. CORRECT+2.5 FT. TAG WHIPSTOCK AT 9620 FT. PICK UP AND INCREASE PUMP 1.55/1.55 BPM @ 2930 PSI FREE SPIN. EASE DOWN AND START TIME MILLING WINDOW FROM 9619.5 FT. 15:30 - 16:00 0.50 STWHIP P WEXIT MILL WINDOW 9619.6 FT. 1.55/1.55 BPM AT 3025 PSI,ECD=9.90. ..IGG 9.45/9.10 PPG IN/OUT. �'7 15 'J4 4/ GETTING SOME LIGHTER MUD AND POLYSWELL COMING BACK,RESIDUAL WATER FROM THE POLYSWELL PILL MIXED IN WITH THE MUD. 16:00 - 17:00 1.00 STWHIP P WEXIT MILL WINDOWAT9620FT. 1.55/1.43 BPM AT 3360 PSI. 9.52/9.38 PPG IN/OUT. ECD=10.11 PPG,PVT=319 BBLS. IA/OA=93/129 PSI. Printed 4/11/2016 1.39:46PM `All depths reported in Drillers Depths" • • North America ALASKA BP ;x' Page 6 Operation Summary Report Common Well Name 15-45 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/26/2016 End Date:4/7/2016 X3-017P2-C:(3,846,961.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:4/8/1996 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292267100 Active datum:Kelly Bushing/Rotary Table©68.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 19:00 2.00 STWHIP P WEXIT MILL WINDOW AT 9622.5 FT. 1.54/1.38 BPM AT 2970 PSI. 9.39/9.33 PPG IN/OUT. ECD=10.00 PPG,PVT=287 BBLS. IA/OA=112/258 PSI. 19:00 - 21:00 2.00 STWHIP P WEXIT MILL WINDOWAT 9624.5 FT. 1.54/1.42 BPM AT 2890 PSI. 9.36/9.33 PPG IN/OUT. ECD=9.96 PPG,PVT=275 BBLS. IA/OA=125/292 PSI. 21:00 - 22:30 1.50 STWHIP P WEXIT MILL WINDOW TO BOTTOM OF WINDOW AT 9225 FT;CONTROL MILL TO 9626 FT FOR FULL REAMER EXIT. 11.54/1.45 BPM AT 2890 PSI. 9.37/9.32 PPG IN/OUT. ECD=9.95 PPG,PVT=267 BBLS. IA/OA=128/315PSt. 22:30 - 00:00 1.50 STWHIP P WEXIT MILL RAT HOLE TO 9631 FT. 1.54/1.44 BPM AT 3000 PSI 9.37/9.32 PPG IN/OUT. ECD=9.95 PPG,PVT=255 BBLS. IA/OA=132/330 PSI. 3/30/2016 00:00 - 01:45 1.75 STWHIP P WEXIT :_MILL RAT HOLE TO 9635 FT. 1.54/1.41 BPM AT 3000 PSI 9.36/9.31 PPG IN/OUT. ECD=9.94 PPG,PVT=242 BBLS. IA/OA=138/353 PSI. TD SAMPLE SHOWS-75%SANDSTONE WITH HIGH CHERT CONTENT 01.45 - 03:15 1.50 STWHIP P WEXIT REAM WINDOW -MAKE 3X REAMING PASSES FROM 9615'TO 9630' -DRY DRIFT WINDOW(CLEAN DRIFT) -FLOW CHECK 03:15 - 05:00 1.75 STWHIP P WEXIT POH WITH MILL ASSEMBLY. UNABLE TO OPEN EDC. -PULL ABOVE LINER TOP AND POH AT 100 FPM -IN I OUT RATE=1/0.65 BPM -IN/OUT DENSITY=9.37/9.31 PPG 05:00 - 07:00 2.00 STWHIP P WEXIT CONDUCT PJSM FOR L/D BHA WHILE POOH. TRIP SHEET IS-8 BBLS TO THIS POINT. NEAR SURFACE,10 MIN PUMPS OFF FLOWCHECK IS GOOD,NO FLOW. TAG STRIPPER AND L/D BHA. INJECTOR OFF AT 05:40. MILL AND REAMER ARE 2.74 GO,2.73 NO-GO. M/U BHA#5,BUILD ASSEMBLY. 3.25'HYC DURAFORCE BIT WITH 1.98 DEG AKO ULS MOTOR AND RES. BHA OAL=70.26 FT. INJECTOR ON AT 06:40. 07:00 - 09:15 2.25 DRILL P PROD1 ZERO COUNTERS,TEST BHI TOOL AND QTS, OPEN EDC. RIH. TIE-IN DEPTH,CORRECT+2 FT. Printed 4/11/2016 1.39:46PM *AII depths reported in Drillers Depths* (TREE= CM/WELLHEAD= FMC SAFETY NOTES: WELL ANGLE >70°@ 9820'*** ACTUATOR= BAKER CITI15-45C M GLEG:24.7°@ 9640'***PREVIOUS • INITIAL KB.ELE 68.06' I I W�RES NOT SHOWN*** BF.ELEV= KOP= 931' , 2118' H4-1/2"HES X NP,D=3.813" Max Angle= 92°@ 10481' DatumMD= N/A Datum TVD= 8800'SS GAS LIFT MANDRELS il ST MD TVD DEV TYPE VLV LATCH PORT DATE 9-5/8"CSG,40#,L-80 BTC,D=8.835" 3829' 4 3355 3157 32 KBG-2 DMY BK 0 10/27/15 3 5561 5012 35 KBG-2 DMY BK 0 10/27/15 2 7436 6596 26 KBG-2 DMY BK 0 05/14/05 Minimum ID =2.377" @ 10579' 1 8846 7899 19 KBG-2 DMY BK 0 05/14/05 3-3/16 X 2-7/8" XO a 8915' -14-1/2"HES X NP,D=3.813" ►�� 8936' -17"X 4-1/2"BKR S-3 FKR,D=3.875" 8959' -14-1/2"HES X NP,D=3.813" TOP OF 3-1/2"LNR --L 9003' - 9003' -13.70"DEPLOYMENT SLV,D=3.00" F' 9024' H3-1/2"OTIS X NP,D=2.812" 4-1/2"TBG, 12.6#,13CR-80 VA TOP, -1 9022' .0152 bpf,D=3.958" II . r 9057' 3 1/2"X 3-3/16,D=2.786" 4-1/2"TBG STUB(DNS 05/13/05) -1 9023' 1' ;I► 9032' H7"X 4-1/2"UNIQUE OVERSHOT 3-1/2"LNR,9.3#,L-80 STL, -I 9057' �� 9056' H 7"X 4-1/2"BKR S-3 PKR,ID=3.875" J .0087 bpf,D=2.992" E3EHIND Ill 0 9079' -14-1/2"HES X NP,D=3.812" CT LNR t 9090' -i 7"X 4-1/2"TBR w/8'PBR,ID=3.881" TOP OF 4-1/2"LNR 9090' E'��, 00.>° 3 9091' -4-1/2"WLEG,D=3.958" 4-1/2"TBG, 12.6#,L-80 BTC-M, -{ 9091' fs 9100' -{7"X 4-1/2"BKR LIP w/HGR,ID=3.92" .0152 bpf,D=3.958" t(}. t i. 7"CSG,26#,L-80 BTC-M,ID=6.276" -{ 9258' , 4-1/2"WHPSTOCK(12/16/13) -1 9286' r 4-1/2"LNR,12.6#,L-80 NSCT,.0152 bpf,ID=3.958" -1 -9286' # MLLOUT WIDOW(15-45C) 9286'-9295' I 3-3/16"MONOBORE WHPSTOCK(03/28/16) - 9620' 04-a 10150'CTM H3-1/4"BKR CPP(02/04/16) 3-1/4"LNR,6.6#,L-80 TC11,.0079 bpf,ID=2.85" H 10578' 4► 10578' -13-3/16"X 2-7/8,ID=2.377" i 10611' -12-7/8"PUP MARKER JOINT w/RA TAGS(01/02/14) PERFORATION SUMMARY AI,..,d, :VI ME REF LOG:BKR RPM ON 01/06/14 4 iii ANGLE AT TOP PERF:89°@ 11050' F41 F 111,74 Note:Refer to Production DB for historical perf data MO 11423' FISH:BOT DISCONNECT w/HYDR 05 SETTING *10 SIZE SPF NTERVAL Opn/Sqz SHOT SQZ TOOL(03/06/14) -SEE PAGE 2 FOR PERFORATION SUMMARY *4 1 IP 11430' -12-7/8"BOT CIBP(03/06/14) 4 4 F PBT° H 12743' 61 ;,.x; 141 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,ID=2.441" -I 12750' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/04/96 D-14 INITIAL COMPLETION 02/14/14 RKT/JMD SET 45 KB LTP(02/08/14) WELL: 15-45C 09/09/00 NORDIC 1 CTD SIDETRACK(15-45A) 02/14/14 DLWJMD GLV GO(02/09/14) PERMIT:"`2131400 05/15/05 D-16 RWO 03/19/14 LLVJMD CIBP/FISWADFERFS(03/11/14) API Nb: 50-029-22671-03 02/16/08 NORDIC 1 CTD SIDETRACK(15-45B) 11/06/15 DJS/JMD PULLED LTP-GLV GO(10/27/15) SEC 22,T11N,R14E,530'FWL&100'FVVL 01/09/14 NORDIC 1 CTD SIDETRACK(15-45C) 02/12/16 JTM/JMD SET BKR CDP(02/04/16) 01/31/14 JN/JMD LNR TALLY DEPTH CORRECTION BP Exploration(Alaska) • 15-450 41 • i [I II 1 I ii iiw 1. I .. I1 PERFORATION SUbMARY +1 . REF LOG:BKR RPM ON 01/06/14 ANGLE AT TOP PERF: 89"011050' I► Note:Refer to Production DB for historical pert data SIZE 5FF INTERVAL Opn/Sqz SHOT SOZ 2" 6 11050-11080 C 03/11/14 2" 6 11090-11120 C 03/11/14 2" 6 11130-11160 C 03/11/14 '4 ♦4 2" 6 11170-11200 C 03/11/14 P' 2" 6 11230-11260 C 03/11/14 :. kl! 2" 6 11300-11330 C 03/11/14 2" 6 11340-11370 C 03/11/14 2" 6 12160-12410 C 01/07/14 in 2" 6 12440-12560 C 01/07/14 :IF nal 2" 6 12620-12740 C 01/07/14 ': ; : h 1i DATE REV BY COMvUffS DATE REV BY COMM3VTS FRUDHOE BAY UNIT 05/04/96 D-14 INITIAL COMPLETION 02/14/14 RKT/JMD SET45 KB LTP(02108/14) WE..L: 15-45C 09/09/00 NORDIC 1 CTD SIDETRACK(15-45A) 02/14/14 DLWJMD GLV 00(02/09/14) PERMIT:"2131400 05/15/05 D•16 RNO 03/19/14 LLI/JM) CBFYFISWADPERFS(03/11/14) AR No: 50-029-22671-03 02/16/08 NORDIC 1 CTD SIDETRACK(15-45B) 11/06/15 DJS/JMD PULLED LTP--GLV C/0(10/27/15) SEC 22,T11N,R14E,530'FWL&100'FWL 01/09/14 NORDIC 1 CTD SIDETRACK(15-45C) 02/12/16 JTMJMD SET BKR CEP(02/04/16) 01/31/14 JWJMD LNR TALLY DEFFH CORRECTION BP Exploration(Alaska) . or Thr • • \ I%%ic, THE STATE Alaska Oil and Gas r�. ALAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 44 ALA91°.- Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen Engineering Team Lead t BP Exploration(Alaska), Inc. � i rte `�s P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-45C Permit to Drill Number: 213-140 Sundry Number: 316-037 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, Cathy . Foerster Chair St DATED this day of January, 2016. RBDMS 1,,., JAN 2 5 2016 STATE OF ALASKA "'ALASKA OIL AND GAS CONSERVATION COMMA N APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tabing ❑ Change Approved Program ❑ Plug for Redrill p " Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 213-140 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory C:1 Development I1 6. API Number: 50-029-22671-03-00 - 99519-6612 Stratigraphic LI Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No I7f PBU 15-45C - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028306 - PRUDHOE BAY,PRUDHOE OIL - (u lis / ll2" 11. PRESENT WELL CONDITION SUMMARY / Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): Ns 12750" 8808 - 11430 8758 2532 11430 11423 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 36-116 36-116 1490 470 Surface 3795 9-5/8" 36-3831 36-3556 5750 3090 Intermediate 9226 7" 33-9260 33-8289 7240 5410 Liner 196 4-1/2" 9090-9286 8128-8313 8430 7500 • Liner 3747 3-1/2"x 3-1/4"x 2-7/8" 9003-12750 8046-8808 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11050-12740 8755-8807 4-1/2"12.64 13Cr80/L-80 31 -9092 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8946/7993 4-1/2"Baker S-3 Packer 9057'/8097 12.Attachments: Proposal Summary p Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch IA Exploratory ❑ Stratigraphic ❑ Development II ' Service ❑ 14.Estimated Date for Commencing Operations: February 5,2016 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended El- 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Ciolkosz,Ryan R be deviated from without prior written approval. Email Ryan.Ciolkosz@bp.com Printed Name J• •-Mc Title Engineering Team Lead 40 Signature Phone +1 907 564 4711 Date / /?/ COMMISSION USE ONLY Condit!• of approval:Notify Commission so that a representative may witness Sundry Number: 3\(..A. _ 03-7 Plug Integrity ❑ BOP Test El Mechanical Integrity Test 0 Location Clearance,❑ Other: BQ p re-5f fiv SUL -) I' (/,pS P 7'S Z53z p515 �dtwr -�Pi_vq` p ace-ice �1ayp122tii� q/ ��r e2v. 2S- H Z C Post Initial Injection MIT Req'd? Yes❑ " No 0 Spacing Exception Required? Yes 0 No a/ Subsequent Form Required: /b -- 4 v 1 2,7_ / /6 Approved by: ;a6 � COMMISSIONER APPROVED BYTHE COMMISSION Date:I U— vr 1/ 0/11, ORIGINAL ... ,,7--D-4, IIRRQQ �� JAN 2 5 201 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the d'a`i1y`Cf4l. tachments in Duplicate • • To: Alaska Oil &Gas Conservation Commission From: Ryan Ciolkosz b CTD Engineer Date: January 5, 2016 Re: 15-45C Sundry Approval Sundry approval is requested to plug the 15-45C wellbore as part of the drilling and completion of the proposed 15-45D CTD sidetrack. History and current status: Parent well 15-45C was completed in 2014 as a 2500' horizontal with 490' Z1A perforations. Significant structural uncertainty complicated the drilling of this well and the well results were disappointing. The well was drilled in the top of 1A, lower 1B and at one point the well encountered Z2 sand. When the well pop'd it went straight to gas, initial rates were 620 bopd and 54 mmscf/d and within days the well was above 90,000 gor. Additional EOL adperfs were pursued, giving up standoff to gas, to try and get some production from the well but the well remains above MGOR. There is no remaining value for this well. Proposed plan: Drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or around July 10th, 2016. CTU to set CIBP to isolate the 15-45C perfs Nordic 2 will a mill a 2.74"window in the 3-1/4" liner and drill a Zone 1 well to —12,175 MD. The lateral will be completed with a 2-3/8" L-80 liner which will be cemented and perforated. This Sundry covers plugging the existing 15-45C perforations via the 15-45D liner cement job or liner top packer set post-rig (alternate plug placement per 20 AAC 25.112(i)) and via CIBP. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. • • , Pre-rig CTU: 1. MU and RIH with a drift assembly suitable for a Baker 3-1/4" CIBP. a. CTMD can be used to tie in as depth control is not critical and TCII is a flush joint connection. b. Kill well as necessary. c. Baker 3-1/4" CIBP is a 2.562" OD tool. Drift ID of 3-1/4" pipe is 2.75" OD. 2. Drift to 10200' MD. 3. MU and RIH with a 3-1/4" Baker CIBP. 4. Load and kill well with 220 bbls of 1% KCI followed by 38 bbls of 60/40 meth. Pump at max rate to flush the gas from the wellbore so that the well is liquid packed when the CIBP is set. 5. Set CIBP at—10150' MD. 6. Keep hole full by pumping 60/40 meth down the backside while POOH. 7. MU and RIH with a drift for a Baker 3-3/16" Monobore whipstock(Baker to provide drift assembly). 8. Drift to the CIBP and tag CIBP. 9. Keep hole full by pumping 60/40 meth down the backside while POOH. Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,532 psi. 2. Mill 2.74"window plus 10' of rathole. Swap the well to 9.5 ppg drilling mud. 3. PU drilling BHA with GR/Resistivity 4. Drill 3.25" hole to TD at—12,175' MD 5. Run 2-3/8" L-80 liner leaving TOL at—8,976 MD. 6. Pump primary cement bringing TOC to TOL, 17.4 bbls of 15.3 ppg liner cmt planned* 7. Test liner lap to 2,400 psi. 8. Perforate liner per asset instructions 9. Freeze protect well, RDMO Post Rig: 1. V: Tree work as necessary. 2. S: Drift. GLV's. LTP if necessary.* 3. F: Pressure test Liner top packer. 4. Contingent adperf if no flow *Approved alternate plug placement per 20 AAC 25.112(i) Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka TREE= CSN • SeY NOTES: WELL ANGLE >70°@ 9820'*** WELLHEAD= FMC 15-4 5 C MAX DOGLEG:24.7°@ 9640'***PREVIOUS ACTUATOR= BAKER C INITIAL KB.ELE 68.06' I I WELLBORES NOT SHOWN*** BF.ELEV= ? KOP= 931' I 2118' —14-1/2"HES X NP,D=3.813" Max Angle= 92°©10481' Datum MD= N/A Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD H DEV TYPE VLLATCH PORT DATE 9-5/8"CSG,40#,L-80 BTC,113=8.835" H 3829' 4 3355 3157 32 KBG-2 DMY BK 0 10/27/15 3 5561 5012 35 KBG-2 DMY BK 0 10/27/15 2 7436 6596 26 KBG-2 DMY BK 0 05/14/05 Minimum ID =2.377" @ 10579' 1 8846 7899 19 KBG-2 DMY BK 0 05/14/05 3-3/16 X 2-7/8" XO I 8915' H4-1/2"HES XNP,D=3.813" 8936' —I 7"x 4-1/2"BKR S-3 PKR,D=3.875" ' 8959' —14-1/2"HES XNP,D=3.813" TOP OF 3-1/2"LNR — 9003' --I 9003' —13.70"DEPLOYMENT SLV,D=3.00" N} 9024' H3-1/2"OTIS X NP,D=2.812" 4-1/2"TBG,12.6#,13CR-80 VA TOP, 9022' w. 0152 bpf,ID=3.958" /�.� � 9057' —13-1/2"X 3-3/16,D=2.786" 4-1/2"TBG STUB(DIMS 05/13/05) 9023' M i `` 9032' —17"X 4-1/2"UNIQUE OVERSHOT 3-1/2"LNR,9.3#,L-80 SR, —1 9057' loI, 9056' H7"X 41/2"BKR S-3 PKR,D=3.875" EHIND .0087 bpf,D=2.992" 9079' —41/2"HES X NP,D=3.812" ttii M CT LNR U � L 9090' --17"X 4-1/2"TBR w/8'PB R D=3.881" TOP OF 4-1/2"LNR 9090' F� ,41" 9091' —14-1/2"WLEG,D=3.958" 4-1/2"TBG,12.6#,L-80 BTC-M, 9091' MF by 9100' 7"X 4-1/2"BKR LTP w/HGR,ID=3.92" .0152 bpf,ID=3.958" t t 7"CSG,26#,L-80 BTC-M,ID=6.276" —1 9258' , L 4-1/2"WHPSTOCK(12/16/13) —, 9286' 4-1/2"LNR,12.6#,L-80 NSCT,.0152 bpf,D=3.958" —1 -9286' � t MLLOUT WINDOW(15-45C) 9286'-9295' t M 1 F` p F 3-1/4"LNR,6.6#,L-80 TC11,.0079 bpf,ID=2.85" —1 10578' P 10578' —3-3/16"X 2-7/8,D=2.377" i 41 III, •41 •!. 10611' -12-7/8"PUP MARKER JONYT w/RA TAGS(01/02/14) • iii PERFORATION SUMMARY REF LOG:BKR RPM ON 01/06/14 ANGLE AT TOP PERF:89°@ 11050' 4 Note:Refer to Production DB for historical perf data � 11423' FISH:BOT DISCONNECT w/HYDR 05 SETTING SIZE SPF /YTERVAL Opn/Sqz SHOT SQZ W . TOOL(03/06/14) -SEE PAGE 2 FOR PERFORATION SUMMARY- 4 '. 11430' —12-7/8"BOT CBP(03/06/14) F• 41 PBTD 12743' '0 2-7/8"LNR,6.5#,L-80 SIL, .0058 bpf,ID=2.441" —{ 12750' •I DATE REV BY COMMENTS DATE REV BY COM IE NTS PRUDHOE BAY UNIT 05/04/96 D-14 INITIAL COMPLETION 02/14/14 RKT/JMD SET 45 KB LTP(02/08/14) WELL: 15-45C 09/09/00 NORDIC 1 CTD SIDETRACK(15-45A) 02/14/14'DLWJMD GLV GO(02/09/14) PERMIT:'2131400 05/15/05 D-16 RWO 03/19/14 LLVJMD CBP/FISWADFERFS(03/11/14) API No: 50-029-22671-03 02/16/08 NORDIC 1 CTD SIDETRACK(15-45B) 11/06/15 DJS/JMD RILED LTP-GLV GO(10/27/15) SEC 22,T11 N,R14E,530'FWL&100'FWL 01/09/14 NORDIC 1 CTD SIDETRACK(15-45C) 01/31/14 JWJMD LNR TALLY DEPTH CORRECTION BP Exploration(Alaska) • 15-45C • I] _ [ 4. z ii , aa w _ ►_ PERFORATION SUMMARY REF LOG:BKR RPM ON 01/06/14 .4 ANGLE AT TOP PERF: 89°@ 11050' 4 4. Note:Refer to Production DB for historical pert data ,j • SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2" 6 11050-11080 0 03/11/14 2" 6 11090-11120 0 03/11/14 4. • . 2" 6 11130-11160 0 03/11/14 a. • . 2" 6 11170-11200 0 03/11/14 4 F 2" 6 11230-11260 0 03/11/14 • • 2" 6 11300-11330 0 03/11/14 2" 6 11340-11370 0 03/11/14 _ 2" 6 12160-12410 C 01/07/14 va 2" 6 12440-12560 C 01/07/14 fr 2" 6 12620-12740 C 01/07/14 . a ill 44 , O iii) DATE . REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 05/04/9 D-14 INITIAL COMPLETION 02/14/14 RKT/JMD SET 45 KB LTP(02/08/14) V ELL: 15-45C 09/09/00 NORDIC 1 CTD SIDETRACK(15-45A) 02/14/14 DLWJMD GLV CIO(02/09/14) PBRMfT: 1131400 05/15/05 D-16 RWO 03/19/14 LLVJMD CBPYPISWADPERFS(03/11/14) API No: 50-029-22671-03 02/16/08 NORDIC 1 CTD SIDETRACK(15-45B) 11/06/15 DJS/JMD PULLED LTP-GLV C/O(10/27/15) SEC 22,TUN,R14E,530'FVVL&100'FVVL 01/09/14 NORDIC 1 CTD SIDETRACK(15-45C) 01/31/14 JWJMD L/42 TALLY DEPTH CORRECTION BP Exploration(Alaska) TREE= CNV ilk NOTES- 70* WELLEEAD= FMC If-4 51) P Yo o se d M GLq WELL AN GLE40' ..PREVIOUS 0,"*" ACTUATOR= BAKER C y NT1AL KB.ELE 68.06' I II WELLBORES NOT SHOWN"` BF.ELEV= KOP= 931' a 2118' 4-112"HES X NP,D=3.813" Max Angle= 92°@ 10481' Datum KO= WA Datum TVD= 8800'SS GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9-5/8'CSG,40#,L-80 BTC,D=8.835" — 3829' 4 3355 3157 32 KBG-2 ( ' BK 0 10/27/15 3 5561 5012 35 KBG-2 l W BK 0 10/27/15 2 7436 6596 26 KBG-2 DM1Y BK 000 05/14/05 Minimum ID =2.377" @ 10579' 1 8846 7899 19 KBG-2 DM1Y BK 0 05/14/05 3-3/16 X 2-7/8" XO ' 8915' H4-1/2"HES X NP,D=3.813" 171 8936' Hr X 4-1/2'BKR S-3 PKR D=3-875" 8959' --i4-1/2"HES X NP,D=3-813" 3.7"BKR DEPLOY SLV,D=3.00"@ 8976 TOP OF 3-1/2'LNR H 9003' ( it! _, 9003' H3.70"DEPLOYMENT SL V,ID=3.00' i 119024' —{3-112"OTtS X NP,D=2.87 2' 4-1/2'TBG,12.6#,13CR-80 VAM TOP, 9022' .0152 bpf,D=3.958" /I•• 1 9057' H3-112"X 3-3/16, 0=2.786' ` 4-1/2"TBG STUB(DMS 05/13/05) 9023' F 9032' _—{T X 4-1/2"UNIQUE OVERSHOT 9056' _—17"X 4-1/2"BKR S-3 R<R D=3.875" 3-112'LNR 9.3#,L-80 STL, H 9057' �t ►� E3EHIND .0087 bpf,D=2.992' 9Q79' —14-1/2"HES X NP,13=3.812' CT LNR / ' i.--i{ 9090' 7"X 4-1/2'TBR w/8'PBR 13=3.881 1 TOP OF 4-112'LNR H 9090' ,' ►M4 9091' —14-12'WLEG,D=3.958" 4-1/2"TBG, 12.6#,L-80 BTC-M — 9091' i 9100• —7"X 4-1/2'BKR LIP/HGR,D=3.92" .0152 bpf,D=3.958" .' 7"CSG,26#,L-80 BTC-M,13=6.276' — 9258' PERFORATION SUMMARY REF LOG BKR RPM ON 01/06/14 4-1/2'WHPSTOCK(12/16/13) —{ 9286' 1 ANGLE AT TOP PERF 89". 11050' Note'Refer to Productaan DB for hntortcal pert data SIZEI SPF l INTERVAL I Opn/Sqz I SHOT I SOZ 4-1/2"LNR, 12.6#,L-80 NSCT,.0152 bpf,13=3.958' —{ —9286' -SEE PAGE 2 FOR PERFORATION SUMMARY- o M N.LO UT WINDOW(15-15C) 9286'-9295' 3-3/16"M onobore W hipsmck @ 9549' ilk 3 1/4"CIBP @ 10,150' '.I• 0 3-1/4"LNR 6.6#,L-80 TC11,.0079 bpf,D=2.85" — 10578' lir ■ 10578' —{3-3116"X 2-7/8,D=2.377" tis RA Tag 2-3/8"4.7#L-80 Liner@ 12,175' . 10611' H2-718'PUP MARKER JOINT w/RA TAGS(01/02/14) o 0 ''1J1f `f"� 11423' —FISH BOT DISCONNECT w/HY DR 05 SEI I ING i 1 I TOOL(03/06/14) ``'' 11430' —2-7/8'BOT CUP(03/06/14) 0:1 INIIR3TD —I 12743' I 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,D=2.441" —{ 12750' ' DATE REV BY COP U'ffS DATE REV BY COM ENTS PRUDHOE BAY UNIT 05/04/96 D-14 INITIAL COMPLETION 02/14/14 RKT/JMD SET 45 KB LTP(02/08/14) WELL: 15-45C 09/09/00 NORDIC 1 CTD SIDETRACK(15-45A) 02/14/14 DLWJMD GLV C/0(02/09/14) PERNIT:'2131400 05/15/05 D-16 RWO 03/19/14 LLVJMD CIBP/FISWADPERFS(03/11/14) AR ND: 50-029-22671-03 02/16/08 NORDIC 1 CTD SIDETRACK(15-45B) 11/06/15 DJS/JMD PULLED LTP-GLV C/O(10/27/15) SEC 22,T11N,R14E,530'EVA&100'RM. 01/09/14 NORDIC 1 CTD SIDETRACK(15-45C) 01/31/14 JWJMD LNR TALLY DEPTH CORRECTION BP Exploration(Alaska) • 15-45C I . ".11P 411 :(> 4 _ sZ ■ PERFORATION SUMMARY REF LOG:BKR RPM ON 01/06/14 ANGLE AT TOP PERF: 89"@ 11050' Note:Refer to Production DB for historical perf data SEE SPF WTERVAL Opn/Sqz SHOT SQZ 2' 6 11050- 11080 0 03/11/14 2" 6 11090- 11120 0 03/11/14 2" 6 11130- 11160 0 03/11/14 2" 6 11170-11200 0 03/11/14 2" 6 11230- 11260 0 03/11/14 2" 6 11300-11330 0 03/11/14 2" 6 11340-11370 0 03/11/14 2" 6 12160-12410 C 01/07/14 .®. 2" 6 12440-12560 C 01/07/14 2" 6 12620- 12740 C 01/07/14 .•4, /4, N DATE REV BY COMuEffS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/04/96 1114 INITIAL COMPLETION 02/14/14 RKT/.MD SET 45 KB LTP(02/08/14) WELL: 15-45C 09/09100 NORDIC 1 CTD SIDETRACK(15-45A) 02/14/14 DLHCIMD GLV C!O(02/09/14) PERAK:"2131400 05/15/05 D-16 RWO 03/19/14 LLVJMO CBPIFISWADPERFS(03/11/14) API Na. 50-029-22671-03 02/16/08 NORDIC 1 CTD SIDETRACK(15-45B) 11/06/15 DJS/JMI) PULLED LIP-GLV C/O(10/27/15) SEC 22,T11N,R14E,530'FWL&100'FIM_ 01/09/14 NORDIC 1 CTD SIDETRACK(15-45C) 01/31/14 JN/JM) LIC TALLY DEPTH CORRECTION BP Exploration(Alaska) 1 I L I 1 1 1 1 8 g 3 .6 1 EiLk I x< x \ 1 MI I mu I nal A 1�4 1 ° =f 1014 I:4 c - a al 1 1 4110010 I: , A 1 • iim1 .; eau t I I II fY ►I 0i t i i 1 0 I.' I 1 a 0. I I Q s I .. t JO V 1 it �.. 1 IL �� I 1 Z tp 1 mut . ' Q 1 1 p, 1 a • r. 1 Z Z' Mt 1 1 I g 5 I " F F fF F � gI I • ° 1 V 'ri. H 1 I \ 1 . Z. CL 1 1 \ v ' y 1 F 1 w 1 I j • • ill .2 s i \ ;1m I 1 ... ••• .2 2 t \‘ Ilt I re 1 pil ;u; sir" .r' cZ O� 1 1 �r ri O Y • a; i \ 1 U9 a illr•• � U o \\ 11 t. NW F 4 4 != v \ !, �' 1 Z I I F. . f'� 0. g0-- p 5 E €\ MI 1 F 4_9--` - Q " t e I F 'x„ x I /2 U i 1 / .- 2 a r U $ \. - a00` U p o f g I ' I IowI I • �z 1 I a u,m !• 1 fn a�3 •E U I 2g I I I U a i x 1 • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist , d in the upper left corner of Form 10-403 is checked. If theAbandon" or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed GeologistAl) work) the initial reviewer will cross out that erroneous entry and initial then 1/ it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code,they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: 15-45C + PB1 PTD: 213-140 API: 50-029-22671-03-00 (15-45C) 50-029-22671-74-00 (15-45CPB1) FINAL LWD FORMATION EVALUATION LOGS (12/13/2013 to 01/02/2014) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) SFTP Transfer - Data Main Folders: SFTP Transfer - Data Sub-Folders: Please include current contact information if different from above. T39397 T39398 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.12 14:31:12 -08'00'
