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209-080
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM! • WELLIItMPLETION OR RECOMPLETION REPO AND LOG 1 a. Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 ' Suspended 0 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development p Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Zero Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 5/2/2016 • 209-080- 315-648 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 9/7/2009 50-029-21545-01-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number 9/19/2009 PBU 04-33A Surface: 678'FSL,304'FWL,Sec.26,T11N,R15E,UM ' 9 KB Ref Elevations 17. Field/Pool(s): 51.25 ' 1471'FSL,716'FWL,Sec.24,T11N,R15E,UM GL 21 PRUDHOE BAY,PRUDHOE OIL - Top of Productive Interval: BF 24.26 Total Depth: 3953'FSL,998'FEL,Sec.23,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 15233'/8656' ADL 028324&028323 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 713115 y- 5952558• Zone - ASP 4 • 15925'/8651' 70-039 TPI: x- 718623 y- 5958792 Zone - ASP 4 12. SSSV Depth(MD/TVD): P0. Thickness of Permafrost MD/TVD: Total Depth:x- 716836 y- 5961224 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 2 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) 8197,7'$43,.'- 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 DIR/GR/RES/PWD,CCL,DIR/GR/RES,DIR/GR/RES/NEU/DEN %AWED OCT 3 12016 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT FT. CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 30' 110' 30' 110' 30" 1775#Poleset 13-3/8" 68#/72# K-55/L-80 29' 2736' 29' 2479' 17-1/2" 3500sx CS III,400 sx CS II,200 sx CS II 9-5/8" 47# L"80 27' 8197' 27' 5849' 12-1/4" 500 sx Class'G' 7" 26# L-80 8020' 12783' 5741' 8631' 8-1/2" 409 sx LiteCrete,173 sx Class'G' 4-1/2" 12.6# 13Cr35 12619' 15923' 8536' 8651' 6-1/8" 407 sx Class'G' 24. Open to production or injection? Yes ❑ No 21 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#13C r85 12626' 12510'/8473' w y 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. M � N�NES E�6MPtETIOM e ir!R EC E I v E D Was hydraulic fracturing used during completion? Per 20 AAC 25.283(i)(2)attach electronic and printed Yes ❑ No RI, DATE JUN 1 information 5/14140. JUN 0 2016 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED 15233' • �_ AO^CC 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 ��► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate ""-a* Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only /' / 3 / 16, Y , /,( RBDMS LL- JUN 0 2 2016 ,A 2.-14 �/ 28. CORE DATA Conventional Core(s) Yes LI No f Sidewall Cores Yes ❑ No R 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 E Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 12816' 8650' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 8362' 5950' West Sak 9543' 6615' Colville Mudstone 10263' 7034' HRZ 12470' 8450' Sadlerochit 12816' 8650' 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 wet 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 R Email: Ryan.Ciolkosz@bp.com Printed Name: Joe La• t. Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date: /l/ ' of 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 1 a. 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 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. 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 • 04-33A, Well History (Pre-Rig Sidetrack) T/I/O = 1800/1800/650. Temp = SI. TBG FL (OPS request). AL online. TBG FL @ 10536' (470' 8/13/2015 below sta#3, DOME, 160 bbls). SV, WV, SSV= C. MV= 0, IA, OA= OTG. 0115 hrs. CTU 9 1.75" 0.134"WT CV=40.6bbl Objective: Whip stock drift/Caliper. MIRU. Weekly BOP test. MU BKR CTC 3.10"x.94", bpv 3.12"x1.57', Jar 3.125"x6.80', disco (7/8" ball) 3.38"x1.58', drift 3.62"x6', drift 3.62"x6.0', 3.70 g-ring 3.62"x7.25', OAL=30.72', Max OD 3.70"). RIH w/drift Set down hard at 14148' CTM. Tried jetting through no luck, POOH. Called APE decision was made to run a 8/13/2015 2.70" drift. CTU 9 1.75" 0.134"WT CV=40.6bbl Objective: Whip stock drift/Caliper. MU RIH w/BKR 2.70"drift OAL=33.25' (MAX OD=2.70"). Tagged PBTD 15845' CTM / POOH / RIH with PDS 40 arm caliper 8/14/2015 MAX OD 2.75" OAL = 20.14'. Log 50 fpm from 15762' CTM to 12600' CTM. POOH. CTU 9 1.75" 0.134"WT CV=40.6bbl Objective: Whip stock drift/Caliper. POOH w/logging tools. At surface good data, spot at 14129'-14139' CTM. RIH w/ Baker motor and a 3.70" Parabolic mill dry tagged at 14144' start milling. Made it down to 14,148'with 21 stalls. Called town and decision was 8/15/2015 made to POOH RDMO. CTU #9 1.75" CT 40.6 bbl CV Job Scope: Mill XN and Ovaled tubing. RIH w/ Baker motor& 3.80" 10/8/2015 diamond parabolic mill w/3.80"diamond string mill milled trhu XN at 12613'. CTU #9 1.75" CT 40.6 bbl CV Job Scope: Mill XN and Ovaled tubing RIH w/ Baker motor& 3.80" long tapered mill. Tagged obstruction @ 14110' began milling and got stuck @ 14128' worked free and POOH to change mill. 10/9/2015 RIH w/ Baker motor& 3.80" Diamond Parabolic Mill w/3.80" Diamond Stringer Mill CTU #9 1.75" CT 40.6 bbl CV Job Scope: Mill XN and Ovaled tubing. RIH w/ Baker motor& 3.80" long tapered mill. Tagged obstruction @ 14110' began milling and got stuck @ 14128' worked free and POOH to change mill. RIH w/ Baker motor& 3.80" Diamond Parabolic Mill wi 3.80" Diamond Stringer Mill. Keep stalling in the same spot 14127'After 6 hrs of milling not making any progress 10/9/2015 POOH to ck mill. CTU #9 1.75" CT 40.6 bbl CV Job Scope: Mill XN and Ovaled tubing. At surface mill is wore out pretty much bald. Cut 150' of coil RBIH w/3.80" parabolic mill milled from 14120' to 14134' POOH. At surface the mill is worn not as bad as# 1 it is wore higher on the shoulder than run #1. RBIH with 10/10/2015 another new 3.80" parabolic mill. CTU #9 1.75" CT 40.6 bbl CV Job Scope: Mill XN and Ovaled tubing. Millled w/a new 3.80" parabolic mill; start milling ar 14136' milled thru oval tubing and drifted to 15300' POOH. Changed out pack offs and perform chain inspection. Drifted w/3.70" x 20' drift to 15,300' all clear. POOH Freeze protect well w/38 bbls of 60/40 methanol. Stop @ 5071' to check pipe wall thickness and it 10/11/2015 is below minimum.blow reel down with N2. CTU #9 1.75" CT 40.6 bbl CV Job Scope:Drift w/3.80" mill &whipstock drift. MIRU Perform weekly BOP test. MU 3.80" milling BHA (string reamer+ parabolic mill). Load well with safelube, FP 12/8/2015 38bbls, RIH. CTU 9 1.75" CV 40.7bbl Objective: drift w/3.80"parabolic and dummy whipstock. Continue rih with 3.80" string reamer/parabolic mill. Dry drift down to 15300'with no issues. POOH. RIH w/3.64" 12/9/2015 dummy whipstock drift. Clean drift to 15314' no bobbles POOH. RDMO. RAN 4-1/2"X-CATCHER (xc-44) TO 12,455 'SLM/12,479' MD. PULLED ST#4 RK-OGLV @ 7,923' 12/10/2015 SLM/7,937' MD. PULLED ST#5 RK-LGLV @ 4,590' MD. SET ST#5 RK-DGLV @ 4,590' MD. LRS LOADED IA W/470 BBLS OF CRUDE. LRS PERFORMED PASSING MIT-IA TO 2500#. 12/11/2015 PULLED 4-1/2"X-CATCHER SUB FROM 12,479' MD. T/I/0=980/1275/600 Assist S-Line MIT-IA PASSED to 2500 psi. (Pre CTD) Loaded IA w/3 bbls methanol, 470 bbls crude. S-Line set DGLV, Pumped 21.6 bbls crude down IA to reach test pressure. Loss of 83psi 1st 15 min. Loss of 37 PSI 2nd 15 min of a total of 120 psi during 30 min test. Bled IA to 300psi. FWHP= 1500/100/640. SL on well at departure, tags and annul sign hung, 12/11/2015 IA OA-OTG AL - SI. i 04-33A, Well History (Pre-Rig Sidetrack) T/I/O = 1500/0/600. Set 4" H TWC#432 . @125"Through tree. LTT on TWC (PASS). Installed TS #01 and 7x4 XO#03 . Torqued and PT'd to API specs. (PASS). Installed tree cap and PT'd to 500 12/15/2015 Psi. (PASS). RDMO. FWHP = TWC/0/600. T/I/O = TWC/VAC/580. Temp=SI. Bleed OAP to 0 psi (Pre Rig). AL is disconnected, FL is blinded @ wing. No well house or scaffolding. OA FL ©220', 13 bbls. Bled OAP from 580 psi to 20 psi in 4 1/2 hrs, gas. Monitor for 30 min. OAP increased 25 psi. Final WHPs=TWCNAC/45. SV,WV=? 12/30/2015 SV=Closed. MV=Open. IA,OA=OTG. (1730 hrs). T/I/O=TWC/300/150 R/D TS#01 and XO#03 R/U TS#08 and XO#01 Pulled 4" CIW"H" TWC 3/23/2016 #432 FWP's 1500/300/150. T/I/0=1500/350/175. Pre Nordic 2. Set 4" TWC#441@ 105"with 4' ext. TWC LTT (Pass),Removed 4/22/2016 tree cap assembly. Install 7" blind PT to 5000 psi. (Pass). Final WHP's TWC/350/175. T/I/O = TWC/390/140. Temp = SI. Bleed IA/OA to 0 psi (pre CTD). Well is disconnected. IA FL = 4/25/2016 110' (6 bbls). OA FL= 300' (17 bbls). T/I/O = TWC/7/7. Temp = SI. Bleed IA/OA to 0 psi (pre CTD). Well is disconnected. IA FL = Near surface. OA FL = 300' (17 bbls). Bled IAP and OAP to BT to 0 psi in 5.5 hrs. fluid and gas (25 gallons from IA to BT). Monitored for 30 min. IAP increased 8 psi, OAP increased 7 psi. IA& OA 4/26/2016 FL's unchanged. FWHP's = TWC/8/7. SV= ? WV, SSV= C. MV= 0. IA, OA= OTG. • • North America-ALASKA-BP Page 1 are,/ Operation Summary Report Common Well Name:04-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/27/2016 End Date: X3-017FK-C:(3,073,918.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:NORDIC 2 Spud DateRime:2/14/1986 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292154500 Active datum:04-33A c 51.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/27/2016 22:00 - 00:00 2.00 MOB N WAIT PRE MOVE OFF WELL U-06. NO TWC IN PLACE,DISCUSS THE FOLLOWING RISK MITIGATIONS: -ENSURE CHOCK BLOCK IS IN PLACE -ENSURE ESD BUTTON IS TESTED AND MANNED -DISCUSS RADIO CHECKS -ENSURE STOP COMMAND IS UNDERSTOOD BY ALL. PULL OFF WELL IS WITNESSED BY WSLAND NORDIC FIELD SUPERINTENDENT. PULL OVER TO FRON SIDE OF PAD AND WAIT THERE,FIELD WIDE POWER OUTAGE HAS POSTPONED THE MOVE. 4/28/2016 00:00 - 06:45 6.75 MOB N WAIT PRE CONTINUE WAITING ON U-PAD FOR IMT APPROVAL TO MOVE TO DS-04. MOVE IS DELAYED DUE TO FIELD WIDE POWER OUTAGE. RIG CREW CONDUCTS HOUSEKEEPING AND COMPLETES RIG MOVE CHECKLIST. 06:45 - 08:00 1.25 MOB N WAIT PRE RIG MOVE STILL ON HOLD BUT SINCE GC 1& 2 ARE AND STABLE,ASKED FOR PERMISSION TO MOVE TO AT LEAST SANTA FE PAD AND GOT THE OK NOTIFY SECURITY(45 MIN OUT)AND HAVE TP&DRILLER DRIVE ROUTE DRIVE TO SANTE FE PAD PREP RIG TO MOVE. 08:00 - 00:00 16.00 MOB N WAIT PRE MOVE RIG FROM U-PAD TO 04-33. MOVE FROM U-PAD ACROSS N-PAD,RIGHT ON SPINE ROAD,LEFT ON OXBOW,RIGHT ON WEST DOCK ROAD TO SPINE ROAD TO DS-04. TOTAL DISTANCE 25 MILES. 4/29/2016 00:00 - 05:00 5.00 MOB P PRE CONTINUE TO MOVE FROM U-PAD ACROSS N-PAD,RIGHT ON SPINE ROAD,LEFT ON OXBOW,RIGHT ON WEST DOCK ROAD TO SPINE ROAD TO DS-04. TOTAL DISTANCE 25 MILES. MOVE RIG ONTO DS-04 AND SET MATS. PJSM THEN MOVE RIG OVER WELLAND SET DOWN. MOVING OVER WELL WITNESSED BY WSL, NORDIC SI. ACCEPT RIG 05:00. 05:00 - 06:45 1.75 MOB P PRE CYCLE TREE VALVES,OPEN SSV AND INSTALL FUSIBLE CAP. PERFORM LEAK TIGHT TEST OF SWAB AND MASTER VALVES. GOOD TEST 06:45 - 07:00 0.25 BOPSUR P PRE CREW CHANGE 07:00 - 07:15 0.25 BOPSUR P PRE PJSM WITH DAY CREW TO CONTINUE RU OPERATIONS 07:15 - 12:00 4.75 BOPSUR P PRE ND TREE CAP AND NU BOPE Printed 5/10/2016 8:43:40AM *AII depths reported in Drillers Depths* i North America-ALASKA-BP Page 2 otQ7 Operation Summary Report Common Well Name:04-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/27/2016 End Date: X3-017FK-C:(3,073,918.00) Project:Prudhoe Bay Site:PB DS 04 - -- Rig Name/No.:NORDIC 2 Spud Date/Time:2/14/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292154500 Active datum:04-33A©51.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth i Phase Description of Operations (hr) j (usft) 12:00 - 18:00 6.00 BOPSUR P PRE SHELL TEST BOPE AS PER BP RP 10-45, NORDIC AND AOGCC REQUIREMENTS 250 PSI LOWAND 3500 PSI HIGH ON ALL RAMS AND ANNULAR ALL TESTS WILL BE ON THE CHART RECORDER AND ELECTRONICALLY CAPTURED ON THE TOTCO 8 CTDS SYSTEMS 18:00 - 20:30 2.50 BOPSUR P PRE SHIFT CHANGE AND RIG CHECKS. CONTINUE TESTING BOPS. 20:30 - 20:50 0.33 BOPSUR P PRE RIG EVAC EXERCISE WITH ORLOFF CREW. !ALL PERSONS MUSTER AND ACCOUNTED FOR IN 3 MIN. CONDUCT AAR,DISCUSS NOTIFICATION RESPONSIBILITIES. i 20:50 - 22:40 1.83 BOPSUR P PRE TEST CABLE,PREP CT TO INSTALL CT CONNECTOR. INSTALL CT CONNECTOR,PULL TEST TO 35K, GOOD. 22:40 - 00:00 1.33 BOPSUR P PRE PLACE INJECTOR OVER CIRC HOLE,FILL REEL FORWARD. 4/30/2016 00:00 - 00:50 0.83 BOPSUR P PRE TORQUE BHI CONNECTIONS. PRESSURE TEST CT CONNECTOR,BHI CABLE HEAD,REEL IRON AND BULKHEAD TO 300/4700 PSI,GOOD. 00:50 - 01:30 0.67 BOPSUR P PRE LINE UP TO REVERSE. TEST INNER REEL VALVE AND CT STRIPPER TO 250/3500 PSI,GOOD. 01:30 - 03:00 1.50 BOPSUR P PRE VALVE CREW CHECKS TORQUE ON TREE BOLTS. INSTALL CHECK VALVES. BRING BPV LUBRICATOR ONTO RIG,HAVE TO USE THE PIPE ELEVATOR. PRESSURE TEST CHECK VALVES 250/3500 PSI,GOOD. 03:00 - 04:20 1.33 BOPSUR P PRE REMOVE BOP TEST PLUG. PJSM WITH VALVE CREW FOR PULLING TWC. INSTALL BPV LUBRICATOR,PRESSURE TEST 300/3500 PSI,GOOD. 04:20 - 06:45 2.42 BOPSUR P PRE TRY TO PULLTWC. •ABLE TO ENGAGE THREADS BUT DIFFICULT TO TURN. 06:45 - 07:10 0.42 BOPSUR P PRE CREW CHANGE VALVE CREW NIGHT CREW STILL WORKING ON PULLING THE TWC TWC PULLED,1541 PSI UNDER TWC CLOSE THE MASTER AND BLEED OFF PRESSURE TO THE TIGER TANK CLOSE THE SWAB,LTT TO CONFIRM BARRIERS 07:10 - 07:20 0.17 BOPSUR P PRE STOP AND HOLD A PJSM WITH THE ALL DAY CREWS TO REMOVE THE LUBRICATOR AND LOAD OUT 07:20 - 08:15 0.92 BOPSUR P PRE PU THE LUBRICATOR AND RD THE PULLING RODS LOAD OT THE LUBRICATOR THROUGH THE PIPE SHED 08:15 - 08:30 0.25 BOPSUR P PRE HOLD A PJSM TO PU THE INJECTOR,MU THE UPPER QTS AND TEST Printed 5/10/2016 8:43:40AM `AII depths reported in Drillers Depths* P P P • North America-ALASKA-BP Page 3 Operation Summary Report Common Well Name:04-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/27/2016 End Date: X3-017FK-C:(3,073,918.00) i Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:NORDIC 2 Spud DateMme:2/14/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292154500 Active datum:04-33A§51.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 09:15 0.75 BOPSUR P PRE MU A NOZZLE BHAAND STAB ON TEST THE QTS AS PER WELL PLAN BACK UP VAC TRUCKS FOR BH KILL 09:15 - 09:30 0.25 BOPSUR P PRE GOOD TEST,BLEED OFF AND HOLD A PJSM TO BH KILL THE WELL 09:30 - 11:00 1.50 BOPSUR P PRE LINE UP TO PUMP ACROSS THE TOP UNTIL WE SEE METHANOL AT THE OUT MM SHUT DOWN AND OPEN THE SWAB PRESSURE UP TO 1500 PSI AND OPEN THE MASTER,1597 PSI ON WELL 09:45 ONLINE WITH 5 BBLS OF METHANOL DOWN THE TUBING FOLLOWED BY 360 BBLS OF 1%KCl 09:50 SWAP TO KCL WHP=1521 PSI 10:12 100 BBLS AWAY WHP=821 PSI IAP= 107 PSI OAP=62 PSI 10:28 193 BBLS AWAY WHP=0 PSI IAP= 121 PSI OAP=63 PSI,ADD ANOTHER TRUCK TO 10:35 230 BBLS AWAY FLUID AT THE BOTTOM PERF,STARTING TO BUILD A LITTLE WHP 10:57 360 BBLS AWAY WHP=55 PSI IAP= 190 PSI OAP=71 PSI MOBILIZE 3RD VAC TRUCK FOR FLUID SUPPORT 11:00 - 11:15 0.25 BOPSUR P PRE REDUCE RATE TO 2.0 BPM WHP=22 PSI, OPEN CHOKE AND ESTABLISH A LOSS RATE START LOADING PIT 4 FOR POLYSWELL PILL 11:03 PVT=379 BBLS 11:08 PVT=358 BBLS OR 21 BBLS IN 5 MINUTES OR 252 BPH CLOSE THE CHOKE AND MAINTAIN A LOW POSITIVE WHP TO KEEP THE WELL FULL WHILE PREPPING TO PUMP THE PILL 11:15 - 11:45 0.50 BOPSUR P PRE CALL ODE AND DISCUSS PLAN FORWARD TO PUMP A POLYSWELL PILL AGREE TO PUMP A 40 BBL 20 PPB PILL BASED ON THE DECISION TREE IN THE WELL PLAN AND LENGTH OF PERFS OPEN TOP TO BOTTOM PERF=—24.2 BBLS 11:45 - 13:40 1.92 BOPSUR P PRE CLOSE KILL LINE WHILE WAITING FOR FLUID SUPPORT 13:40 - 13:55 0.25 BOPSUR P PRE PILL IS READY,TRUCKS ARE HERE HOLD A PJSM TO PUMP A POLYSWELL PILL Printed 5/10/2016 8:43:40AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 4 Q127' Operation Summary Report Common Well Name:04-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/27/2016 End Date: X3-017FK-C:(3,073,918.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:NORDIC 2 Spud Date/me:2/14/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292154500 Active datum:04-33A t 51.25usft(above Mean Sea Level) Date From-To Hrs r Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:55 - 15:40 1.75 BOPSUR P PRE ONLINE WITH PUMPS AT 6 BPM 214 BBLS TO TOP PERF PUMP SCHEDULE 14:00 150 BBLS OF KCL AHEAD 14:17 START CUTTING SACKS ZERO BBL COUNTER 14:21 40 BBLS OF POLYSWELL WHP STARTING TO BUILD AS SOON AS THE POLYSWELL GOT IN THE TUBING,SAME PRESSURE INCREASE SEEN ON M-08 14:28 40 BBLS OF FRESH WATER 14:34 130 BBLS OF KCL 14:40 WHP=460 PSI 14:50 WHP=648 PSI 170 BBLS AWAY 14:56 210 BELS AWAY WHP=802 PSI REDUCE PUMP TO 2 BPM,WFIP INCREASE TO 854 PSI IN THE LAST 2 BBLS 14:57 RATE AT 2 BPM WHP=465 PSI 14:58 215 BBLS AWAY WHP STARTING TO CLIMB WHP=505 PSI 15:02 223 BBLS AWAY WHP=564 PSI 15:04 227 BBLS AWAY WHP=648 PSI 15:06 231 BBLS AWAY WHP=758 PSI 15:10 240 BBLS AWAT WHP=875 PSI AND IS STABILIZING,SHUT DOWN THE PUMP AND HESITATE 9 BBLS LEFT TO SQUEEZE AWAY MIGRATION WILL BE MINIMAL AS THE TOP PERF IS AT 91° 15:16 WHP SLOWLY BLEEDING OFF=186 PSI 15:30 WHP=36 PSI SLOWLY BLEEDING OFF THIS IS EQUIVELENT TO ANOTHER 360 BBL KILL VOLUME BEFORE WE SLOW DOWN THE PUMPS TO 2 BPM PUTTING THE LEAD(210 BBLS)OF THE POLYSWELL JUST ABOVE THE TOP PERF. 15:40 - 15:45 0.08 BOPSUR P PRE HESITATED FOR 30 MINUTES,WHP SLOWLY DROPPED TO 11 PSI 9 BBLS POLYSWELL LEFT TO DISPLACE COME ONLINE AT 1 BPM,PRESSURE CLIMBING RIGHT AWAY 1 BBL AWAY WHP=513 PSI 2 BBLS AWAY WHP=663 PSI 13 BBLS AWAY WHP=699 PSI 4 BBLS AWAY WHP=725 PSI 15:45 - 16:10 0.42 BOPSUR P PRE SHUT DOWN THE PUMP,WHP LEVELEING OFF AND WE ARE INJECTING AND I DON'T WANT TO BREAK IT DOWN ALLOW WHP TO DISIPATE ON ITS OWN TO KEEP FROM DRAWING THE PRESSURE AND FLOWING THE POLYSWELL OUT OF THE PERFS 16:10 - 16:30 0.33 BOPSUR P PRE LINE UP ACROSS THE TOP AND ESTABLISH A LOSS RATE IF ANY DISCUSS WITH ODE OPTION FOR CLEAN OUT RUN,WELL TURNS 90°AT 13,000'SO WE HAVE—2300'OF HORIZONTAL TUBING AND 1185'OF PERFS. 16:30 - 19:30 3.00 CLEAN P PRE RIH WITH NOZZLE AND CHECKS TO CLEANOUT TO WHIPSTOCK SETTING DEPTH AS PER OCN#4. WT CHECK AT 12,000 FT IS 50K. Printed 5/10/2016 8:43:40AM *All depths reported in Drillers Depths* • 11111 North America-ALASKA-BP Page 5 c22,Y Operation Summary Report Common Well Name:04-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/27/2016 End Date: X3-017FK-C:(3,073,918.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:NORDIC 2 Spud Date/Time:2/14/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292154500 Active datum:04-33A©51.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 20:00 0.50 CLEAN N SFAL PRE DURING WT CHECK DRILLER NOTICES A CLUNKING NOISE FROM INJECTOR. STOP AND ASSESS. STOP HERE AND CALL SLB MECHANIC FROM DEADHORSE. PUMP A B/U AT 3.1/2.8 BPM FROM 11,884 FT TO CLEAR THE WELL,IN CASE THIS MAINTENANCE EVENT LASTS AWHILE. GETTING SMALL AMOUNT OF POLYS WELL BACK. REDUCE RATE TO 2.54/2.20 BPM AFTER RETURNS DIMINISH AT 3 BPM. LOST RETURNS AFTER 46 BBLS INTO B/U. 20:00 - 21:20 1.33 CLEAN N SFAL PRE LINE UP TO KEEP WELL FULL DOWN THE KILL LINE. PUMPING 2.29 CT+1.23 KILL LINE GETTING 1.18 BACK. ADD A THIRD TRUCK FOR ROUND TRIPPING FLUIDS. I SLB MECHANICS ARRIVE AND ADJUST GOOSENECK. NOISE DIMINISHES. 21:20 - 22:30 1.17 CLEAN P PRE CONTINUE RIH. PUMP 2.28/0.99 BPM WHILE RIH. WT CHECK AT 13,000 FT IS 66K. WT CHECK AT 13,500 FT IS 64K. WT CHECK AT 14,000 FT IS 62K. WT CHECK AT 14,500 FT IS 62K. RIH TO 15,325 FT,NO ISSUES NOTED. 22:30 - 00:00 1.50 CLEAN P PRE POOH,UP WT AT 15300 FT IS 70K AT 63 FT/MIN. STOP AND ADJUST GOOSENECK AGAIN AT r 13,900 FT THEN CONTINUE OOH. 5/1/2016 00:00 - 02:00 2.00 CLEAN P PRE CONTINUE POOH WITH BHA#1. 02:00 - 02:30 0.50 CLEAN P PRE CONDUCT PJSM FOR CHANGING BHA WHILE POOH. TRIP SHEET IS-346 BBLS TO THIS POINT. 02:30 - 03:15 0.75 WHIP P WEXIT AT SURFACE,10 MIN LOSS RATE IS 1.2 BPM VERIFIED WITH MM AND PVT. INJECTOR OFF AT 02:30. TAG STRIPPER,L/D NOZZLE BHA. M/U BHA#2,WHIPSTOCK. INJECTOR ON AT 03:15. 03:15 - 06:40 3.42 WHIP P WEXIT ZERO COUNTER,TEST QTS AND BHI TOOLS. RIH. LOSING ABOUT 80 BBLS/HR WHILE RIH. 106:40 - 07:35 0.92 WHIP P WEXIT 14167'SET DOWN WT AND TRIPPED THE INJECTOR INJECTOR TRIPS SET 4K BELOW RIH WT RESET INJECTOR AND RIH 14245'SET DOWN AGAIN AWGRS REPORT 10/08/2015-10/11/2015 MILLING OVALED TUBING WITH 3.80 MILL FROM 14128 TO 14424 WITH SEVERAL STALLS 07:35 - 08:10 0.58 WHIP P WEXIT LOG TIE IN Printed 5/10/2016 8:43:40AM `All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 6a Operation Summary Report Common Well Name:04-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/27/2016 End Date: X3-017FK-C:(3,073,918.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:NORDIC 2 Spud DateMme:2/14/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292154500 Active datum:04-33A©51.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:10 - 08:40 0.50 WHIP P WEXIT CORRECT DEPTH-20.5' BASED ON THIS CORRECTION THE DRIFT RUN ON SERVICE COIL ONLY DRIFTED TO 15325' THE CCL IS 65'BEHIND THE BOTTOM OF THE WS SO WE NEED TO CCL LOG TO A MINIMUM OF 15312.45' CALL ODE AND DISCUSS MAKING A SLOW VERY CAUTIOUS PASS TO 15340 THEN PU AND CCL LOG DOWN TO ENSURE WE DO NOT SET THE WS INA COLLAR 08:40 - 08:55 0.25 WHIP P WEXIT APPROVAL GIVEN TO DRIFT TO 15340'THEN PU AND LOG TO THAT DEPTH TO ENSURE THE WS WILL NOT BE SET IN A COLLAR 08:55 - 10:00 1.08 WHIP P WEXIT DRIFT TO 15340'WAS CLEAN NO SURFACE OR WOB CHANGE SEEN AT ALL PU TO 15100 AND CCL LOG DOWN TO 15340 10:00 - 10:10 ' 0.17 WHIP P WEXIT AFTER LOGGING THE CCL THE BOTTOM OF THE WS IS IN A COLLAR.CALLED ODE AND DISCUSSED SETTING THE WS 5'HIGHER WITH THE TOWS NOW AT 15230'AND THE BOTTOM AT 15242.5' 10:10 - 10:15 0.08 WHIP P WEXIT APPROVAL GIVEN PUH TO 15200',RIH AND STOP AT 15242.5',PU TO 5K UNDER UP Wr,CLOSE THE EDC AND SET THE WS 10:15 - 13:50 3.58 WHIP P WEXIT WS SET,STACK 7K DOWN TO ENSURE THE WS IS SET AND WON'T MOVE 7K DOWN,NO MOVEMENT,POOH PUMPING DOWN THE COIL AND ACROSS THE TOP T KEEP THE HOLE FULL LOSS RATE AD DRILLING RATE=112 BPH, STATIC=60 BPH,NOTIFY ODE HOLD A PJSM WITH THE CREW TO LD THE WS SETTING BHA,INSTALL NIGHT CAP AND PERFORM AN INJECTIVITY TEST. 13:50 - 14:20 0.50 WHIP P WEXIT AT SURFACE WELL TAKING 1.45 BPM OR 87 BPH LOST 318 BBLS DURING THE TRIP SHUT DOWN THE PUMP AND PU THE INJECTOR TO LD THE WS SETTING BHA ------------------ 14:20 - 15:10 0.83 WHIP P WEXIT BHA OOH LOAD OUT TOOLS INSTALL NIGHT CAP AND TEST 15:10 - 15:20 0.17 WHIP P WEXIT PJSM TO TEST WELL INJECTIVITY FOR POSSIBLE POLYSWELL PILL 15:20 - 15:40 0.33 WHIP P WEXIT PERFORM INJECTIVITY TEST 6 BPM AT 404 PSI CALL ODE FOR OCN AND PREP TO PUMP A30 BBL 20 PPB POLYSWELL PILL 15:40 - 15:55 0.25 WHIP P WEXIT HOLD A PJSM TO PUMP 30 BBL 20 PPB POLYSWELL PILL Printed 5/10/2016 8:43:40AM *All depths reported in Drillers Depths* . • North America-ALASKA-BP Page 7 4177." Operation Summary Report Common Well Name:04-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/27/2016 End Date: X3-017FK-C:(3,073,918.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:NORDIC 2 Spud Date/Tune:2/14/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292154500 Active datum:04-33A©51.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:55 - 17:00 1.08 WHIP P T WEXIT LINE UP BOTH PUMPS DOWN THE COIL VERIFY LINE UP IS CORRECT WITH PRESSURE CROSS CHECK LIST 210 BBLS TO TOP OF PERFS 233 BBLS TO WS 234 BBLS TO BOTOM PERF 16:03 START CUTTING SACKS 16:06 ONLINE WITH 30 BBL POLYSWELL PILL, 'WHP SLOWLY BUILDING 16:11 SWAP TO 30 BBL FRESH WATER WHP =327 PSI 16:43 200 BBLS AWAY WHP=809 PSI 16:45 210 BBLS AWA REDUCE RATE TO 2.0 BPM AND DISPLACE POLYSWELL AT 2.0 BPM 16:47 212 BBLS AWAY WHP=570 PSI 16:49 220 BBLS AWAY WHP=656 PSI 16:54 233 BBLS AWAY WHP=938 PSI POLYSWELL AT THE WS 16:57 238 BBLS AWAY WHP=989 PSI '17:00 244 BBLS AWAY WHP=1055 PSI POLYSWELL DISPLACED AND FRESH WATER IS ACROSS THE PERFS/POLYSWELL 17:00 - 17:10 0.17 WHIP P WEXIT DOWN ON PUMP ALLOW POLYSWELL TIME TO DO ITS THING WITH FRESH WATER WHILE WHP DISIPATES ON ITS OWN 17:10 - 17:25 0.25 WHIP P WEXIT HOLD A PJSM TO MU THE MILLING BHA 17:25 - 18:00 0.58 WHIP P WEXIT BLEED OFF REAMING 101 PSI REMOVE NIGHT CAP GAUGE MILLS TIGHT 3.80 WINDOW AND STRING MILLS MU MILLING BHA 18:00 - 21:10 3.17 WHIP P WEXIT RIH WITH MILLING BHA. PUMP MIN RATE THROUGH OPEN EDC WHILE RIH,GOOD RETURNS. WI CHECK AT 14,000 FT IS 56K. CLOSE EDC AT THIS DEPTH TO TURN MILL THROUGH OVALLED TUBING. RIH 30 FT/MIN PUMP 0.5 BPM PAST 14,000 FT SET INJECTOR TRIPS TIGHT. SEE VERY SLIGHT MOTOR WORK PERIODICALLY RUNNING FROM 14100-14350 FT,SLIGHT(ABOUT 3K)SETDOWNS. 21:10 - 22:30 1.33 WHIP P WEXIT WT CHECK AT 15,150 FT IS 63K. LOG TIE-IN FROM 15,180 FT. CORRECT-17 FT. TAG PINCH POINT AT 15,233 FT. PICK UP AND OPEN EDC. EASE RATE UP TO 2.9 BPM,SEE WHAT - RETURNS WE CAN GET. INITIAL RATE IS 2.97/2.13 BPM. GETTING LOTS OF POLYSWELL BACK. 22:30 - 23:30 1.00 WHIP P WEXIT DISCUSS WITH ODE,RETURN RATE IS ENOUGH TO SWAP TO MUD. VAC OUT RETURN PITS TO PREP FOR MUD SWAP. START NEW MUD DOWNHOLE. Printed 5/10/2016 8:43:40AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 8 ot927 Operation Summary Report Common Well Name:04-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/27/2016 End Date: X3017FK-C:(3,073,918.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:NORDIC 2 Spud Date/Tme:2/14/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292154500 Active datum:04-33A @51.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 WHIP P WEXIT MUD IS AT THE BIT,CONTINUE CIRCULATING IT AROUND 2.6/1.7 BPM INITIAL CIRC RATE. AFTER 20 BBLS OUT RETURNS START TO DECREASE. 2.63/1.58 BPM WITH 23 BBLS OUT. 2.63/1.12BPM WITH36BBLS OUT. 5/2/2016 00:00 - 00:30 0.50 WHIP P WEXIT CONTINUE CIRCULATING MUD AROUND. OUT RATE HAS REDUCED TO 2.6/0.5 BPM WITH 60 BBLS MUD OUT THE BIT. DISCUSS WITH OPS SPECIALIST AND ODE, DECIDE TO SWAP BACK TO KCL FOR WINDOW MILLING. Vv v.t, 00:30 - 01:00 0.50 STWHIP P WEXIT CLOSE EDC,RIH TO MILL. TAG AT 15232.7 FT,START MILLING AT 2.83/ 04-331 0.61 BPM. T SWAP BACK TO KCL WHILE MILLING. 01:00 - 02:00 1.00 STWHIP P WEXIT MILL AT 15233 FT 2.79/0.61 BPM,DWOB=0.65 KLBS. 02:00 - 02:30 0.50 STWHIP P i WEXIT MILL AT 15234 FT 2.83/0.04 BPM,DWOB=2.20 KLBS. MILL TO 15,234.3 FT. 02:30 - 04:50 2.33 STWHIP N DPRB WEXIT PICKUP AND WAIT FOR MORE FLUID. HAVE 4 TRUCKS ROUND TRIPPING BUT NONE ARE HERE NOW. CIRCULATE ACROSS TOP TO KEEP THE WELL FULL. STATIC LOSS RATE ABOUT 25 BBLS/HR ACROSS THE TOP. 04:50 - 05:30 0.67 STWHIP P WEXIT ADEQUATE FLUID VOLUME ON LOCATION, CONTINUE MILLING WINDOW. 05:30 - 06:25 0.92 STWHIP P WEXIT MILL WINDOW AT 15,234.6 FT 2.81/0.83 BPM,DWOB=3.16 KLBS. 06:25 - 08:45 2.33 STWHIP P WEXIT CONTINUE MILLING WINDOW FREE SPIN=1641 PSI AT 2.83 BPM RATE IN=2.81'BPM RATE OUT=0.90 BPM LOSS RATE =1.91 BPM OR 115 BPH MW IN=8.37 PPG MW OUT=8.90 PPG ECD =9.23 PPG ROP=1 FPH WOB=3.76 K CIRC PSI= 1857 PSI IAP=148 PSI OAP=117 PSI PVT=308 1BBLS 08:45 - 10:35 1.83 STWHIP P WEXIT ;CONTINUE MILLING WINDOW WEIGHT IS CLOSE TO MAX WOB,SLOW ROP DOWN AND ALLOW TO DRILL OFF FINE METAL ON THE MAGNETS,NO VISCOSITY TO CARRY METAL TO SURFACE FREE SPIN=1641 PSI AT 2.83 BPM RATE IN=2.78 BPM RATE OUT=1.84 BPM LOSS RATE =0.94 BPM OR 56 BPH MW IN=8.44 PPG MW OUT=8.47 PPG ECD =9.06 PPG ROP=<1 FPH WOB=3.93 K CIRC PSI= 1882 PSI IAP=158 PSI OAP=120 PSI PVT=145 BBLS Punted 5/10/2016 8:43:40AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 9 of5W Operation Summary Report Common Well Name:04-33 I AFE No Event Type:RE-ENTER-ONSHORE(RON) �Start Date:4/27/2016 End Date: X3-017FK-C:(3,073,918.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:NORDIC 2 Spud Date/Time:2/14/1986 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292154500 Active datum:04-33A©51.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations - _-- (hr) (usft) 10:35 - 13:20 2.75 STWHIP P WEXIT CONTINUE MILLING WINDOW MAX WOB,VIBRATION ATA STEADY 4 FREE SPIN=1641 PSI AT 2.83 BPM I RATE IN=2.78 BPM RATE OUT=1.97 BPM LOSS RATE =0.81 BPM OR 48 BPH MW IN=8.44 PPG MW OUT=8.47 PPG ECD =9.06 PPG ROP=<1 FPH WOB=4.72 K CIRC PSI= 1882 PSI IAP=158 PSI OAP=120 PSI PVT=145 BBLS 13:20 - 15:45 2.42 STWHIP P WEXIT CONTINUE MILLING WINDOW ROP IS BACK TO NORMAL MIX A 40 BBL HIGH VIS PILL AND PUMP TO CLEAN THE CUTTINGS OUT FREE SPIN=1641 PSI AT 2.83 BPM RATE IN=2.78 BPM RATE OUT=1.99 BPM LOSS RATE =0.80 BPM OR 48 BPH MW IN=8.44 PPG MW OUT=8.44 PPG ECD =8.98 PPG ROP=1 FPH WOB=4.72 K CIRC PSI= 1882 PSI IAP=158 PSI OAP=120 PSI PVT=145 BBLS 15:45 - 16:50 1.08 STWHIP P WEXIT CONTINUE MILLING WINDOW FREE SPIN=1641 PSI AT 2.83 BPM RATE IN=2.77 BPM RATE OUT=2.05 BPM LOSS RATE =0.72 BPM OR 43 BPH MW IN=8.43 PPG MW OUT=8.40 PPG ECD =8.99 PPG ROP=1 FPH WOB=2.60 K CIRC PSI= 2095 PSI IAP=160 PSI OAP=125 PSI PVT=210 !BELS 16:50 - 17:50 1.00 STWHIP P WEXIT WINDOW MILL EXIT THE 4.5"CASING MILL 1' AT SAME ROP TO DRESS BOTTOM OF WINDOW WITH STRING MILL 17:50 18:30 0.67 WEXIT MILL 9'OF OH TO PUMP 28 BBLS HIVIS PILL AROUND. 118:30 - 20:10 1.67 STWHIP P WEXIT PICK UP FOR FIRST REAMING PASS. SOME MOTOR WORK SEEN AT THE BOTTOM OF THE WINDOW. SECOND PASS IS CLEANER,JUST SLIGHT MOTOR WORK SEEN. THIRD PASS IS CLEAN. 20:10 - 00:00 3.83 STWHIP P WEXIT DRY DRIFT IS CLEAN,POOH. BOTTOMS UP SAMPLE HAS NO FORMATION, JUST POLYSWELL AND METAL SHAVINGS. DYNAMIC FLOW CHECK JUST ABOVE WHIPSTOCK IS GOOD,1 BPM RATE IN WITH 0.8 BPM OUT,POOH AT 5 FT/MIN. POOH,PUMP 3.1/2.4 BPM THROUGH OPEN EDC. PERFORM PJSM WITH CREWS WHILE POOH, TRIP SHEET IS-60 BBLS TO THIS POINT. WHILE POOH,MIX KCL AND POLYMER IN BATCH MIXER TO PREP FOR POLYSWELL JOB. Printed 5/10/2016 8:43:40AM *All depths reported in Drillers Depths* TREE= CM/ ; S NOTES:WELL ANGLE>70 @ 12893'*** I VvELLFE,AD= FMC1 • 1 4- CHROME TBG ORIG WELL NOT SHOWN ACTUATOR= BAKER C 04-33A 1 BELOW WHPSTOCK*** 10KB. ELEV = 62' 1 REF ELEV = 5125 i I I I I BF. BEV= 2426.1 . 1 i 2112' —4-1/2'HES X NIP,D=3.813' 1 KOP-- 60001 i 'Max A ngle= 99'@ 13087! 1 !Datum MD= NA! GAS LFT MANDRELS I Datum TVD= 8800SS ST MD TVD Ce/ TY PE VLV LATCH i RDRT DATE 1 I 5 4590 36064.54 ANG DMY RK 0 12/11/15; IL 13-3/8"CSG, 72#, L-80/K-55,ID=12.347 — 274TI 4 7937 5692 r 53 MMG DMY RK 0 12/11/151 3 10066 6919 r 54 K8G2 DMY BK 0 06/15/151 2 I 11402 T78347 KBG2 DMY BK 0 06/15/151 1 12195 82931 55 KG82 DMY BK i 0 06/15/151 Minimum ID = 3.80" @ 12613' 4-1/2" HES XN NIPPLE 1 8020' —19-5/8'X r BKR ZXP LTP w/TF_BACK SLV, J ID=6.290" I I 1 D I 8036' —9-5/8'X 7^BKR FLEXLOCK LNR HGR, I 'T T vI ID Q =6.230'9-5/8'W IIPSTOCK(09/06/09) I— 8197' . '1 4 14 MILLOUT W#430W(04-33A) 8197'-8214' .• 9-5/8"CSG.47#,L-80 STC,ID=8 681" H 12880' I I .,- -...-. 17"LNR,26#,L-80,E3TC Tal X0 TO L-80 BTC-M H 9'177 ; 12479' ---14-1/2-HES X NP,11)=3.813" 1 1 7 ‘1 ORATION SUMMARY LOG: 7717 12509' I—7"X 4-1/2"BKR S-3 PKR,o=3.875"PERF REF ANGLE AT TOP PERE 91'@ 14050' ilk Note Refer to Production DB for historical pert data 411/4 SIZE SPF INTER'VAL Opn/Sqz DATE N.i. 111 12543' —I4-1/T HES X NP,ID=3.813" 2-718' 6 14050- 14160 0 09/22/09 2-7/8" 6 14200- 14310 1 0 09/22/09 1 12613' —4-1/2'HES XN NP PALLED 2-7/8" 6 14370-14430 1 0 09/22/09 2-7/8" 6 15130-15160 0 09/22/09 TO 3.80'(10/11/15) 2-7/8" 6 15195- 15350 0 09122/09 12619' —7'X 5'FIRO ZXPN LTP w/ 2-7/8' 6 15380- 15420 0 0902/09 TIEBACK SLV,ID=4.460° 1 2-7/8" 6 15500- 15520 I 0 09/22/09 2-718' 6 15540- 15650 I 0 09122/09 1 \ 12625' —4-1/2"WLEG,CI=3.958" I 11. I 1 12836' —7I "X 5'BKR FLB(LOCK , I 1 LNR HGR,ID=4 450" [4-1/2"TBG,12.6#,13CR-85 VAM TOP,.0152 bpf,ID=3.958' _II— 12626' 12645' I: 15-1/2"X 4-1/2" I X0,ID=3.958' il 7"LNR,28#,L-80 BTC-M,.0383 bpf,ID=6.278' HL 12783' , 4-1/2'MONOBORE WHIPSTOCK(05/01/16) I-1 15232' IIII 14-1/2"LNR. 12.6#,13CR-85 VA M TOP X0 TO L-80 E3T-M I 16842' Vok PI-737ID 15842' '41444 INS 4%k 1,1&i&b , a& [4-1/2"LNR, 12.6#,L-80 E3T-M,.0152 bpi.ID=3.958" IH 15923' ------ — _ DATE REV BY I COMMENTS DATE 'REV BY COMMENTS ! FRUCHOE BAY UNIT I 03/18/86 !ORIGINAL COMPLETION 05/13/16 JNIJAID A COED REF ELEV&BF B...EV WELL 04-33A , 04/18/94 N2ES RWO 06/01/16 JNLAMD AC1JED1114-111STOCK(05/01/16) FERMI-No.w2090800 09/24/09 N7ES SIDETRACK(04-33A) . API W. 50-029-21545-01-00 07/24/15 STFLIMDIGLV(70(06/15115) SEC 26,T11N,R15 E.678'FSL 303'FW_ 12/17/15 JTIVIAIDI ktILLED XN NP(10/11/15) 12/31/15 GTVV/JktiGLV(70(12/11/15) E3P Exploration(Alaska) . • • tioF T� THE STATE Alaska Oil and Gas 1- Of/� /� (� Conservation Commission KA 333 West Seventh Avenue ITh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o< ;;; '•• Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen r ��E 8 Engineering Team Lead SCP *4 Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU 04-33A Sundry Number: 315-648 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, /1° 1?(//k Cathy P oerster Chair DATED this�day of October, 2015 Encl. JL RBDMS ff.T 2 6 2015 STATE OF ALASKA • •LASKA OIL AND GAS CONSERVATION COMM$ N APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations o Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 2• Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 209-080 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Er 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21545-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? RECEIVED Will planned perforations require a spacing exception? Yes 0 No EI PBU 04-33A , 9. Property Designation(Lease Number): 10. Field/Pools: O C i 1 a)C 2015 ADL 028324&028323 • PRUDHOE BAY,PRUDHOE OIL• 11. PRESENT WELL CONDITION SUMMARY �O(pZ�� Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(rfie9e ��",,rr 15925, 8651 • 15842 8654 None None Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 30-110 29-109 1490 470 Surface 2707 13-3/8" 29-2736 29-2479 4930 2670 Intermediate 8170 9-5/8" 27-8197 27-5849 6870 4760 Liner 4763 7" 8020-12783 5741 -8631 7240 5410 Liner 3304 4-1/2" 12619-15923 8536-8651 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14050-15650 8655-8656 4-1/2"12.6# 13Cr85 25-12626 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 12510'/8473' No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal Il 13.Well Class after proposed work: BOP Sketch II Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development II ' Service 0 14.Estimated Date for Commencing Operations: November 1,2015 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended El • 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned o Commission Representative: Op Shutdown 0 GSTOR 0 • SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ciolkosz,Ryan R Email Ryan.Ciolkosz@bp.com Printed Name John McM en �^ Title Engineering Team Lead Signatur z.--//..L___ / (J Phone +1 907 564 4711 Date ( 6 l//`�,c/s---_. COMMISSION USE ONLY Con 'i of approval:Notify Commission so that a representative may witness Sundry Number: 31S —(QL4C Plug Integrity 0 BOP Test tE17 Mechanical Integrity Test 0 Location Clearance 0 Other: z3Df 1rS-f' fc., 35G2(.2 p5,�) fir'/75P 1S ZS Ito 7t, , 51 A r/i✓tvtcr� prcvtv?�tr fit� �� • 25-%ops; , l A6ter771M1-C pIv7 pG�ietvYrc�z7` app �faprr !, 4_/-C2SZ ,ltLLJ Spacing Exception Required? Yes 0 No Ni/ Subsequent Form Required: /D-- I 7 1 _' APPROVED BYTHE Approved by: /($(� COMMISSIONER COMMISSION Date:Id'2s.../3- 1- s.../J1-- JO/ZZ/1 nr r75 70150RIGINAL RBDMSC. (o .0 r4 Submit Form and Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. 4) /0'16'/S • • To: Alaska Oil &Gas Conservation Commission From: Ryan Ciolkosz b CTD Engineer Date: October 12, 2015 Re: 04-33A Sundry Approval Sundry approval is requested to plug the 04-33A liner perforations as part of the drilling and completion of the proposed 04-33B CTD sidetrack. History and current status: 04-33 was Rotary Sidetracked in 2009 to the Zone 1 04-33A targets. Since then the IOR has dropped off to 180 bbls/day. Proposed plan: Drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or around January 1st, 2015. Coil tubing service unit will drift for CTD whipstock and mill. Nordic 2 will set a whipstock and a mill a 3.80"window in the 4-1/2"tubing and drill a Zone 1 well to—17,300' MD. The lateral will be completed with a 3-1/2" x 2-7/8" 13Cr-80 liner which will be cemented and perforated. This Sundry covers plugging the existing 04-33A perforations via the 04-33B liner cement iob or liner top packer set post-rig (alternate plug placement per 20 AAC 25.112(i)). 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. q3z /.'oPe> , „1, ; (7/z_‘/ iciepb e-fir- a - �c. l,,i/� '�{ %hr we fr'lf Ped a/vC.rl G) (�A,SOna 1/e Q,�v/% ,� Co" Gv�. pro��cr�`o �,' ACCafa�,A� i 0 BP a r� be h�c f ovr- ;„ eider ry y.s r 1/ fa l►C fir cl1,fi&1ta( Ica�-ao� ,j /ow. d r4Gl rode,ee ar S� venal well f On T4-f P Qo,P ply,' "^s rips 1,,,e// r- Ieo'r %l/ 54p/o• 4//401 000 0r Q1O vpt/l (P cO✓en, f/04 %Off fol",64 °I- %49 A°j. /d�� / .--- • • Pre-Rig Work(scheduled to begin Nov 1 , 2015) 1. C Drift for whipstock and window mill to 3.80" 2. V Pre CTD Tree Work. Set TWC 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 2,576 psi. - - 2. RIH and set 4-1/2" monobore Whipstock. Top at 15,235' MD 3. Mill 3.80"window plus 10' of rathole. Swap the well to 9.5 ppg PowerPro. 4. PU drilling BHA with GR/Resistivity 5. Drill 4.25" hole to TD at-17,300' MD 6. Run 3-1/2"x 2-7/8" 13Cr-80 liner leaving TOL at-12,578 MD. 7. Pump primary cement bringing TOC to TOL, 35 bbls of 15.8 ppg liner cmt planned* 8. Test liner lap to 2,400 psi. 9. Perforate liner per asset instructions 10. Freeze protect well, RDMO Post Rig: 1. V: Tree work as necessary. 2. S: Drift. LTP if necessary.*Set Live GLV's 3. F: Pressure test Liner top packer 4. T: ASRC flow back *Approved alternate plug placement per 20 AAC 25.112(i) Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka • L D= FMC 04-33B 4117'CHROME TBG*`*(MG WELL NOT SHOWN *ACTUATOR= BAKER C BELOW WHIPSTOCK*** KB.ELEV= 62' BF HSV= 24.65' I L I KOP= 6000' 2112' —14-1/2"FES XMP,D=3.813" Max Angle= 9°C 13082' Datum MD= NA Datum TVD= 8800'SS GAS LFT MANDRH S ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-801K-55,O=12.347" —I 2747' _5 4590 3606 ir 54 MG DOME RK 16 12/17/10 I 4 7937 5692'53 MMG DOME RK 16 12/17/10 3 10066 6919'54 KBG2 DOME BK 16 12/17/10 2 11402 7783'47 KBG2 COME BK 16 12/17/10 1 12195 8293'55 KGB2 SO BK 24 12/17/10 Minimum ID = 3.725" @ 12613' 4-1/2" HES XN NIPPLE 8020' 9-5/8'X7'BKR ZXPLWw/TIEBACK SLV, 1 D=6,290' 9-5/8"WHIPSTOCK(09/06/09) H 8197' f 8036' -19-5/8'X 7'BKR FLEXLOCK LIQ HGR, D=6.230' MLLOUT WIMDOW(04-33A) 8197'-8214' ‘ 7" .26#,L-80,BTC TCI XO TO L-80 BTC-M —1 9172' 12479' 4-1/2"HES X NP,D=3-813" LN I ! 12509' —7'X4-1/2"BKR S-3 PKR,D=3.875" 9-518"CSG,47#,L-80 BTC,D=8.681' -{ 1--26 ! 12643* H 4-1/2"HES X MP,13=3.813" FERFORATIONStLMAR1' ® A `70"BKR DEPLOY SLV,ID =3.00"@ 12,578'MD REF LOG: ??? _ I ' 3 1/2 X3`I�pp� ID-2.813 @ 12,598'MD ANGLE AT TOP PERF: 91*@ 14050' Note:Refer to Production DB for historical perf data 12613' H4-1t2"HES XN NP,D=3.725' SIZE SFF N4TH?VAL Opn/Sqz DATE Fri 2-7/8" 6 14050-14160 0 09/22/09 I 12625' H4-1/2"VVLEG,AO=3.958" 2-7/8" 6 14200-14310 0 09/22/09 2-7/8" 6 14370-14430 0 09/22/09 12619' —17"X 5"K S ,ID 4 w' TEBACLVD=4.460' 2-7/8" 6 15130-15160 0 09/22/09 ■ 2-7/8' 6 15195-15350 0 09/22/09 i4 12635' 1—7"X 5"BKR FLEXLOCK 2-7/8' 6 15380-15420 0 09/22/09 LNR HGR,D=4.450' 2-7/8" 6 15500-15520 0 09122/09 i 12645' 15-112"X 4-1/2" 2-7/8" 6 15540-15650 0 09/22/09 XO,D=3.958" 3-1/2"93j#STL 13CR-80 7'LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" --I 12783' it 4-1/2'TBG,12.6#,13CR-85 VAM TOP,.0152 bpf,D=3.958" — 12625' 3-1/2"x2 7/$"XO @ -15,135 4-1/2"LNR,12.6#,13CR-85 VAM TOP XO TO L-80 BT-M —1 12650' 4-1/2"Monoboiwhiostnck@ 15,235'4/D f / RA TAG @ TBD RIM 158427-- 5842_'- [ 2-7/8"6 5#STL 13CR-80 @ 17,300' 4-1/2"LNR, 12.6#,L-80 BT-M,.0152 bpf,D=3.958" -H 15923' k4444rrffr4 DATE REV BY COMvfNTS DATE REV BY OOMENTS PRDHOEBAY !!NIT 03/18/86 ORIGINAL COMPLETION 01/02/11 VVEYPJC GLV C/O(12/17/10) WELL: 04-33A 04/18/94 FRES RWO P8 AT No:"2090800 09124/09 FRES SIDETRACK(04--33A) AR No: 50-029-21545-01-00 09/29/09 SV DRLG HO CORF ECTIONS SEC 26,T11 N,R15 E,678'FSL 303'RAL 10/08/09 DAV/SV GLV DO(09/30/09) 05/10/10 JR'JM) DRLG DRAFT COFTIO1S BP Exploration(Alaska) py NOTES: � 4TTE'D= • - -1CHRR BGORIGWELL NOT SHOWN ACTUATOR= RAKER C BELOW WHIPSTOCK'** KB.R_EV= 62' BF.ELEV= 24.65' I I KOP= 6000' Max Angle= 9"@ 13082' j L 2112' —I4-1/2"HES X NIP,D=3.813" Datum MD= NA Datum ND= 8800'SS GAS LFT MANS ST ND ND DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-801K-55,D=12.347" H 274T 5 4590 3606'54 MMG DOME RK 16 12/17110 4 7937 5692 r 53 MMG DOME RK 16 12/17/10 3 10066 6919 r 54 KBG2 DOME BK 16 12/17/10 2 11402 7783' 47 KBG2 DOME BK 16 12/17/10 1 12195 8293 r 55 KGB2 SO BK 24 12/17/10 Minimum ID =3.725" @ 12613' 4-1/2" HES XN NIPPLE 8020' H9-518'X7"BKR ZXPLTPwITEBACKSLV, D=6.290' I Si I!, 8036' -19-5/8"X 7"BKR FLEXLOCK LNR HGR, ,.j •� D=6.230' 9-5/8"WHESTOCK(09/06/09) —I8197' 'l ,1 AA 1 -vs,• MLLOUT WINDOW(04-33A) 8197'-8214' • 9-5/8"CSG,47#,L-80 BTC,D=8.681" — 12682' , 7"LNR,26#,L-80,BTC TCI XO TO L-80 BTC-M —I 9172' K 12479' —14-1/2"HES X NP,D=3.813" PERFORATION SINMAARY REF LOG: ??? ANGLE AT TOP 1 : 91'@ 14050' 12509' H7"X 4-1/2"BKR S-3 PKR,D=3.875" Note:Refer to Production DB for historical perf data `� SIZE SPF IJTERVAL Opn/Sqz DATE 2-7/8" 6 14050-14160 0 09/22/09 \j ` 12543' —14-1/2"HES X NP,D=3.813" 2-7/8" 6 14200-14310 0 09/22/09 2-7/8" 6 14370-14430 0 09/22/09 2-7/8" 6 15130-15160 0 09/22/09 12613' —I4-1/2"HES XN NP,D=3.725" 2-7/8" 6 15195-15350 0 09/22/09 2-7/8" 6 15380-15420 0 09/22/09 12619' H 7"X 5"HRD ZXPN LTP w/ 2-7/8" 6 15500-15520 0 09/22/09TTIEBACK SLV,D=4.460' 2-7/8" 6 15540-15650 0 09/22/09 \ 12625' H4-1/2"WLEG,D=3.958" t III ` 12635' 17"X 5"BKR FLEXLOCK 'Silk LNR HGR,D=4.450" 4-1/2"TBG,12.6#,13CR-85 VAM TOP,-0152 bpf,ID=3-958" —I 12625' 12645' —5-1/2"X 4-1/2" 4-1/2"LNR, 12.6#,13CR-85 VAM TOP XO TO L-80 BT-M — 12650' XO,ID=3.958" 7"LNR,26#,L-80 BTC-M,-0383 bpf,113=6.276" H 12783' , III 111) 1/4 PBTD H 15842' 11\4,4` 4-1/2"LNR,12.6#,L-80 BT-M,.0152 bpf,D=3.958" H 15923' DATE REV BY CONSENTS DATE REV BY COMvBJTS R?UDHOE BAY UNT 03/18/86 ORIGINAL COMPLETION 01/02/11 WECIPJC GLV C/O(12/17/10) WELL: 04-33A 04/18/94 N2ES RWO REilvITNo:'r2090800 09/24/09 N7ES SIDETRACK(04-33A) AR No: 50-029-21545-01-00 09/29/09 SV DRLG HO CORRECTIONS SEC 26,T11 N,R15 E,678'FSL 303'FWL 10/08/09 DAV/SV GLV C/O(09/30/09) 05/10/10 JR/JMJ DRLG DRAFT CORRECTIONS BP Exploration(Alaska) 0 0 _ _ y 1 L I 1 1 1 a� I 2 2 1 2 - - 0 II VI all I I ._ 01 I C. 4 a. I 4 :' / I ei' I 1 t', r I �":� :R��: :M��: 1 1 = 1 "-' I. a w. c genie Iii \\\\\\\\\\\\\\\\\ uw w m ;---2 ....•• * i 2 ,. p I o C7 x e I I N 0 In d .� I I, I Z , iC '':,, I i < `.,',, Milt Z y� I 1 I O I f 1 g I • !I I u I U ` v !i.l II .1 I_ '\ I Ce C) s I :I i 1 \\ u z I 1' 1 WL. .., 1 "� ...: 05 I � f :,_,C o I i \ Z I :... ....: II f Y \ li I M a x : I V lid I Za I I Fr• g �' a g,gym a U V\ I .. a 2r .. t I1 . I 1 i_ , ; i °o I _ _ �� f CI IX o z -1 _ �I 1 1 Z z a $ I u Z a I _1 i I -, 0 MI i LI Ii ii 1 Et I 0 I s 11 I t .1 i k. 1 s „I 1I .Q • • • 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 in the Patricia or Steve V upper left corner of Form 10-403 is checked. If the "Abandon" 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 Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on —� both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then d check the "Suspended" box and initial that change. Guy or Victoria 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 for Jenni Redrill" box, she 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, she will check the History tab Jenni 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, she 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 change Jenni 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 Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve 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. • • Roby, David S (DOA) From: Ciolkosz, Ryan R <Ryan.Cioikoszcwoo.corn Sent: Wednesday, October 21, 2015 7:28 AM To: Roby, David S (DOA) Subject: RE: Sundry application for PBU 04-33A (PTD 209-080) 1) Can you explain what's causing/caused this odd production behavior? When the 04-33A was continuously online there was a fine balance of drawdown of gas from the north and water from the south. While 04-33A was offline the injector, 04-20 continued to push water and oil towards the producer. Once 04-33A came back online it had to produce out some higher water cut oil before it got back to the higher oil rates that were seen before it was recently SI. It has struggled to bring in the gas from the north after being shut in during late 2014 early 2015. We do not feel that there is any odd behavior from this well. In your application it references a production rate of 180 bbls/day, but I don't see any evidence that the ?roauction rate has been that low, at least not for an extended period of time. Can you explain where this 180 bbls/day is coming from? The current value of the well is 180108 as stated in the Sundry. The production is not 180 bbls/day. The difference between IOR and production is due to facility backout. Roby, please see the response from our reservoir engineer above. Let me know if you have any other questions. Thanks, Ryan From: Roby, David S (DOA) [mailto:dave.robyOalaska.gov] Sent: Friday, October 16, 2015 6:09 PM To: Ciolkosz, Ryan R Subject: Sundry application for PBU 04-33A (PTD 209-080) I'm reviewing the above referenced sundry application to plug the well and prepare it for redrill and have noticed some odd things in the production data for the well. According to the production data in our database the well oroauce - more or less continuously from the time it was initially completed until September 2014. For the majority of this time it produced in the neighborhood of 350 BOPD with a water cut of approximately 95%. GOR increased more or less steadily until early last year,when it peaked at about 25 mcf/stb and then began slowly decline to about 15 mcf/stb at the time the well was shut in. The well was brought back on production in March of this year producing about 200 BOPD less than before it was shut in and with a GOR that dropped to about 10 mcf/stb, but with similar water cut. The water cut hasn't changed much but since being brought back but the GOR dropped almost to nothing in just a few months and the oil production climbed back into the 400-450 BOPD range. I have a couple of questions for you: 1) Can you explain what's causing/caused this odd production behavior? 2) In your application it references a production rate of 180 bbls/day, but I don't see any evidence that the production rate has been that low,at least not for an extended period of time. Can you explain where this 180 bbls/day is coming from? Thanks, Dave Roby • Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments.contains information from the Alaska Oil and Gas Conservatior Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privilegeo information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.roby@alaska,aov. 2 05/06/11 Schlumberger NO. 5738 Alaska Data 8. Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD P2 -16 BBSK -00061 USIT - - • 04/04/11 1 1 1.35/0 -25 _ BBKA -00101 PRODUCTIeNPROFILE - - - , r i ur,, - 1 P2-52 BJGT -00027 CROSS FLOW CHECK 'Yrka, V 04/14/11 1 Ol _ 1 03-37 BJGT -00028 INJECTION PROFILE VT .A\. ✓ 1 3 w 04/16/11 1 (/ 1 2- 42/P -13 BAUJ -00076 MEMLDL / lff( — /L/ 04/15/11 1 / 1 N -11C BH4H -00048 PRODUCTION PROFILE �C j lL f ,It. 04/19/11 1 1 -1(O e 1 02 -12C BD88 -00098 MEM CBL ,411 d 04/21/11 / /Lj 1 1 S -120 BD88 -00100 MEM INJECTION PROFILE ():71-0 '3 `_1 Q4t" 04/25/11 1 Lay /1- 1 P1-09 BJOH -00024 PRODUCTION PROFILE / /Q4, -- / 05/01/11 1 /C/4 1 P1 -09 BJOH -00024 SCMT / C:r(p - 05/02/11 p 603 1 1 • P2-43 BG4H -00049 SCMT c --()' Cl" 04/28/11 I (p/5 1 1 16 -21 BJGT -00030 PRODUCTION PROFILE 175 A TP 04/28/11 1 1 71( I 7.''''''-'?*. 09-26 -33 BD88 -00104 MEM LDL I 61-63 04/30/11 1 / 1 04 -33A BLPO.00095 MEM PRODUCTION PROFIL W (')'�{(� 04/30/11 1 / Go j 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services I !, Petrotechntcal Data Center LR2 -1 900 E Benson Blvd Anchorage, ambl Street, -283 400 Anchorr A 9 age, AK 99503-2838 3 -2838 - 30 ) 120't • ■ ■
