Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
203-125
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM! WELL OMPLETION OR RECOMPLETION REPO AND LOG 1a. Well Status: Oil 0 Gas ❑ SPLUG 0 Other 0 Abandoned LZ ° Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ® Exploratory ❑ GINJ 0 WINJ ❑ WAG 0 WDSPL ❑ No.of Completions: Zero ° Service ❑ Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 8/24/2016 • 203-125 ' 316-261 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 8/31/2003 50-029-20446-01-00' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: . 9/5/2003 PBU 02-14A• • Surface: 4713'FSL,851'FWL,Sec.36,T11N,R14E,UM 9 Ref Elevations KB 57.93 - 17. Field/Pool(s): Top of Productive Interval: 1383'FNL,1501'FEL,Sec.35,T11N,R14E,UM GL 31 • BF 31.61 PRUDHOE BAY,PRUDHOE OIL• Total Depth: 1421'FNL,134'FWL,Sec.36,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 9471'/8759' • ADL 028308 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 687592 • y- 5950634 • Zone - ASP 4 . • 11880'/8995' . 74-017 TPI: x- 685262 y- 5949759 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 686897 y- 5949761 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No RI 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) • 9248'/8554' • 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,RES,ABI SCANNED FEB 2 7 2017 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 27' 108' 27' 108' 30" 431 sx Arctic Set 13-3/8" 72# N-80 26' 2711' 26' 2711' 17-1/2" 2300 sx Fondu,400 sx PF'C' 9-5/8" 47# L-80 24' 9248' 24' 8554' 12-1/4" 1100 sx Class'G',300 sx PF'C' 7" 26 L-80 2813' 9248' 2813' 8554' Scab Liner 356 sx Class'G',348 sx Class'G' 4-1/2" 12.6# L-80 9072' 11879' 8378' 8995' 6-1/8" 348 sx Class'G' 24. Open to production or injection? Yes 0 No 0 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#13Cr85 8875' 8641'/7948' x 4-1/2"12.6#L-80 8819'/8125' SBR)Oa OD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ECDATE ,I ireD Was hydraulic fracturing used during completion? Yes 0 No H • p ZLl Per 20 AAC 25.283(i)(2)attach electronic and printed O 1 L information SP i 5 2016 VERIFIED D L DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LA.- AO G CC See Attached 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 .....40' Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only U 1 l n/7/! �(. /o /� 0 L- SEP 16 2016 .../•` - int-,,,,t... �� RBDMSC1 28. CORE DATA Conventional Core(s) Yes 0 No 0 • Sidewall Cores Yes 0 No l 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 El Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9565' 8825 separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4 9204' 8510' CGL-Zone 3 9390' 8688' Base of CGL-Zone 2C 9465' 8754' 23SB-Zone 2B 9565' 8825' 21 TS-Zone 2A 9734' 8919' Zone 1B 9851' 8974' Zone 1A 9942' 9005' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Workover,Summary of Daily Reports,Summary of Pre-Rig Work,Summary of Daily Drilling Reports, Wellbore 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 MC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Hyatt,Trevor Email: Trevor.Hyatt©bp.com Printed Name: Joe Lastufk Title: Drilling Technologist //�� , r Signature: J Phone: +1 907 564 4091 Date:v//14-/i INSTRUCTIONS i ' I 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 ND 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 • i WELL NAME: 02-14A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8754' Cut and Pull Tubing 8762' Run 4-1/2" 12.6# 13Cr85 Tubing 10000' Fish: CIBP Milled and Pushed 9471' Set Whipstock • 02-14A Well History (Pre-Rig Workover) CTtVITYOt ***WELL SHUT IN ON ARRIVAL*** (HES E-LINE -TUBING PUNCH, RCT) INITIAL T/I/O = 0/0/0. RUN 1: RIH W/2' x 2", 4 SPF, 0 DEG PHASE TUBING PUNCHER. PUNCH TUBING FROM 8758'-8760' MD. RUN 2: RIH W/ RCT. CUT TUBING AT 8754' MD. GOOD INDICATION OF CUT.ALL RUNS CORRELATED TO TUBING SUMMARY 5/22/2016 DATED 8-SEPT-2003.FINAL T/I/O = 0/0/0. T/I/0=20/70/25 (RWO CAPITAL) CMIT-TxIA**PASSED** 1st attempt Pumped 15.4 bbls of diesel to achieve test pressure. 1st 15 min TBG/ IA lost 28/28 psi. 2 nd 15 min TBG/IA lost 16/16 psi. For a total loss of 44/44 psi in a 30 min test. Bleed TBG/IA pressure, Bled back- 14.5 bbls, AFE sign and tags hung on well, Valve position @ departure-WV, SV, 5/23/2016 SSV= Closed MV= Open IA& OA= OTG, FWHP= 17/70/27 T/I/O=110/110Nac. Pre-Parker 272. Set 5" "K" BPV#606 at 125", BPV LTT (Pass) . PT tree cap to 500 psi. (Pass) ***Job Incomplete ***See log. Final WHP's BPV/110/0. Note: 6/21/2016 Tree, wellbore, and annulus is fluid packed. T/I/O = BPV/128/23. Pumped up tubing through the IA to 250 psi. Remove 5x7 upper tree. Install 5x7 dry hole temp. valve#53 . Installed piggybacks IA Temp#81 .OA Temp#58 .Torqued & PT'd to API specs. PASS.Bled tubing, IA, OA to zero. Evacuated fluid down to MV gate. Installed tree cap & PT'd to 500 psi. PASS.RDMO ***Job complete***see log for 6/22/2016 details. FWHP= 0/0/0. T/I/O = 58/58/0. Temp = SI. IA FL (API request). Well is disconnected from the system. IA FL @ 108' (6 Bbls). 6/22/2016 API in control of well head upon departure. 02:15 T/I/O = BPV/28/0+. Temp = SI. Bleed WHPs to 0 (Pre rig). No AL, wellhouse, flowline or scaffolding. Dryhole tree installed. IA FL @ 108' (6 bbls). OA FL @ surface. Bled the OA from 0+ psi to 0 psi in 1 minute (fluid, 1 gallon). Bled the IAP from 28 psi to 0 psi in 10 minutes (all gas). Monitored the WHPs for 30 minutes. No change in the IA or OAP. FWPs= BPV/0/0. 6/28/2016 SV, MV= ?. IA, OA= OTG. 1100 hrs. T/I/O = ?/28/0+. Temp = SI. Bleed WHPs to 0 psi. (Pre Rig). No AL, wellhouse or scaffolding. Dryhole tree installed. IA FL = 108' (6 bbls). OA FL @ surface. Bled the OAP 6/28/2016 from 0+ psi to 0 psi in 1 minute (1 gallon, all fluid). Bled the IAP from 28 psi to T/I/O = BPV/33/11. Temp = SI. WHPs (Pre Rig). No AL, wellhouse, flowline or scaffolding. lAp increased 33 psi, OAP increased 11 psi since 6/28/16. 7/4/2016 SV= C. MV= 0. IA, OA= OTG. 1630 T/I/O=BPV/60/0 Pulled 5" Gray"K" BPV#606 through tree. FWP's 60/60/0 see log for 7/14/2016 details. 7/15/2016 T/I/0=60/60/0 Installed 5"Temp. ASV#11 FWP's 60/60/0 see logford details eta s T/I/0=48/61/15 Temp=SI Circ-Out(Pre RWO) Safety drill Spear in to TBG with 2 bbls of meth followed by 589 bbls of 130* Sea H2o down TBG up IA returns to 02-15 SSV shut 7/22/2016 crow valve shut casing valves open to gauges Final Whp's=103/108/64 T/I/O= VAC/0/0. Set 5" K BPV#606 @113". RD ASV#11. RDMO. Final T/I/O= BPV/0/0. 7/23/2016 ***Job Complete***. See log for details. T/I/O = BPVNAC/40. Temp = SI. WHP's (Pre Rig). No AL, flowline, well house, scaffolding. 7/23/2016 SV= ? (Unable to reach). MV= 0. IA, OA= OTG. 08:30. T/I/O= BPV/0/0. RU ASV#4. Pull 5" K BPV#606 ©113". PT'd 5000 (Passed). RDMO. 7/25/2016 Final T/I/O= VAC/0/0. ***Job Complete***. See log for details. T/I/O=0/0/30 Temp = S/I Circ Out (CTD) Pumped down TBG up IA taking returns to 02-15 F-line Spear in to TBG with 2 bbls of meth followed by 596 bbls of 120* Sea H2O SSV shut 7/25/2016 crown valve shut casing valves open to gauges Final Whp's=144/161/66 • • 02-14A Well History (Pre-Rig Workover) T/I/O =VAC/VAC/100. Set 5" Gray BPV#606 @ 113", Set Good. Performed LTT on BPV (PASS). RD ASV#04. Install Tree Cap Assembly. See Log For Details. ***JOB 7/25/2016 COMPLETE*** FWHP's = BPV/VAC/O. • • North America-ALASKA-BP Page 1 of 7 Operation Summary Report Common Well Name:02-14 AFE No Event Type:WORKOVER(WO) Start Date:7/25/2016 End Date:7/29/2016 jX3-017W4-C:(1,927,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:5/21/1980 12:00:00AM Rig Release:7/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292044600 Active datum:2-14A:@57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 7/25/2016 03:00 - 06:00 3.00 MOB P PRE BEGIN EVENT WITH PARKER RIG 272 AT 03:00 ON 7/25/16 GENERAL RIG DOWN OPERATIONS ON L1-13 -SECURE TOP DRIVE AND BRIDLE UP -PERFORM DERRICK INSPECTION -RIG DOWN RIG FLOOR AND SECURE [FORUM CRANE 06:00 - 07:00 1.00 MOB P PRE LOWER PIPE CAT. SKID CATTLE CHUTE AND RIG FLOOR. 07:00 - 07:30 0.50 MOB P PRE LOWER MAST -365 KLBS HOOKLOAD PRIOR TO LANDING ON DERRICK STAND 07:30 - 09:00 1.50 MOB P PRE RIG DOWN INTERCONNECTS. ORIENT TIRES AND INSTALL TIE-RODS. 09:00 - 12:00 3.00 MOB P PRE SEPARATE MODULES AND BACK OFF OF L1-13. STAGE MODULES ON DRILLSITE AND MAKE FINAL PREPARATIONS FOR RIG MOVE I-MINOR DELAY WITH MUD MODULE DUE TO SINKING TIRES 3-4'INTO PAD BUILDUP. ABLE TO JACK RIG UP AND LAY CRIBBING TO PROCEED AHEAD. 12:00 - 16:30 4.50 MOB P PRE .MOVE RIG FROM L1 TO DS02 5.2 MILES -REMOVE DUMMY WELLHOUSE OFF L1 WITH LOADER,SEND TO DS02 ON TRUCKAND SET OVER 02-14 WITH LOADER. 16:30 - 18:00 1.50 MOB P PRE SPOT MODULES -BACK DRILL MOD OVER DUMMY WELLHOUSE. SPOT MUD MOD AND UTILITY MOD NEXT TO DRILL MODULE. SHIME ALL THREE TO LEVEL. 18:00 - 20:00 2.00 RIGU P PRE GENERAL RIG UP OPERATIONS -RIG UP ELECTRICAL INTERCONNECTS. SWAP OVER TO MAIN GENERATORS -PRE-MAST RAISING CHECKLISTS ANS !SAFETY MEETING 20:00 - 20:30 0.50 RIGU P PRE RAISE MAST -520 KLBS HOOKLOAD OF STAND 20:30 - 21:30 , 1.00 RIGU P PRE SKID RIG FLOOR AND CATTLE CHUTE. RAISE PIPE CAT. 21:30 - 00:00 2.50 RIGU P PRE GENERAL RIG UP OPERATIONS -RIG UP RIG FLOOR AND FLUID INTERCONNECTS -BRIDLE DOWN AND HOOKUP TOP DRIVE TO BLOCKS -TAKE ON 290 BBLS 120°F 8.5 PPG SEAWATER. QUADCO REP ON LOCATION TO CALBIRATE PIT SENSORS. 7/26/2016 00:00 - 02:00 2.00 RIGU P PRE GENERAL RIG UP OPERATIONS -SKID DRILLER'S SIDE RIG FLOOR FOR FINAL ADJUSTMENT -TAKE ON 290 BBLS 120°F 8.5PPG SEAWATER -QUADCO REP CALBIRATE PITAND FLOW SENSORS -RIG UP SURFACE LINES AND RIG TONGS -RIG UP SECONDARY KILL TO IA -INSTALL FLOORING IN WELLHOUSE Printed 9/6/2016 1:13:47PM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 2 of 7 Operation Summary Report Common Well Name:02-14 AFE No Event Type:WORKOVER(WO) Start Date:7/25/2016 End Date:7/29/2016 X3-017W4-C:(1,927,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/me:5/21/1980 12:00:00AM Rig Release:7/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292044600 Active datum:2-14A:@57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:30 2.50 RIGU P PRE !ACCEPT RIG AT 02:00 PRESSURE TEST BPV FROM BELOW TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH TO ESTABLISH BARRIERS FOR NIPPLE DOWN(PASSING TESTS) -RIG UP AND PRESSURE CROSSCHECK PERFORM LEAKTIGHT PRESSURE OF SURFACE LINES AGAINST IA VALVES(3500 PSI) -5 BBLS TO PRESSURE UP AND BLEED BACK -CONFIRM NO FLOW PAST BPV INTO TREE AND NO PRESSURE BUILDUP ON OA. 04:30 - 05:00 0.50 RIGU P PRE RIG EVACUATION DRILL AND AAR WITH YEAROUT CREW. 05:00 - 06:30 1.50 WHSUR P DECOMP NIPPLE DOWN FMC 7-1/16"X 5-1/8"5K TREE AND 13-5/8"X 7-1/16"5K ADAPTER FLANGE -CAMERON REP BLEED OFF ADAPTER VOID -MAKEUP 5-7/8"RH ACME CROSSOVER WITH 18 TURNS. HANGER THREADS IN GOOD CONDITION -INSTALL GRAY TEST DART IN BPV FOR TESTING BOP AGAINST 06:30 - 10:00 3.50 BOPSUR P DECOMP NIPPLE UP HIGH PRESSURE RISERS AND BOPE -13-5/8"5K SHAFFER ANNULAR PREVENTER -5K CAMERON 2-7/8"X 5"VBRS -5K CAMERON BLIND-SHEAR RAMS -MUD CROSS -5K CAMERON 3-1/2"X 5-7/8"VBRS 10:00 - 11:00 1.00 BOPSUR P DECOMP RIG UP TO TEST BOPE. FILL SYSTEM WITH WATER AND SHELL TEST. 11:00 - 16:00 5.00 BOPSUR P DECOMP PRESSURE TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH TO BP STANDARDS AND AOGCC REGULATIONS. -AOGCC REP CHUCK SCHEVE WAIVES STATE'S RIGHT TO WITNESS TEST -NO FAILURES,SEE ATTACHED DOCUMENTATION -TEST WITH 4"(ANNULAR+RAMS)&4-1/2" (RAMS) 16:00 - 16:30 0.50 BOPSUR P DECOMP RIG DOWN AFTER BOPE TESTING 16:30 - 18:00 1.50 WHSUR P DECOMP RIG UP DUTCH RISER AND VALVE SHOP LUBRICATOR WITH QUICK TEST SUB. PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS PER LEAKTIGHT CRITERIA). UNSTAB&STANDBACK LUBRICATOR. 18:00 - 20:30 2.50 WHSUR N SFAL 41.00 DECOMP UNSUCCESSFULLY ATTEMPT TO PULL VETCO GRAY TEST DART WITH T-BAR. UNABLE TO I ENGAGE DART. CALLOUT SLB FISHING MAGNET T RECOMMENDATION OF VALVE SHOP COORDINATOR. 20:30 - 21:00 0.50 WHSUR P DECOMP MAKEUP 5-3/4"SLB MAGNET FISHING ASSEMBLY AND RUN IN HOLE THROUGH DUTCH RISER. RETRIEVE GRAY TEST DART ON FIRST ATTEMPT. -DART FOUND TO BE FULL OF CLOBBERED MUD,WHICH PREVENTED T-BAR FROM ENGAGING DART Printed 9/6/2016 1:13:47PM `AII depths reported in Drillers Depths* P P P • • North America-ALASKA-BP Page 3 of 7 Operation Summary Report Common Well Name:02-14 AFE No Event Type:WORKOVER(WO) Start Date:7/25/2016 End Date:7/29/2016 X3-017W4-C:(1,927,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud DateTme:5/21/1980 12:00:00AM Rig Release:7/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292044600 Active datum:2-14A:©57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (usft) 21:00 - 22:30 1.50 WHSUR P DECOMP MAKEUP LUBRICATOR TO QUICK TEST SUB. PRESSURE TEST QUICK TEST SUB TO 250/3500 PSI(PASS). PULL 5"TYPE K BPV. NO PRESSURE BELOW PLUG. 22:30 - 23:30 1.00 WHSUR P DECOMP RDMO VALVE SHOP LUBRICATOR AND DUTCH RISER 23:30 - 00:00 0.50 PULL P DECOMP MAKEUP 4-1/2"SLB SPEAR ASSEMBLY 7/27/2016 00:00 - 01:00 1.00 PULL P DECOMP PULL 4-1/2"TUBING HANGER TO RIG FLOOR: -RUN IN HOLE WITH 4-1/2"SLB SPEAR ASSEMBLY. -ENGAGE TUBING BELOW HANGER CROSSOVER. VERIFY SPEAR ENGAGED WITH 28KLBS OVERPULL. -CAMERON REP BACKOUT LOCKDOWN SCREWS. -UNSEAT HANGER WITH 150 KLBS. PICKUP WEIGHT OF STRING=136 KLBS. NO FLOW FROM WELL AFTER UNSEATING HANGER. PULL HANGER TO RIG FLOOR(ALL COMPONENTS RECOVERED). 01:00 - 02:00 1.00 PULL P DECOMP WITH HANGER AT RIG FLOOR AND WHILE STILL ENGAGED WITH SPEAR,CIRCULATE BOTTOMS UP(261 BBLS)THROUGH CHOKE AGAINST ANNULAR PREVENTER. -8 BPM,1780 PSI -MW IN/OUT=8.5 PPG j-FLOWCHECK WELL FOR 10 MIN AFTER PUMPS DOWN(STATIC) 02:00 - 03:30 1.50 PULL P DECOMP DISENGAGE SLB SPEAR AND LAYDOWN HANGER+PUP ASSEMBLY 03:30 - 08:00 4.50 PULL P DECOMP LAYDOWN 4-1/2",12.6#,L-80,IBT-M TUBING FROM CUT AT 8754'ELMD TO 4500'MD -BREAKOUT TORQUE=3-8 KFT-LBS I-INITIAL PICKUP WEIGHT AT 8755'MD=136 KLBS(MATCHED WEIGHT WHEN SET IN 2003) -FINAL PICKUP WEIGHT AT 4500'MD=83 KLBS(48 KLBS TUBING WEIGHT) 08:00 - 10:00 2.00 PULL P DECOMP HANGOFF 4-1/2"TUBING ON 9-5/8"HES STORM PACKER AT 50'BELOW WELLHEAD -PRESSURE TEST RTTS FROM ABOVE AGAINST BLIND RAMS TO 250 PSI LOW AND [3500 PSI HIGH FOR FIVE MINE(PASSING TESTS,SEE ATTACHED CHARD. 10:00 - 13:30 3.50 BOPSUR P DECOMP NIPPLE DOWN BOP STACK AT BASE OF BOP DECK. SET STACK BACK. NIPPLE DOWN HIGH PRESSURE RISERS AT TOP OF TBING i SPOOL. LIFT TUBING SPOOL OFF WELLHEAD WITH RISERS,THEN LOWER DOWN TUBING SPOOL TO GROUND. LIFT HIGH PRESSURE RISERS TO RIG FLOOR FOR WELLHEAD WORK. -SIMOPS: CHANGE SAVER SUB ON TOP I DRIVE TO HT38 13:30 - 15:30 2.00 WHSUR P DECOMP REPLACE GRAY 9-5/8"IC PACKOFF -NOTE: OA WAS MONITORING FOR PRESSURE FOR>6 HOURS PRIOR TO PACKOFF CHANGEOUT. 0 PSI PRESSURE DURING ENTIRE MONITOR. Printed 9/6/2016 1:13:47PM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 4 of 7 Operation Summary Report Common Well Name:02-14 AFE No Event Type:WORKOVER(WO) Start Date:7/25/2016 End Date:7/29/2016 X3-017W4-C:(1,927,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:5/21/1980 12:00:00AM Rig Release:7/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292044600 Active datum:2-14A:@57.93usft(above Mean Sea Level) Date From-To Hrs j Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 17:30 2.00 WHSUR P DECOMP NIPPLE UP NEW GRAY"T2S"13-5/8"5K TUBING SPOOL. 1-CAMERON REP PRESSURE TEST NEW9-5/8" IC PACKOFF AND LOWER FLANGE BREAK(AT BASE OF TBG SPOOL)TO 250 PSI LOW FOR FIVE MIN ADN 3500 PSI HIGH FOR 15 MIN (PASSING TESTS,SEE ATTACHED CHARTS). RECEIVE APPROVAL TO PROCEED FROM WSUP FOR PACKOFF TEST. 17:30 - 20:30 3.00 BOPSUR P DECOMP NIPPLE UP BOP STACK AND HIGH PRESSURE RISERS ON NEW TUBING SPOOL 20:30 - 21:30 1.00 BOPSUR P DECOMP TEST BREAKS ON BOP STACK+NEW IA SECONDARY WORKING GATE VALVE TO 250 PSI LOWAND 3500 PSI HIGH FOR FIVE MIN l EACH(PASSING TESTS,SEE ATTACHED CHART). -TEST AGAINST RTTS AND BLIND RAMS 21:30 - 22:30 1.00 PULL P DECOMP PULL STORM PACKER AND LAYDOWN -MAKEUP CLOSED FOSV TO TOP OF STAND OF DRILLPIPE. RUN STAND IN AND ENGAGE STORM PACKER WITH 22 TURNS. MAKEUP TOP DRIVE AND OPEN FOSVE TO CHECK FOR PRESSURE(NO PRESSURE). BREAKOUT TOP DRIVE. CLOSE ANNULAR PREVENTER AND PICKUP ON STRING TO UNSEAT STORM PACKER. ALLOW PACKER ELEMENTS TO RELAX FOR FIVE MIN AND CHECK FOR PRESSURE UNDER ANNULAR PREVENTER(NO PRESSURE). OPEN ANNULAR. -PULL STORM PACKER TO RIG FLOOR AND LAYDOWN. 22:30 23:00 0.50 PULL P DECOMP RIG UP TO PULL TUBING -DOYON CASING POWER TONGS,SWAP ELEVATORS 23:00 - 00:00 1.00 PULL P DECOMP LAYDOWN 4-1/2",12.6#,L-80,IBT-M TUBING FROM 4500'MD TO 4000'MD AT MIDNIGHT -COMPLETE LAYING DOWN ON 7/28/16 I-MW IN/OUT=8.5 PPG 7/28/2016 00:00 - 03:30 3.50 PULL P DECOMP LAYDOWN 4-1/2",12.6#,L-80,IBT-M TUBING FROM 4000'MD AT MIDNIGHT TO SURFACE. 1-NO SIGN OF HOLE AROUND 6163'MD IN STRING -(208)TOTAL JOINTS RECOVERED+TUBING HANGER ASSY,(3)GLM ASSYS+(1)X NIPPLE ,ASSY -6.5'CUT JOINT(AS EXPECTED). EXCELLENT CUT WITH NO FLARE(4.5"OD) -MAJORITY OF PIN-END THREADS OBSERVED TO BE HEAVILY CORRODED -ALL EQUIPMENT TESTED FOR NORM PRIOR TO LEAVING LOCATION(NO NORM DETECTED) 03:30 - 04:30 1.00 RUNCOM P RUNCMP RIG UP TO RUN TUBING -DOYON CASING WITH POWER TONGS AND TORQUE TURN EQUIPMENT. I-CONFIRM PIPE COUNT IN PIPE BARN. Printed 9/6/2016 1:13:47PM `AII depths reported in Drillers Depths* r • North America-ALASKA-BP Page 5 of 7 Operation Summary Report Common Well Name:02-14 AFE No Event Type:WORKOVER(WO) Start Date:7/25/2016 End Date:7/29/2016 X3-017W4-C:(1,927,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:5/21/1980 12:00:00AM Rig Release:7/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292044600 Active datum:2-14A:©57.93usft(above Mean Sea Level) Date From-To Hrs ! Task Code NPT NPT Depth ' Phase Description of Operations (hr) (usft) 04:30 - 15:30 11.00 RUNCOM P RUNCMP RUN 4-1/2",12.6#,13CR,VAMTOP COMPLETION ASSEMBLY FROM SURFACE TO PLANNED SET DEPTH AT 8781'MD(8754'MD CUT DEPTH ON 2003 N2ES TALLY+19' CORRECTION FOR P272 RKB+8'SWALLOW) FLOWCHECK WELL PRIOR TO RUNNING IN HOLE(STATIC) -BAKERLOKALL CONNECTIONS BELOW PACKER -APPLY JET LUBE SEAL GUARD AND TORQUE TURN VAMTOP CONNECTIONS TO OPT MU TORQUE OF 4440 FT-LBS •-MW IN/OUT=8.5 PPG SEAWATER INITIAL TAG UP DESCRIPTION: -RUN IN HOLE WITH JOINT#203. NO SIGN OF TUBING STUB WHEN OVERSHOT END PASSES OVER. -SET DOWN ON 1ST SET OF SHEAR PINS AT 4'BACK IN OVERSHOT. SHEAR PINS WITH 21 KLBS DOWN. RUN IN ADDITIONAL 4'WITH DECREASING SLACKOFF WEIGHT FROM 120 I KLBS DOWN TO 97 KLBS. PICKUP AND PULL OVERSHOT OFF STUB WITH 26 KLBS OVERPULL 15:30 - 18:00 2.50 RUNCOM P RUNCMP SPACEOUT AND LAND 4-1/2"PRODUCTION !TUBING -LAYDOWN JOINTS 203,202,&201. PICKUP 19.85'AND 5.82'PUP JOINTS,JOINT 201, GRAY GEN II TUBING HANGER ASSEMBLY AND LANDING JOINT. -RUN IN HOLE TO LAND,NO DRAG OBSERVED WITH FIRST 4'OF OVERSHOT OVER STUB. 2 KLBS STEADY DRAG FOR NEXT 2'OF TRAVEL. DECREASING SLACKOFF WEIGHT FROM 118 KLBS TO 103 KLBS OVER FINAL 2'UNTIL FINAL LANDING DEPTH AT 8781'MD(8"OF OVERSHOT SWALLOW). -WITH 8'OF SWALLOW,TUBING TAIL IS SPACED OUT 6.5'FROM NO-GO AT TOP OF OVERSHOT -FINAL PICKUP WEIGHT=131 KLBS, SLACKOFF=120 KLBS(P272 BLOCKS+TD= 35 KLBS) -EXTRA TIME DUE TO SWAPPING POWER TONGS ON RIG FLOOR FOR MAKING UP 7" HANGER PUP XO TO 4-1/2"TUBING STRING. 18:00 - 19:30 1.50 RUNCOM P RUNCMP ,REVERSE CIRCULATE IN 280 BBLS 120°F !CORROSION-INHIBITED SEAWATER 3 BPM,680 PSI -AFTER 280 BBLS AWAY,LINEUP DOWN TUBING AND PUMP 5 BBLS LONG WAY TO CLEAN OFF RHC-M PLUG PROFILE-MW IN/OUT=8.5 PPG SEAWATER 19:30 - 20:00 0.50 RUNCOM P RUNCMP MAKEUP LANDING JOINT AND DROP STANDARD 1-7/8"BALL AND ROD. LAYDOWN LANDING JOINT WHILE ALLOWING BALL/ROD TO DROP FOR 15 MIN. PJSM FOR TESTING. -1.375"FISHING NECK. PULLING TOOL (ROD/BALL)=2"SB/RB,PULLING TOOL (RHC-M PLUG)=4.5"GS/GR Printed 9/6/2016 1:13:47PM "All depths reported in Drillers Depths* • North America-ALASKA-BP Page 6 of 7 Operation Summary Report Common Well Name:02-14 AFE No Event Type:WORKOVER(WO) Start Date:7/25/2016 End Date:7/29/2016 X3-017W4-C:(1,927,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:5/21/1980 12:00:OOAM Rig Release:7/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292044600 Active datum:2-14A:©57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 22:00 2.00 RUNCOM P RUNCMP SET PACKER AND PRESSURE TEST TUBING/IAAS FOLLOWS: CLOSE BLINDS AND PERFORM 250 PSI LOW TEST ON TUBING(PASS) -PRESSURE UP TO 3500 PSI ON TUBING WITH 2 BELS. SET PROD PACKER AT 3000 PSI. HOLD PRESSURE FOR 30 MIN(PASSING TEST) -LOSE 40 PSI IN FIRST 15 MIN,10 PSI IN SECOND 15 MIN -BLEED TUBING PRESSURE TO 2000 PSI -PRESSURE TEST IA TO 250 PSI LOW FOR FIVE MIN AND 3500 PSI HIGH FOR 30 MIN WITH 4 BBLS TO PRESSURE UP(PASSING TESTS) -LOSE 40 PSI IN FIRST 15 MIN,20 PSI IN SECOND 15 MIN BLEED OFF IA PRESSURE,THEN TUBING PRESSURE TO 0 PSI TO CONFIRM BLEED BACK VOLUMES. -RECEIVE AUTHORIZATION TO PROCEED FROM WSUP,SEE ATTACHED DOCUMENTATION. 22:00 - 22:30 0.50 RUNCOM P RUNCMP SHEAR DCK VALVE IN UPPER GLM AT 3838' MD -PRESSURE UP ON TUBING TO 2000 PSI, PRESSURE UP ON IA TO 3500 PSI -BLEED PRESSURE ON TUBING SIDE TO 0 PSI QUICKLY AND OBSERVE EQUALIZATION -CONFIRM 2-WAY CIRCULATION WITH 2.5 BPM©1080 PSI DOWN TUBING,2.5 BPM 1000 PSI DOWN IA 22:30 - 00:00 1.50 RUNCOM P RUNCMP FREEZE PROTECT TUBING AND IA TO 2200' MD WITH 152 BBLS 6.8 PPG DIESEL -PRESSURE TEST LINES TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH PER 'LEAKTIGHT CRITERIA(PASSING TESTS) -2.5 PSI,900 PSI ICP-1500 PSI FCP -WELL IS 300 PSI OVERBALANCE TO THE RESERVOIR PRESSURE -U-TUBE COMPLETED ON 7/29 7/29/2016 00:00 - 01:30 1.50 RUNCOM P RUNCMP ALLOW FREEZE PROTECT DIESEL TO U-TUBE FROM IA TO TUBING FOR 1 HOUR -CONFIRM NO PRESSURE/FLOWAT END OF U-TUBE -BLOWDOWN ALL LINES AND DRAIN BOP STACK AT END OF U-TUBE 01:30 - 02:30 1.00 RUNCOM P RUNCMP RIG UP DUTCH RISER AND VALVE SHOP HYDRAULIC LUBRICATOR -NO PRESSURE TEST BECAUSE OF USE ONLY FOR MECHANICALASSIST WITH LARGE PLUG 02:30 - 03:30 1.00 RUNCOM P RUNCMP SET 6"GRAY TYPE K BPV -PRESSURE TEST BPV FROM BELOW WITH DIESEL TO 250 PSI LOWAND 3500 PSI HIGH FOR 5 MIN EACH(PASSING TESTS,SEE ATTACHED CHART). 03:30 - 04:00 0.50 RUNCOM P RUNCMP RIG DOWN LUBRICATOR AND DUTCH RISER Printed 9/6/2016 1:13:47PM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 7 of 7 Operation Summary Report Common Well Name:02-14 AFE No Event Type:WORKOVER(WO) Start Date:7/25/2016 End Date:7/29/2016 X3-017W4-C:(1,927,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:5/21/1980 12:00:OOAM Rig Release:7/29/2016 Rig Contractor PARKER DRILLING CO. UWI:500292044600 Active datum:2-14A.@57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 05:30 1.50 BOPSUR P RUNCMP NIPPLE DOWN HIGH PRESSURE RISERS AND BOP STACK. -SIMOPS: RIG DOWN FLUID INTERCONNECTS AND BLOWDOWN MUD MODULE 05:30 - 09:00 3.50 WHSUR P RUNCMP NIPPLE UP NEW GRAY GEN 1113-5/T X 7-1/16" TUBING HEAD ADAPTER+NEW 7-1/16"X 6-3/8"CAMERON FLS DOUBLE MASTER DRYHOLE TREE. -CAMERON REP TEST TUBING HEAD VOID TO 250 PSI LOW FOR 5 MIN AND 4500 PSI HIGH FOR 15 MIN(PASSING TESTS APPROVED BY WSUP,SEE ATTACHED CHARTS) -RIG TEST DRYHOLE TREE WITH DIESEL TO 250 PSI LOWAND 4500 PSI HIGH FOR 5 MIN EACH(PASSING TESTS) -CAMERON REP PULL TEST DART WITH DRY ROD -EVACUATE ALL FLUID FROM TREE AND ADD DIESELL 911 TO TREE ON TOP OF BPV TO PREVENT FREEZING -INSTALL PROPER ANNULUS EQUIPMENT (SECONDARY VALVES LEFT ON FOR REMOVAL POST RIG) 09:00 - 12:00 3.00 RIGD P RUNCMP SECURE WELLAND CLEAN CELLAR ALL WELLHEAD AND TREE VALVES LEFT CLOSED TO GAUGES -FINAL T/I/O=0/0/0 PSI -HANDOVER COMPLETED WITH WELLS GROUP -CLOSEOUT WELLWORK TRANSFER PERMIT 'WITH DRILLSITE OPERATOR RELEASE PARKER RIG 272 AT 12:00 ON 7/29/16. NEXT PROJECT=RON EVENT ON L5-12A PERFORMANCE SUMMARY: -4.375 DAYS VS 6.70 DAYS TARGET,8.00 DAYS AFE -2.5 HOURS NPT,2.4%NPT VS 5%TARGET -1.60MM VS$1.615MM TARGET,$1.927MM AFE Printed 9/6/2016 1.13:47PM *All depths reported in Drillers Depths* ! A 02-14A Well History (Pre-Rig Sidetrack) ACTIVITYDAT• 9..91T4Tyl.," T/I/O= 0/0/0. Barriers= BPV x MV. RD piggyback valves= 3" IA TEMP#81 , 3" OA TEMP#58 . Installed tapped blind flanges. Torqued and PT'd TO API specs. RD dryhole 6" TEMP#62 . Installed 6" CIW upper tree serial#120420846-03 . Torqued and PT'd to API specs. Ran down polish rod, tagging @125" . Pulled BPV#612 and RD lubricator. Installed tree cap and PT'd to 500 psi against SV gate (PASSED) RDMO***Job Complete*** . SEE LOG FOR DETAILS. Final T/1/0=VAC/0/0. Note: Tree , wellbore and annulus are fluid packed. AOGCC testing required within 5 days of POP time due to 7/30/2016 component change, All tags and signage hung on appropiate valves to include AFE sign PULLED BALL& ROD FROM RHC IN X-NIPPLE @ 8,677' MD.PULLED BEK-DCK FROM ST#6 @ 3,818' MD.SET BK-DGLV IN ST#6 @ 3,818' MD.ATTEMPT TO MIT-IA TO 2,500psi.(tbg/ia communication). RAN 1.25" LIB TO ST#6 @ 3,818' MD.(recovered impression of bk latch) MADE MULTIPLE ATTEMPTS TO PULL BK-DGLV FROM ST#6 @ 3,818' MD.PULLED BK-DGLV FROM ST#6 @ 3,818' MD.SET BK-DGLV IN ST#6 @ 3,818' MD.PERFORM 8/2/2016 PASSING MIT-IA TO 2,500# (see log). ***CONTINUE WSR FROM 08/02/2016*** (ctd). PULLED 4-1/2" RHC PLUG BODY FROM X-NIPPLE AT 8,677' MD.RAN 3.50" LIB, TOOLS S/D @ 9,109' SLM.(impressions of debris on outside edge).RAN 10' x 2.50" PUMP BAILER, TOOLS S/D @ 9,119' SLM.(recovered —1 gallon of mud). BRUSHED TBG W/4-1/2" BRUSH & 3.70" GAUGE RING TO 9,116' SLM. MADE MULTIPLE RUNS W/ 10' x 3.00" PUMP BAILER TO 9,117' SLM.(recovered —6 gallons of mud) RAN 3.62" BARBELL & 3.25" LIB, TAGGED 4-1/2" EZ DRILL CIBP @ 9,113' 8/3/2016 SLM.(recovered impression of cibp). CTU 9w/ 1.75" CT Job Objective: Mill XN Nipple, Mill CIBP, WS Drift MIRU. Perform weekly BOP test. Make up and RIH with 3.800" LH diamond parabolic milling BHA. Tag XN at 8865. Milled through. Dry drifted with 3.800" centralizer. POOH. OOH with LH milling BHA. Centralizer is still a 3.800" NO-GO with a gauge ring. Standby 8/5/2016 for scaffolding; high winds prevented use of man lift. MU BOT RH 3.70"Junk Mill BHA and CTU 9 w/ 1.75" CT Job Objective: Mill XN Nipple, Mill CIBP, WS Drift MIRU. Perform weekly BOP test. Make up and RIH with 3.800" LH diamond parabolic milling BHA. Tag XN at 8865. Milled through. Dry drifted with 3.800" centralizer. POOH. 8/5/2016 OOH with LH milling BHA. Centralizer is still a 3.800" NO-GO with a gauge ring. CTU 9 w/ 1.75" CT Job Objective: Mill XN Nipple, Mill CIBP, WS Drift***Job Continued from WSR 8/5/16*** RIH with BOT RH 3.70" Junk Mill BHA. Tag CIBP at 9,110, mill plug and push to 10,000'. 8/6/2016 POOH and lay down milling BHA. MU BOT 3.70"Whipstock BHA. CTU 9 w/ 1.75" CT Job Objective: Mill XN Nipple, Mill CIBP, WS Drift***Job Continued from WSR 8/5/16*** RIH with BOT RH 3.70" Junk Mill BHA. Tag CIBP at 9,110 (originally set 6/9/15 @ 9121' SLM), mill plug and push to 10,000'. POOH and lay down milling BHA. MU BOT 3.70" Whipstock BHA, OAL: 30.67'. Drifted down to 9602 CTMD. POOH. OOH with drift. All 8/6/2016 looks normal. Well freeze protected with 38bbl of 50/50. DSO notified of status of well. T/I/O=0/0/15, Assist Slickline (Pre CTD) Pumped 4 bbls 60/40 meth followed by 33 bbls 8/7/2016 1% KCL with Safelube down TBG while Slickline brushes, • 02-14A Well History (Pre-Rig Sidetrack) ***WELL S/I ON ARRIVAL***(ctd). DRIFTED TBG W/3.70" x 20' DUMMY WHIPSTOCK TO 9287' SLM (stopped due to tight spot in tbg). RAN 4-1/2" BRUSH & 3.74" GAUGE RING TO 9950' SLM (recovered metal shavings and 10" piece of bailing wire). DRIFTED TBG W/3.70" BAKER DUMMY WHIPSTOCK TO 9546' SLM (able to pass 9287'with —170 fpm run). RAN 4-1/2" BRUSH & 3.805" GAUGE RING TO 9946' SLM (drift cleanly to cibp). 8/7/2016 LRS BEGAN PUMPING AT 3 BPM WHILE IN HOLE W/3.80" G.RING. ***Job continued from 8-7-16***, Assist Slickline (Pre CTD), Pumped an additional 127 bbls 1% KCL with safelube down TBG (160 bbls total)while Slickline brushes, Pumped another 40 bbls KCL w/safelube down TBG to assist slickline, See log for details, Pumped 38 bbls diesel down TBG for freeze protect, Tag hung on MV, FWHP=0/50/20, 8/8/2016 IA/OA=open, Slickline in control of well at departure ***CONT. FROM 8/7/2016***(ctd). RAN 4-1/2" BRUSH & 3.74" GAUGE RING TO 9550' SLM WHILE LRS PUMPED 3 BPM 9550' SLM (no issues). RAN 3.70" x 23.3' BKR DRIFT ASSY. TO 9478' SLM (Had to use LRS at 2 bpm to pass —9300' area). RAN 3.625"x 13.3' BKR DRIFT ASSY TO 9287' SLM WORK DRIFT DOWN TO 9413' SLM (not falling on its 8/8/2016 own). T/I/O=Vac/0/0 Set 6" Gray"K" BPV#612 Installed Nordic TS#06 Ensured SSV operates 8/9/2016 with 0 psi. PT'd between SSV& Swab valve. FWP's BPV/0/0 see log for details. T/I/O = BPV/vac/20. Temp = SI. WHPs (pre CTD). No wellhouse, no flowline or AL. Drilling scaffolding installed. 8/13/2016 SV,WV, SSV= C. MV= O. IA, OA= OTG. 16:00 T/I/O = BPVNAC/10. Temp = SI. WHP's (pre CTD). No wellhouse, flowline or AL. Drilling scaffolding installed. OAP decreased 10 psi since 8/13/16. 8/18/2016 SV, WV, SSV, MV= C. IA, OA= OTG. 15:30. T/1/O = BPVNac/10. Temp = SI. Eval jewelry (pre CTD). No flowline, no AL no wellhouse. Adjusted Jewelry on IA and OA as requested. 8/19/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:50 i 41111 North America-ALASKA-BP Page 1 obILL Operation Summary Report r Common Well Name:02-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.8/18/2016 I End Date:8/30/2016 X3-017W4-C:(2,568,858.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:5/21/1980 12:00:00AM ;Rig Release:9/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292044600 Active datum:2-14A:©57.93usft(above Mean Sea Level) Date ' From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/18/2016 06:00 - 08:20 2.33 MOB P PRE PJSM TO MOVE OFF WELL DISCUSS PROCEDURE FOR PULLING OFF. PERFORMED LO/TO OF ADJACENT WELLS i NK-17&18 TO PULL OFF. 12 X 12 CHOCK BLOCK IN PLACE. ESD TESTED AND MANNED BY NORDIC SUPERINTENDENT. ASSIGNED SPOTTER AND VERIFIED RADIO COMMUNICATION VERIFIED ALL VALVES CLOSED. PULLED OFF WELL WITH NO ISSUE. 08:20 - 09:00 0.67 MOB P PRE PU RIG MATS NOTIFY ACS TO INSPECT MUD ON GROUND FROM PUMP FAILURE,CONED OFF AREA. 09:00 - 10:30 1.50 MOB P PRE MOVE RIG FROM NIAKUK ISLAND TOWARDS L5. 10:30 - 11:00 0.50 MOB P PRE STOP AT ENTRANCE OF L5 AND HOLD CONFERENCE CALL WITH TOWN TEAM AND 272 BEFORE MOVING DOWN THE ACCESS ROAD AND BLOCKING ACCESS TO THE RIG. 11:00 - 11:30 0.50 MOB P PRE OK TO MOVE MOVED TO STAGING AREA,ALLOW LOADERS TO MOVE RIG MATS DOWN THE ACCESS ROAD 11:30 - 18:00 6.50 MOB P PRE WAIT AT L5 STAGING AREA FOR RIG MATS TO BE LAID IN FRONT OF RIG. 18:00 - 00:00 6.00 MOB P PRE CONTINUE WAITING AT L5 FOR RIG MATS TO BE LAID. 8/19/2016 00:00 - 06:10 6.17 MOB P PRE CONTINUE WAITING AT L5 STAGING AREA FOR MATS TO BE LAID IN FRONT OF RIG. '06:10 - 07:00 0.83 MOB P PRE CALL 272 WSLANND DISCUSS THEIR OPERATIONS CURRENTLY DRILLING AHEAD WITH 20-30 BPH LOSS RATE AND THEY HAVE ENOUGH FLUID TO MANAGE THEIR OPERATION WHILE WE ARE ON THE ACCESS ROAD TO EAST DOCK ROAD WHERE WE WILL STOP AND STAGE THE RIG OUT OF THE WAY TO MOVE THE RIG MATS DOWN THE EAST DOCK ROAD. CALLED WOS AND DISCUSSED OUR STATUS AND 272'S j WE WILL MAKE ANOTHER CALL TO BOTH ONCE WE ARE READY TO START MOVING JUST TO MAKE SURE 272'S STATUS HAS NOT CHANGED 07:00 - 08:45 1.75 MOB P PRE RIG MATS ARE READY TO MOVE CALL 272-THEY ARE GETTING READY TO 'TOH AND ARE OK FOR US TO MOVE CALL WOS-DISCUSS 272'S CURRENT 1 STATUS AND WE ARE OK TO MOVE 08:45 - 09:15 ' 0.50 MOB P PRE RIG IS CLEAR OF THE L-5 ACCESS ROAD AND BACKING INTO A STAGING AREA TO ALLOW RIG MATS TO BE MOVED OUT IN FRONT OF THEM Printed 9/6/2016 1.08:48PM •AII depths reported in Drillers Depths* • I North America-ALASKA-BP Page 2 VO Operation Summary Report Common Well Name:02-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2016 End Date:8/30/2016 X3-017W4-C:(2,568,858.00) Project:Prudhoe Bay 4 Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:5/21/1980 12:00:00AM Rig Release:9/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292044600 Active datum:2-14A:@257.93usft(above Mean Sea Level) Date From-To I Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:15 - 00:00 14.75 I MOB r P PRE RIG IS STOPPED ATA STAGING AREA CLEAR OF L5'S ACCESS ROAD. CONTINUE RIG HOUSEKEEPING PROJECTS WHILE MATS ARE LAID ON EAST DOCK ROAD IN FRONT OF RIG. 8/20/2016 00:00 - 06:00 6.00 MOB P PRE CONTINUE WAITING AT EAST DOCK ROAD STAGING AREA FOR RIG MATS TO BE LAID IN FRONT OF RIG. PERFORM RIG HOUSEKEEPING AND MAINTENANCE TASKS WHILE WAITING. 06:00 - 14:20 8.33 MOB P PRE CALL 272&WOS TO DISCUSS MOVING TO DS 4 STAGING AREA 272 IS GOOD FOR US TO MOVE 14:20 - 16:00 1.67 MOB P PRE MOVE RIG TO DS 4 16:00 - 18:00 2.00 MOB P PRE RIG STOPPED AT DS 4 WITH ROOM FOR TRAFFIC TO GET AROUND TO 272 WO RIG MATS TO BE PLACED IN FRONT OF THE RIG TO MOVE TO PBOC 18:00 - 00:00 6.00 MOB P PRE CONTINUE WAIT ON RIG MATS TO BE PLACED FROM DS-04 TO PBOC. 8/21/2016 00:00 - 06:00 6.00 MOB P PRE CONTINUE WAIT ON RIG MATS TO BE PLACED FROM DS-04 TO PBOC. 06:00 - 14:30 8.50 MOB P PRE WO RIG MATS TO BE MOVED DOWN EAST DOCK ROAD IN FRONT OF THE RIG TO PBOC 14:30 - 14:45 0.25 MOB P PRE CALLED 272 WSLAND DISCUSSED THEIR OPS,THEY ARE INA GOOD POSITION FOR US TO MOVE CALL WOS AND DISCUSS MOVING NORDIC 2 AND 272'S OPS WE HAVE APPROVAL TO MOVE,ONCE THE MATS ARE IN PLACE PJSM TO MOVE THE RIG 14:45 - 15:00 0.25 MOB P PRE JACK RIG UP 15:00 - 18:00 3.00 MOB P PRE MATS ARE IN PLACE,MOVE RIG TO DS 2 18:00 - 19:00 1.00 MOB P PRE WAIT AT GC1 FOR SHIFT CHANGE AND TO LET TRAFFIC PASS. 19:00 - 20:00 1.00 MOB P PRE CONTINUE MOVING TOWARDS DS-02 ON WEST DOCK ROAD. 20:00 - 21:00 1.00 MOB P PRE RIG ARRIVES DS-02. SPOT RIG NEAR WELL AND CONDUCT PJSM FOR PULLING OVER THE WELL. DISCUSS USE OF ESD AND CHOCK BLOCK DISCUSS CLEAR COMMUNICATIONS AND USE OF THE STOP COMMAND. TEST ESD TO VERIFY FUNCTIONALITY. PULL RIG OVER WELLAND SET DOWN, WITNESSED BY WSL,NORDIC SI AND TOURPUSHER.ACCEPT RIG AT 21:00. 21:00 - 23:00 2.00 MOB P PRE PJSM THEN LIFT REEL ONTO THE RIG.IN THE CELLAR,VALVE SHOP CREW OPEN SSVAND INSTALL FUSIBLE CAP,WITNESSED BY WSL. OPEN SSV,CYCLE SWAB AND MASTER TO ALLEVIATE TRAPPED PRESSURE. RIG UP FOR LEAK TIGHT TEST,INSTALL PRESSURE TRANSDUCER ON WING.GOOD LEAK TIGHT TEST. 23:00 - 00:00 1.00 MOB P PRE PJSM THEN REMOVE TREE CAP,INSTALL BOPS. Printed 9/6/2016 1:08:48PM *All depths reported in Drillers Depths* • I North America-ALASKA-BP Page 3 te2'a Operation Summary Report Common Well Name:02-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2016 End Date:8/30/2016 X3-017W4-C:(2,568,858.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:5/21/1980 12:00:00AM Rig Release:9/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292044600 Active datum:2-14A:@57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 8/22/2016 00:00 - 02:30 2.50 MOB P PRE CONTINUE INSTALLING BOPS. INSTALL RISER SECTIONS. IN THE REELHOUSE,SLB HOOK UP 1502 LINE AND GRAPPLE,PREP TO PULL CT ACROSS. 02:30 - 04:30 2.00 MOB P PRE 'PJSM THEN PULL CT ACROSS FROM REELHOUSE INTO INJECTOR. REMOVE GRAPPLE FROM CT. 04:30 - 07:10 2.67 MOB P PRE INSTALL BOOT ON END OF CT TO PUMP CABLE BACK,THERE IS NOT ENOUGH CABLE AT THE REEL TO MAKE UP THE BULKHEAD. GET RKB MEASUREMENTS OF THE STACK ......... . 07:10 - 09:00 1.83 MOB P PRE LINE UP TO REVERSE CIRCULATE THE ELINE TO MU THE PRESSURE BULKHEAD 09:00 - 10:10 1.17 MOB N HMAN PRE CTS LUBRICATOR NEEDS TO BE RECONFIGURED.THE PORT TO TEST THE QUICK TEST SUB IS TOO CLOSE TO THE ROTARY BUSHING COVER AND THE HOSE CAN NOT BE ATTACHED. THIS IS SOMETHING THAT SHOULD BE VERIFIED EACH TIME THE LUBRICATOR IS MADE TO VERIFY THE TEST HOSE CAN BE MADE UP BEFORE STARTING OPERATIONS. 10:10 - 16:35 6.42 MOB P PRE START TESTING BOPEAS PER BP,NORDIC AND AOGCC REGS. FROM TOP DOWN TEST ANNULAR WITH 2-3/8"AND 3-1/2"TEST JOINT,BLIND RAMS, UPPER 2-3/8"COMBIS,VBRS WITH 2-3/8"AND 3-1/2"TEST JOINT,AND LOWER 2-3/8" COMBIS. TEST CHOKE VALVES AND FLOOR VALVES. TEST PRESSURE IS 250/3500 PSI. 16:35 - 17:45 1.17 MOB P PRE BOPE TESTED HOLD RIG EVAC DRILL 17:45 - 18:00 0.25 BOPSUR P PRE TEST IRV AND PACK OFF 18:00 - 18:30 0.50 MOB P PRE CALIBRATE OUT MM BY PUMPING FRESH WATER THROUGH CT. NOT GETTING CORRECT READING ON CTDS SCREEN,TROUBLESHOOTAND FIX THE I ISSUE. 18:30 - 19:30 1.00 MOB P PRE PJSM FOR CUTTING CT WITH HYDRAULIC CUTTER. RIG UP HYDRAULIC CUTTER,CUT 262 OF CT. DID NOT SEE WIRE. 19:30 - 20:30 1.00 MOB P PRE INSTALL CT CONNECTOR,PULL TEST TO 35K IS GOOD. PRESSURE TEST TO 250/4700 PSI,GOOD. GET ON WELL,PUMP SLACK FORWARD. TEST WIRE,GOOD. 20:30 - 21:30 1.00 MOB P PRE INSTALL BHI UQC,WITHOUT FLOATS. 21:30 - 22:00 0.50 MOB P PRE PJSM FOR 6K PT. REVIEW PRESSURE CROSSCHECK AND VALVE ALIGNMENT. VERIFY ALL COMPONENTS RATED>6 KSI. BYPASS IN MM,TEST ALL REEL HARDLINE I AGAINST MM ISOLATION VALVE. USE RIG PUMP FOR LOW PT,GOOD. GO TO 4,700 PSI WITH RIG PUMP THEN DOUBLE ISOLATE IT. Printed 9/6/2016 1:08:48PM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 4 etatt Operation Summary Report Common Well Name:02-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2016 End Date:8/30/2016 X3-017W4-C:(2,568,858.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:5/21/1980 12:00:00AM Rig Release:9/1/2016 Rig Contractor NORDIC CALISTA UWI:500292044600 Active datum:2-14A:@57.93usft(above Mean Sea Level) Date From-To Hrs i Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 MOB P PRE BRING PRESSURE UP TO 6,050 PSI WITH HIGH PRESSURE PUMP. GOOD PT OF BULKHEAD AND REEL IRON TO 6,050 PSI. 8/23/2016 00:00 - 00:30 0.50 MOB P PRE RIG EVAC DRILL WITH BEZOLD CREW. I ALL PERSONS MUSTER AND ACCOUNTED FOR IN 2 MIN. 00:30 - 01:30 1.00 MOB P PRE INSTALL BHI CHECK VALVES. PRESSURE TEST IS GOOD. 01:30 - 04:30 3.00 MOB P PRE VALVE CREW CHECKS TORQUE OF TREE BOLTS. GET VERY SLIGHT MOVEMENT ON A FEW OF THEM. LOAD BPV LUBRICATOR ONTO RIG,M/U TO RISER. PRESSURE TEST BPV LUBRICATOR. HOLD 2000 PSI PRESSURE,PULL BPV 04:30 - 04:45 0.25 MOB P PRE I BPV PULLED,WHP=1990 PSI 'LOAD OUT LUBRICATOR&PULLING TOOLS 04:45 - 04:55 0.17 BOPSUR P PRE 1 INSTALL NIGHT CAP AND PT TO PREP FOR BULLHEAD KILL 04:55 - 05:10 0.25 BOPSUR P PRE HOLD A PJSM TO BHK WELL DISCUSS FOLLOWING THE PRESSURE CROSS CHECK LIST,VOLUMES TO PUMP, MONITORING CELLAR AND IA&OA PRESSURES 05:10 - 06:15 1.08 BOPSUR P I PRE LINE UP BOTH PUMPS TO KILL LINE OPEN SWAB AND PRESSURE UP TO 2000 PSI PUMP 10 BBLS OF NEAT METH 90 BBLS OF 1%KCL 30 BBLS OF HIGH VIS 145 BBLS KCL STARTING PRESSURES WHP=2020 PSI IAP=0 PSI OAP=0 PSI 5.5 BPM 94 BBLS AWAY PRESURE LEVELED OFF AT 2411 PSI AND IS STARTING TO DROP FLUID AT THE PERFS AND WHP IS CLIMBING FROM 960 PSI PRESSURE LEVELED OFF AT 1813 PSI WHP SLOWLY INCREASING AS HIGH VIS IS GETTING TO THE PERFS 06:15 - 06:35 0.33 BOPSUR P PRE 270 BBLS AWAY WHP AT 1853 PSI SHUT DOWN THE PUMPS AND BLEED OFF WHP IAP=1422 PSI OAP=22 PSI BLEED OFF LUBRICATOR AND LINE UP TO PUMP ACROSS THE TOP TO 06:35 - 07:20 0.75 BOPSUR P PRE CIRCULATING ACROSS THE TOP TO MONITOR FOR LOSS RATE LOST 1 BBL IN 4 MIN LOAD WS ON RIG,HS WS WHILE MONITORING WELL LOSS RATE LOST 1 BBL IN 8 MIN LOST 1 BBL IN 10 MIN LOSS RATE AS STABILIZED AT-6 BPH Printed 9/6/2016 1:08:48PM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 5 Operation Summary Report Common Well Name:02-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2016 End Date:8/30/2016 X3-017W4-C:(2,568,858.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:5/21/1980 12:00:00AM Rig Release:9/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292044600 Active datum:2-14A:©57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:20 - 07:35 0.25 STWHIP P WEXIT HOLD PJSM TO MU THEWS BHA 07:35 - 08:20 0.75 STWHIP P WEXIT MU THE WS BHA 08:20 - 10:35 2.25 STWHIP P WEXIT BHA MU RIH 10:35 - 11:30 0.92 STWHIP P WEXIT LOG TIE IN FROM 9270 FT. CORRECT-23 FT. LOG CCL DOWN ACROSS SETTING DEPTH. PARK AT 9590 FT AND ANALYZE CCL LOG. 11:30 - 12:00 0.50 STWHIP P WEXIT WHILE LOOKING AT LOG,NOTICE INCREASE IN OUT RATE FOLLOWED BY REDUCTION IN OUT MM DENSITY. SHUT DOWN PUMP,MONITOR OUT MM FOR FLOW CHECK, CURRENTLY FLOWING OUT TO TIGER TANK SO CAN'T DO A VISUAL FLOW CHECK. OUT MM SHOWS FLOW,SHUT IN AT CHOKE HCR. LINE UP WELL TO A CLOSED HAND CHOKE AND READ PRESSURES,ABOUT 10 PSI. ANNULAR PRESSURE AT 3802 PSI,ABOUT 500 PSI OVERBALANCE. MAKE NOTIFICATION AS PER TIER 3 FLOWCHART,NOTIFY WOS GREG SARBER -AND CTD SI KEN SCHNEIDER,RECEIVE PERMISSION TO CIRCULATE WELL CLEAN AND CONTINUE OPERATIONS. NOTIFY DSO. 12:00 - 12:30 0.50 STWHIP- P WEXIT VAC OUT TIGER TANK,LEAVE WELL SHUT IN. 12:30 - 13:00 0.50 STWHIP P WEXIT START CIRCULATING OUT TO TIGER TANK, HOLD 100 PSI WHP WITH CHOKE. PICK UP TO WHIPSTOCK SET DEPTH. CLOSE EDC. SET WHIPSTOCK AT BIT DEPTH OF 9485.9 FT, LEAVES TOP WHIPSTOCK TOP AT 9,470 FT AT 25L TF. SET 4.7K DOWN ON DWOB TO CONFIRM SET. 13:00 - 14:30 1.50 STWHIP P WEXIT PICK UP 20 FT ABOVE WHIPSTOCK,SWAP WELL TO MUD. GETTING PERIODIC GAS CUT FLUID BACK. AFTER 1 B/U RETURNS CLEAN,NO SIGN OF GAS. GETTING 9.5 MUD BACK,SEND RETURNS TO PITS. Printed 9/6/2016 1:08:48PM *AII depths reported in Drillers Depths* • . North America-ALASKA-BP Page scams Operation Summary Report Common Well Name:02-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2016 End Date:8/30/2016 X3-017W4-C:(2,568,858.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:5/21/1980 12:00:00AM Rig Release:9/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292044600 Active datum:2-14A:©57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ' Phase I Description of Operations (hr) , (usft) 14:30 - 16:00 1.50 STWHIP P WEXIT SHUT DOWN PUMP FOR FLOW CHECK. WHEN PUMP IS SHUT DOWN,LEL ALARM AT SHAKER GOES OFF. 1 SLB SHUTS IN CHOKE HCR AND UPPER COMBI RAMS. CREW MUSTERS TO DESIGNATED SAFE AREAS,ALL PERSONNELACCOUNTED FOR. MAKE NOTIFICATIONS AS PER TIER 3 EVENT. LIKELY SOURCE OF GAS WAS FROM RISER ABOVE THE FLOW CROSS THAT HAD COLLECTED THERE WHEN GAS WAS CIRCULATED OUT EARLIER. NOTIFY WOS AND CTD SI,RECEIVE PERMISSION TO RE-ENTER RIG. PJSM WITH CREWS FOR OPENING WELL AND BLEEDING OFF RISER GAS BUBBLE. I EQUALIZE AND OPEN NCR AND PIPE SLIP I RAMS,ABOUT 20 PSI BLEED OFF TO TIGER TANK. 10 MIN PUMPS OFF FLOW CHECK IS GOOD. NORDIC ELECTRICIAN RE-CALIBRATES SHAKER SENSOR THE RECORDED THE LEL. 16:00 - 17:45 1.75 STWHIP P I WEXIT POR WITH BHA WITH NO ISSUES. RETURNS WERE 1 FOR 1,MUD DENSITY IN 9.45 PPG, MUD DENSITY OUT 9.39 PPG. -CONDUCT AAR OF FLUIDS HANDLING OPERATION,PROVIDE FEEDBACK TO SUPERINTENDENT -PULL BHA TO SURFACE,FLOW CHECK ALL GOOD. PULL BHA INTO STACK. -POP OFF AND STAND INJECTOR TO SIDE 17:45 - 18:15 0.50 STWHIP P WEXIT LAY DOWN BHA,PREPARE NEXT BHA FOR OPERATION -CHANGE OUT PACKOFFS ON INJECTOR 18:15 - 19:00 0.75 WHSUR N SEAL WEXIT CONTINUE TO PREPARE BHA FOR MILLING OPERATION -RIG UP TO CONDUCT PRESSURE TEST OF UPPER COMBI RAMS WITH 2-3/8"TEST JOINT TO 250 PSI LOW/3500 PSI HIGH. -GREASE CREW OUT TO SERVICE TREE VALVES 19:00 - 21:40 2.67 WHSUR N SFAL WEXIT TEST 2-3/8"UPPER COMBIS,HCR AND CT STRIPPER. 21:40 - 22:20 0.67 WHSUR N SFAL WEXIT 'REMOVE TEST PLUG. INSTALL NIGHT CAP AND TEST TO PREP TO OPEN THE WELL UP. OPEN WELL,FILL WITH 0.5 BBLS. 22:20 - 23:00 0.67 WHSUR P WEXIT PJSM FOR PICKING UP BHA#2,WINDOW MILLING BHA. GREASE CREW SERVICES TREE VALVES WHILE HAVING PJSM. MAKE UP BHA#2,WINDOW MILLING BHA. MILL AND REAMER ARE 3.80"GO,3.79" NO-GO. INJECTOR ON AT 22:55. 123:00 - 00:00 1.00 WHSUR P WEXIT ZERO COUNTERS,TEST QTS AND COILTRAK OPEN ECD. RIH. 8/24/2016 00:00 - 01:00 1.00 STWHIP P WEXIT CONTINUE RIH LOG TIE-IN FROM 9340 FT. CORRECT-25 FT. Printed 9/6/2016 1:08:48PM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 7 pied Operation Summary Report Common Well Name:02-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2016 End Date:8/30/2016 X3-017W4-C:(2,568,858.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:5/21/1980 12:00:OOAM Rig Release:9/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292044600 Active datum:2-14A:@57.93usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (111:) Ali- i (usft) sibyl01:00 - 03:20 2.33 STWHIP P WEXIT CLOSE EDC,RIH FOR DRY TAG. !�r(/� DRY TAG AT 9473 FT. 01 Jp 'PICK UP AND START MILLING FROM 9471.3 FT. 2.72/2.72 BPM IN/OUT,FREE SPIN=2,900 PSI. 9.51/9.51 PPG,ECD=10.52 PPG. PVT=384 BBLS,IA/OA=770/22 PSI. 03:20 - 04:00 0.67 STWHIP P WEXIT CONTINUE MILLING WINDOWAT 9473 FT. 2.71/2.72 BPM 9.52/9.52 PPG. ECD=10.58 PPG,PVT=385 BBLS. 04:00 - 06:00 2.00 STWHIP P WEXIT ATA DEPTH OF 9473.7 FT,RETURNS FALL OFF BRIEFLY THEN START COMING BACK AGAIN. AT 9474.1 FT MILLING AT 2.70/2.56 BPM 06:00 - 12:15 6.25 STWHIP P WEXIT MILLING WINDOWAT 9475.2 FT. 2.70/2.64 BPM AT 2820 PSI. l 9.50/9.48 PPG IN/OUT. ECD=10.49 PPG,PVT=358 BBLS. -WELL TOOK FLUID DURING THIS SECTION, STABILIZED FAIRLY QUICKLY. -36 BBLS I LOST. LOSSES SLOWED TO-1 TO 2 BPH ' DURING NORMAL MILLING OPS .THEREAFTER. I -MILLING WENT VERY SMOOTH,PUMP DOWN LO-VIS/HI-VIS SWEEP WITH STRING I REAMER ON RAMP TO HELP WITH SLIDE, CLEANING UP DEBRIS. CONSITENT METAL 'RETURNS ACROSS SHAKER. -MW IN STEADY AT 9.5 PPG AND MW OUT 9.47 PPG. CONTINUED TO LOSE-1 BPH THROUGHOUT REMAINDER OF MILLING. -MILL RATHOLE FROM 9479'TO 9490' 12:15 - 14:00 1.75 STWHIP P WEXIT CONDUCT REAMING PASSES PER WELL PROGRAM AND BOT REP. -CIRCULATE DOWN LO-VIS/HI-VIS COMBO TO CLEAN UP METAL SHAVINGS -PASSES LOOKED GOOD,NO ISSUES ' -SAMPLE FROM BOTTOM GOOD OBSERVATION OF FORMATION -CONDUCT DRY DRIFT,ALL GOOD 14:00 - 16:15 2.25 1 STWHIP P WEXIT STOP IN WINDOW TO OPEN EDC. FLOW CHECK,NO FLOW. ' -POH WITH MILLING BHA. CONDUCT PJSM FOR LAYING DOWN BHA. -FLOW CHECK WITH BHA AT 200'. PULL BHA !INTO BOP STACK. -POP OFF WITH BHA 16:15 - 17:15 1.00 STWHIP P WEXIT LAY DOWN BHA. MILLS GAUGE AT 3.80"GO, 3.79"NO-GO. -MU BHA#3,3.75"BY 4.25"HYCALOG BIT ON TO 1.16°BEND MOTOR AND BHI SMART TOOLS I___ j___ l -STAB ON WITH INJECTOR Printed 9/6/2016 1:08:48PM *All depths reported in Drillers Depths* 111.L= 5"X 7"L FMC 120 02-1 4A DLA:34.6"@ 9466'. CHROME TBGo 9899'.MAX WELLHEAD GRAY ACTUATOR 6AK162 C OKB.EIEV: — 64' LI REF EiEI/= 57.93' 2 - 2220' H4-1/2"HES X NP,ID=3-813" BF.BEV= 31.61' 20"CONDUCTOR, - 113' KOP= _ 9248' 91.5#,H 40, Max Angle= 97"@ 11063' 2813' 195i8XTLTPwBAC< SL V&HGR, Datum MD= X22 D=19.124" /1 D=6.315" Datum ND= 8800'SS GAS LIFT MAPDRELS 0 /� ST MD N D DEV TYPE V LV LATCH PORT DATE 13-3/8"CSG,72#,N-80 BUTT,D=12-347" H 271T 11 1 IA 6 3813 3807 16 KBG-2 DMY BK 0 08/02/16 �� 1j 5 6043 5561 42 KBG-2 DMY BK 0 07/28/16 Minimum ID =3.80" @ 8865' �� 1j 4 6780 6159 25 KBG-2 DMY BK 0 07/28/16 4-1/2" HES XN NIPPLE MILLED w, 11 3 7352 6697 18 KBG-2 DMY BK 0 07/28/16 ' 11� 2 7924 7244 15 KBG-2 DMY BK 0 07/28/16 '/ 111 1 1 1 8498 7806 8 KBG-2 DMY BK 0 07/28/16 '/ 1 '1 1�/ 8615' -I4-112"HES X NP,ID=3.813" IlA 1 1, ,1� 8643' --17"X 4-1/7'HES TNT PKR,D=3.856" 4-1/2"TBG,12-6#,13CR-85 VAM TOP, H 8747' �'�x •1�� 8677' -14-1/2"FES X NP,ID=3.813" .0152 bpf,ID=3-958" I !Ii.4-1/2"TBG CUT(07/28/16) -1 8754' I88762' J-17"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TBG PUNCH(05/22/16) 8758'-8760' 1 • ., 8800' H4-1/2"FES X NP,ID=3.813" 0, 1� ,.t�� r:'V. 8821' --17"X 4-1/2"BKR S-3 PKR,D=3.875" 1 �; E 8844' -14-1/2"FES X NP,ID=3.813" • V, j 8866' H4.112"HES XN NP MILLED TO 3-80"(08/06116) •1� i 11A 4-1/2"TBG,12.6#,L-80,-0152 bpf,D=3.958" - 8877' 1.1 8877' --I4-112"WLEG,ID=3.958" 11 VI •• 14 H ELM)TT NOT LOGGED 11 4 i'41 9072' -ILNR TIEBACK SLV,D=4.37" $ 9083'9083' -1 7"X 5"BKR ZXP LTP,D=4.370" 1' ,1 4, ;1, 9094' --17"X 5"HMC HGR,ID=4.410" '1 111 9100' -15^X 4-1/2"XO,D=3.90" 1I 1 7"WHPSTOCK(08/29/03) -{ -9248' ,11 q7"SCAB LNR,26#,L-80,ID=6-276" H -9248' ,., , MLLOUT WINDOW (02-14A)9248'-9260' 9-5/8"CSG,47#,L-80 BTC/SOO-95,ID=8.681" - -9248' '1 %`, 10 f� , 10000'CTM -FISH:4-112"GBP MILLED& 1� ` ��� PUSHED DH(08/06/16) PERFORATION SUMMARY ,1'..:.. 1i/111111'11 ` REF LOG: �.X11111111111111 , 11200' J-4-1/2"CIBP(01/06/06) •ANGLE AT TOP PEW:57°@ 9680' 11�1111111111111� \/ Note:Refer to Production DB for historical perf data SIZE SPF MT RVAL Opn/Sqz SHOT SQZ 4-1/2"WHPSOCK H 9471' //�� ' 2-7/8" 6 9680-9700 0 04/02/10 (08/23/16) � 2-1/2" 6 9910-9930 0 05/10/06 2-7/8" 6 9930-9958 0 03/14/06 PBTD -I 11792' 2-1/2" 4 10010-10210 0 09/07/03 2-1/7' 4 10430-11110 0 09/07/03 2-1/2" 4 11260-11780 C 09/07/03 4-1/2"LNR,12.6#,L-80, -{ 1187W -0152 bpf,D=3-958" DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 06/17/80 ?? ORIGINAL COMPLETION 08/09/16 JPK/JM)GLV C/O(08/02/16) WELL: 02-14A 08/13/88 PKR 176 RWO 08/09/16 JMJM? MLLED XN M/SET FISH(08/06/16) PERMfT No:'2031250 09/08/03 N2E5 SIDETRACK(02-14A) APINo: 50-029-20446-01 07/29/16 P-272 RWO SEC 36,T11 N,R14E,567'FNL&851'FWL 08/02/16 JM) DRLG HO CORRECTIONS 08/03/16 TWJND MAL ODE APPROVAL BP Exploration(Alaska) • • yoFzo , A THE STATE Alaska Oil and Gas of LAsKA Conservation Commission _ 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ^?' Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Sean McLaughlin Drilling Supervisor BP Exploration (Alaska), Inc. P.O. Box 196612 SCANNED SEP 2 g 20 16 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-14A Permit to Drill Number: 203-125 Sundry Number: 316-261 Dear Mr. McLaughlin: 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 DATED this 2-Y'day of May, 2016. RBDMS t)- MAY 3 1 2U16 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI41, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill Q ' Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 203-125 ` 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Q 6. API Number: 50-029-20446-01-00 99519-6612 Stratigraphic 0 Service ❑ 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 0 No RI PBU 02-14A , 474 V ED 9. Property Designation(Lease Number): 10. Field/Pools: lvl ADL 028308 • PRUDHOE BAY,PRUDHOE OIL ' MAY 0 9 2016 11. PRESENT WELL CONDITION SUMMARY Dasz-f/(0 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(M AGOG CC 11880 - 8995 - 9121 8427 2410 9121',11200' None Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20" 27-108 27-108 1530 520 Surface 2684 13-3/8" 26-2711 26-2710 4930 2670 Intermediate 9924 9-5/8" 24-9248 24-8554 6870/8150 4760/5080 Scab Liner 6429 7" 2813-9248 2813-8554 7240 5410 Liner 2807 4-1/2" 9072-11879 8378-8995 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9680-11780 8891 -8994 4-1/2"12.6# L-80 22-8875 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8819/8125 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic IZI 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch RI Exploratory ❑ Stratigraphic ❑ Development RI ' Service 0 14.Estimated Date for Commencing Operations: July 15,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended RI 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Hyatt,Trevor be deviated from without prior written approval. Email Trevor.Hyatt@bp.com Printed Name Sean McLaughlin Title Drilling Supervisor Signature Phone +1 907 564 4387 Date j/6/ 16 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry 3\TNumber:n �2Lp Plug Integrity El BOP Test Mechanical Integrity Test 0 Location Clearance 0 ` \ Other: 5oP fie5 f to 3S70p5 740,� ✓lG pr '✓t -4—tr�-IfC3i te, Z50o p5 Alfer�u¢c p, p a«erv7apprvve'c�9 Post Initial Injection MIT Req'd? Yes 0 No IN"-- / ll/ ��}/�CZ� p120,)2 t Spacing Exception Required? Yes 0 No ©' Subsequent Form Required: 1 U — 40-7_ // ` �/ APPROVED BYTHE Approved by: Y -- /,p COMMISSIONER COMMISSION Date:J– // V?L /2 L/i ORIGINAL RBDMS 1-' MAY 312016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. �' / Attachments in Duplicate • • To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt , bp CTD Engineer Date: May 4, 2016 Re: 02-14A Sundry Approval Sundry approval is requested to plug the 02-14A liner perforations as part of the drilling and completion of the proposed 02-14A CTD sidetrack. History and current status: 02-14 was initially drilled as a barefoot completion 1980. The 9-5/8' production casing was set into the Ivishak. A RWO in 1988 installed and cemented a 7" production liner across the barefoot interval. In 2003 the parent well, 02-14A, was rig sidetracked to its current location. The rig initially ran a 7" scab liner from the top of the old cut tubing sub at 9290 all the way up to 2827' MD to repair a logged PC leak at 3280' in the 9-5/8" casing. The 7" liner was fully cemented. The crews saw—20 bbls contaminated cement returns, presumably from the top of the 7", and all cementing parameters seemed normal. The top of the 7" also had an LTP installed. The notes form the 2003 sidetrack reflected that they wanted to perf the Put River and install a straddle assembly, but their economics at the time did not allow the extra expense, so they left a gap between their top of 4-1/2" liner, and their tubing tail. In Feb-2011 the well failed a warm TIFL. After DGLV's were set, a subsequent MIT-IA failed losing 1240 psi in the first 15 minutes. An LDL showed a leak to be at 6163' MD (not a GLM). The well was made non operable for TxIA communication. The well was patched and lasted 4 more months before a subsequent tubing leak happened. Given the poor caliper results, no further non- rig operations were pursued. The well has been SI non-operable since. Proposed plan: After a planned RWO, to perform a tubing swap, service coil will mill CIBP and push to bottom, followed by e-line setting packer whiptstock at—9,450' MD. Nordic 2 Coiled Tubing Drilling rig will then drill a through tubing sidetrack on or around Aug 20, 2016. Nordic 2 will exit into Zone 2 Ivishak formation above the existing 02-14A perforations. The side track will target Zone 1A/1 B reserves. The proposed sidetrack is a —2,685' MD horizontal Ivishak Zone 1A/1 B producer. The lateral will be completed with a 3-1/2"x 3-1/4" x 2-7/8" L-80 liner which will be cemented and perforated isolating the current Zone 1A/1 B perforations. This Sundry covers plugging the existing 02-14A perforations via the 02-14B packer whipstock and liner cement job 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. co,,cut. i h G c✓Pu e&t— (A-elf piv(9c//C+ or q 670 p� l" A�'1 �, d Sha-ed ( -le �7 Rn� recAoe w�e c��1" 9 lei( 04 ae �D©oma well err1or- h CP a7 eC, 44 4� � Coy 4,ri 01 Of %4e_ !l G Src.,e rf4ck 1 h/_ pro (Ve tX e left War 7J,7, for_ /4e0'y fecol j, ice r--i fort?'OP 01 r'‘e t9(t)I, • • Pre-Rig Work 1. V Pull BPV/TWC 2. S Pull B&R and RHC insert, Dummy off Shear GLV 3. C Mill 4-1/2" CIBP and Push to PBTD, Dummy WS drift 4. E Mill XN nipple to 3.80" ID, Set 4-1/2" packer whipstock* 7-1415 5. V Pre CTD Tree Work 3vvzCir/ 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 2,410 psi. - 2. Mill 3.80"window plus 10' of rathole. Swap the well to 8.5-9.5 ppg PowerPro. 3. PU drilling BHA with GR/Resistivity 4. Drill 4.25" hole to TD at—12,135 MD 5. Run 3-1/2"x 3-1/4"x 2-7/8" L-80 liner leaving TOL at—9,350' MD. 6. Pump primary cement bringing TOC to TOL, 27.5 bbls of 15.8 ppg liner cmt planned* Mc W 7. Cleanout liner and run RPM/GR/CCL log if cement job does not go as planned. 8. Test liner lap to 2,400 psi. I P%U 9. Perforate liner per asset instructions (up to 1,200' MD) 10. Freeze protect well, RDMO Post Rig: 1. V: Tree work as necessary. 2. S: LTP if necessary*and KO GLV's 3. F: Pressure Test LTP if necessary. 4. T: ASRC flowback *Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CTD Engineer 564-4627 CC: Well File Joe Lastufka TREE=. 5"X 7"L FMC 120 • ' aLHEAD GRAY 02-14A SAFETY NOTES:WELL ANGLE>70"@ 9899'. ACTUATOR BAKER C 1 OKB.E.EV: 64' BF.E.EV= 34' KOP= 9248' tufax Angle= 97°@ 11063' 20"CONDUCTOR, — 113' ' I2194` --{4-1/2"HES X NP,ID=3.813" Datum MD= 9627 91.5#,H-40, Datum TVD, 8800'SS D=19.124" L13-3/8"CSG,72#,N-80 BUTT,D=12.347" J-i 271T -_ 2813' H9-5/8"X 7"LTP w/TIEBACK SLY,D=6.315" C2827' -I 9-5/8"X 7"LNR HGR,D=6.315" I, GAS LFT MANDRELS L 1 ST MD ND DEV TYPE VLV LATCH PORT DATE Minimum ID =3.725" @ 8865' �; ;� 3 3287 3286 5 KBG-2 DMY BK 0 03/03/11 4-1/2" HES XN NIPPLE �� �� 2 6338 5782 39 KBG-2 DMY BK 0 03/03111 1' 1 1 8401 7711 10 KBG-2 DMY BK 0 06/09/15 � l 8800' -14-1/2"HES X NP,ID=3.813" 04 8821' H 7"X 4-112"BKR S-3 NKR,D=3.875" i. .• i;8844' --{4-1/2"HES X NP,ID=3.813" 1i .1 • i,. 8865' H4-1/2" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" H 8877' , • 8877' - WA- {4-1/2" EG,ID=3.958" 11 H BIM TT NOT LOGGED r. 9072' --I LNR TIEBACK SLV,D=4.37" B �;� , 9083' _-17"X 5"BKR ZXP LW,D=4.370" 9094' H7"X 5"HMC HGR,D=4.410" 4-1/2"LZ DRLL CP(06/09/15) )—{9121'SLMD (/� .1111 1 9100' --15"X 4-112"XO,D=3.90" 7"WHPSTOCK(08/29/03) —{ -9248' t� 4 MLLOUT WINDOW (02-14A)9248'-9260' 7"SCAB LNR,26#,L-80,D=6.276" H -9248' 9-5/8"CSG,47#,L-80 BTC/SOO-95,ID=8.681" — -9248' 111�1�1�1�1�1�1 :1111111111111 111111111 ` pEFFORATION SUMMARY .1.1.1. 1.1.1.1 REF LOG: 11200' -14-1/2"CIBP(01/06106) ANGLE AT TOP PERF:57°@ 9680' ` I'bte:Refer to Production DB for historical perf data SIZE SFF INTH2VAL Opn/Sqz SHOT SQZ 2-7/8" 6 9680-9700 0 04/02/10 ` 2-1/2" 6 9910-9930 0 05/10/06 2-7/8" 6 9930-9958 0 03/14/06 // ` 2-1/2" 4 10010-10210 0 09/07/03 2-1/2" 4 10430-11110 0 09/07/03 2-1/2" 4 11260-11780 C 09/07/03 �;;=� PBTD 11792' ��;,�• 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" — 11879' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/17/80 ?? ORIGINAL COMPLETION ____01/02/14 DUIJMD TREE C/O(12/22114) WELL: 02-14A 08/13/88 PKR 176 R#JO 05/08/15 GJB/PJC PULL PATCH'NP RDCR(5/6-5/7/15) PERMIT No:'031250 09/08/03 N2ES SIDETRACK(02-14A) 06/29/15 DLH'JMD SET(]BP/GLV C/O(06/09/15) AR No: 50-029-20446-01 11/18/13 RKT/JMD FULL PXN RUG(11/13/13) 06/30/15 AU PRE-RIG CLEAN UP SEC 36,T11N,R14E,567'FM_&851'FW_ 05/12/14 JLS/PJC SET PATCH(05/10/14) 05/05/16 JNIJMD EDITS TO LTP/WS&SCAB LI,F2 DEPTH 05/14/14 PJC MND CORRECTION -1 BP Exploration(Alaska) 120 WELLHEAD 5"X 7"L FMGCRAY • 02-14A I SATETY NOTES:WELL ANGLE>700 @ 9899'. ACTUATOR BAKER Proposed RWO I LI BF.REV= 34' KOP= 9248' Max Angle= 970 @ 11063' 20"CONDUCTOR, — 113' ' 2,200' H4-1/2"FES X NP,D=3.813" Detum WD= 9622' 91.5#,H-40, Datum TVD 8800'SS D=19.124" I]13-3/8"CSG,72#,N-80 BUTT, D=12.347" H 271T 282T H9-5/8"X 7"LNR TOP FKR )1 111 Minimum ID = 3.725" @ 8865' 0 14 I1 'r� 8,603' —4-112"HES X NIP,ID=3.813" 4 �1 4-1/2" HES XN NIPPLE 'Ii ►',11 8634'J—{7"X4-1/2"HES'TNT'FKR,ID=3.875" )j` - 11 It 11 111 I 8,668' H4-112"HES X NIP,ID=3.813" 4-1/2"TBG,12.6#,13Cr-85 VamTop,ID=3.958"H 8,758' ti 111 X11 1' •' 1 .. ... 8,758' I--I''-1/2"OVERSHOT 1' 1 .. ';'; 8800' --I 4-1/2"HES X NIP,ID=3.813" o.; 're 8821' H7"X 4-1/2"BKR S-3 PKR,ID=3.875" �j IA 7' 8844' —14-1/2"HES X NIP,ID=3.813" I'�, 1 )4 I,1 4, ,�' 8865' H4-1/2"HES XN NIP,ID=3.725" IL 1412'TBG,12.6#,L-80,.0152 bpf,ID=3.958" H887T 1/ 8877' H4-1/2"WLEG,ID=3.958" r1 111 11 111 �1 ;�: 9072' —I LNR TIE-BACK SLV,ID=4.37" 7' 1 � • ,, ;�11 9083' --17"X 5"BKR ZXP LTP,D=4.370" '1 , 111 9094' —{7"X 5"HMC HGR,D=4.410" 4-112"EZ DRLL CBP(06/09/15) H 9121'SLMD 'j ,'' 9100' —{5"X 4-112"XO,D=3.90" 9-518"CSG,47#,L-80 BTC,0=8.681" --I 9260 .4 o1 11 MLLOUT WINDOW (02-14A)9248'-9260' 1. 7"SCAB LNR,26#,L-80, D=6.276" H '-9260x•1.1.1.1.1.1.11�.r .j.111111/1111111 141. 11111111111111111111 PERFORATION SUMMARY 1'.11.1.101.1:1 SLOG: 11200' �4-1/2"CIBP(01/06/O6) ANGLE AT TOP FERF:57°@ 9680' Note:Refer to R-oduction DB for historical perf data ` SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2-7/8" 6 9680-9700 0 04/02/10 ` 2-1/2" 6 9910-9930 0 05/10/06 2-7/8" 6 9930-9958 0 03/14/06 2-1/2" 4 10010-10210 0 09/07/03 2-1/2" 4 10430-11110 0 09/07/03 2-1/2" 4 11260-11780 C 09/07/03 �\ FBTD 11792' S ;;�Amikv� 4-1/2"LNR, 12.6#,L-80, .0152 bpf, ID=3.958" H 11879' DATE REV BY COM'dENT5 DATE REV BY COMv1ENTS PRUDHOE BAY UNIT 06/17/80 ?? ORIGINAL COMPLETION 01/02/14 DU/JMD TREE C/O(12/22/14) WELL: 02-14A 08/13/88 PKR 176 RWO 05/08/15 GJB/PJC FULL PATCH/NIP RDCR(5/6-5/7/15) FERMT No: 2031250 09/08/03 N2ES SIDETRACK(02-14A) 06/29/15 DLI-YJM3 SET CBP/GLV C/O(06/09/15) API Nb: 50-029-20446-01 11/18/13 RKT/JMO PULL PXN FLUG(11/13/13) 06/30/15 JMD PRE-RIG CLEAN UP SEC 36,T11N, R14E,567'FNL&851'FWL 05/12/14 JLS/PJC SET PATCH(05/10/14) 05/14/14 PJC MN ID CORRECTION BP Exploration(Alaska) TREE= WELLHEAD5"X 7"L RAC 120 • O 2-14 B [AV NOTES:WELL ANGLE>70°@ 9899'. GRAY ACTUATOR BAKERC Proposed RWO & CTD OKB.ELEV= 64' LI BF.BEV= 34' KOP= 9248' Max Angle= 97°@ 11063' 20"CONDUCTOR, — 113' ' 2,200' —14-1/2"HES X NP,ID=3.813" Datum MD= 9622' 91.5#,H-40, Datum TVD. 8800'SS D=19.124" 13-3/8"CSG,72#,N-80 BUTT,D=12.347" H 2717' 2827' —I 9-5/8"X 7"LNR TOP PKR l 74 I . 1. Minimum ID = 3.725" @ 8865' •/ •, / 8,603' —14-1/2"HES X NIP,D=3.813" 4-1/2" HES XN NIPPLE 7 1• A^, A 1 8634' H7"X 4-1/2"HES'TNT'PKR,ID=3.875" I. Z 8,668' H4-1/2"HES X NIP,ID=3.813" 4-1/2"TBG,12.6#,13Cr-85 VamTop,D=3.958"--1 8,758' v 4 1 • 11 8,758' —14-1/2"OVERSHOT 1 1 8800' H4-1/2"HES X NP,ID=3.813" ,, 8821' H7"X 4-1/2"BKR S-3 PKR,D=3.875" 1 ,,1 y 8844' H4-1/2"HES X NP,ID=3.813" 1 0 8865' —14-1/2"HES XN NIP,ID=3.725" • I4-1/2"TBG,12.6#,L-80,.0152 bpf,D-3.958^ H 8877' A 8877' —14-1/2"WLEG,D=3.958" 14 1v `• 9072' —1 LNR TIE-BACK SLV,ID=4.37" 1 * 9083' H7"X 5"BKR ZXP LTP,ID=4.370" o1 .101‘ 9094' --17"X 5"HMC HGR,ID=4.410" .4 A 9100' —15"X 4-1/2"XO,ID=3.90" 4, • 9-5/8"CSG,47#,L-80 BTC,ID=8.681" H --9260 4 t• , ., 9350' —13.70"DEPLOY SLV,ID=3.00" 0I 4-1/2" KB PACKER WHIPSTOCK H 9450' 1. 7"SCAB LNR,26#,L-80,D=6.276" H —9260 4','4'41'.'1'4'4'1 MILLOUT WINDOW (02-14B)9450'-9460' 4�44,4�•�•4/441i 4 4:l..1.1.�..04 1� TOP OF LNR/CMT H 9350' 11200' —+4-112"CIBP(01/06/06) 3-1/2"LNR,, #,L-80 STL,.0087 bpf,ID=2.992" H 9410' 1 PERFORATION SUMMARY ` REF LOG: ON XX/XX/XX 10' PUP w/RA Tag @ XXXX'MD `� ANGLE AT TOP PERF:°@' 41p Note:Refer to Production DB for historical pert dataSIZE SPF INTERVAL Opn/Sqz DATE SQZ ' 3-1/4"6.6#STL L-80 @ 11500' MD . `�,� 2-7/8"6.5#STL L-80 @ 12135'MD !Ji DATE REV BY COMMENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT 06/17/80 ?? ORIGINAL COMPLETION 01/02/14 DU/JMD TREEC/O(12/22/14) WELL: 02-14A 08/13/88 PKR 176 RWO 05/08/15 GJB/PJC PULL PATCH/NP RDCR(5/6-5/7/15) PERMIT No: 2031250 09/08/03 N2ES SIDETRACK(02-14A) 06/29/15 DLH/JMD SET CBP/GLV C/O(06/09/15) API No: 50-029-20446-01 11/18/13 RKT/JMD PULL PXN PLUG(11/13/13) 06/30/15 AID PRE-RIG CLEAN UP SEC 36,T11N,R14E,567'FNL&851'FWL 05/12/14 JLS/PJC SET PATCH(05/10/14) 05/14/14 PJC MIN ID CORRECTION BP Exploration(Alaska) • • . I I • I 0 1 4 I 4 I% II n w fog'., . • 1 I MOP .: • 1074 v. / ICE -. Y'f d • • 40I A " 1111= 3 1 s9:.- z4s� 1 ISO 1, \\\\\\� I 1 1 f :' rrrt ) 1 i I g d2 14 III 114 I 1 I 0 CO Q N I a p _ � . I !O p * I I OV S I IIIII .. 1 ii I I Z 4---- <I --o_a>,i\ I mill. 1i _ 1 Z 1 I 1 A _ _ 1 11 1 J & 3 I sf i1 2 gI I • . � Q' . I _ 1 \ U U a S I U I I \ n W I m Y 0 I \ e e1 1 J f 1 I 3:J. 1 co N I f W'i . •• 0 E- 0 1 Y I ,� a; 'zI 1 1 O W \ \ , ! . N H v \ 1 1 Z a I Ia . _ � A�, 5 \ I . I s nl I Ui .i a - _ _ p oo � MEM J I ✓Or' „ f 1 cc U U �I 1 gl ink y '-=` 11. it !, u Mr o 1 I `;',1LL U EX I 1.Z, E U 3 U I ' 12 H u u I I I IV n = 1 i = • • 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 in the 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 Geologist work)the initial reviewer will cross out that erroneous entry and initial then- 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, 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 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, 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 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 in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • Carlisle, Samantha J (DOA) a'b:,7 From: Loepp, Victoria T (DOA) Sent: Tuesday, May 10, 2016 3:36 PM To: Carlisle, Samantha J (DOA) Subject: FW: Cancel Sundry# 315-428 Sam, Please handle, SCANNED JUN 1 6 2016 Thanx, Victoria From: Lastufka, Joseph N [mailto:Joseph.Lastufka©bp.com] Sent: Wednesday, May 04, 2016 3:27 PM To: Loepp, Victoria T(DOA) Cc: Hyatt,Trevor Subject: Cancel Sundry # 315-428 Victoria, Please cancel Sundry#315-428 for Plug for Redrill of 02-14A.A new sundry will be submitted later this week. If you have any questions, please let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 OM Al MI BP Exploration AlaskaI900 E. Benson Blvd.lRoom: 788DIAnchorage,AK 1 RBDMS Lv MAY 1 1 2016 • ti OF T4j� �w\��\��jyti7 THE STATE Alaska Oil and Gas F�,,;,-s �0, of AsKA Conservation Commission f t =5_ i:- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OPALASllCP Fax. 907.276 7542 �� www.aogcc.alaska.gov John McMullen Q03- /as'Engineering Team LeaderI BP Exploration(Alaska), Inc. - P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-14A Sundry Number: 315-428 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, f Cathy P. Foerster Chair DATED this of July, 2015 Encl. STATE OF ALASKA fF D • ALASKA OIL AND GAS CONSERVATION COMA DN (2(7-5 7 2 -S APPLICATION FOR SUNDRY APPROVALS JUL 16 2015 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 A O Gutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill IZI• 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: 203-125 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development H 99519-6612Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20446-01-00 • 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 0 Nom PBU 02-14A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028308 PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft)* Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11880' • 8995' ' 9121' 8427' 9121'.11200' None Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 27'-108' 27'-108' 1530 520 Surface 2685' 13-3/8" 26'-2711' 26'-2711' 4930 2670 Intermediate 9224' 9-5/8" 24'-9248' 24'-8554' 6870/8150 4760/5080 Scab Liner 6429' 7" 2819'-9248' 2819'-8554' 7240 5410 Liner 2807' 4-1/2" 9072'-11879' 8378'-8995' 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): 9680'-11780' 8891'-8994' 4-1/2"12.6# L-80 8875' Packers and SSSV Type. 7"x 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and ND(ft): 8819'/8125' 12 Attachments' Description Summary of Proposal EI 13.Well Class after proposed work: BOP Sketch Q Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development ® • Service 0 14.Estimated Date for Commencing Operations: 8/1/2015 15 Well Status after proposed work: Oil 0 Gas 0 WDSPL❑ Suspended Ef • 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned ❑ 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 McMulle• Title Engineering Team Leader Signature 2.‘,.......7 Phone +1 907 564 4711 Date 7 .-67— (5— COMMISSION (5 COMMISSION USE ONLY Condi ons• -pproval:Notify Commission so that a representative may witness Sundry Number:_ /.> (72 Plug Integrity 0 BOP Test V Mechanical Integrity Test 0 Location Clearance 0 Other: I30P rCSf-to 35-005, (7v1 I, 5p ' S 2.1+p.5, ) 777--47v/ar pre- VicelCI'" te-51- to 2SaO /9s ' 2C, ArtC2 . IIZ- (L. tl1fl�rtafC plvcr✓✓ C t piavzl �ppr� vtCI P� Spacing Exception Required? Yes❑ No Subsequent Form Required: 16 —4c . APPROVED BYTHE Approved by: a/eCOMMISSIONER COMMISSION Date: 7_24.15--- 1/7-L_ 7_24_1S1/7L 7-/z4/i,5- ORIGINAL -/14/i,jORIGINAL , -� •7. o. �s 7 /. ' S bmit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Alt hrrlents in Duplicate RBDM AUG - 2 2015 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMft ON APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1. Type of Request Abandon 0 Plug Perforations o Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill (ZI " 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: 203-125 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development (ZI 99519-6612Stratigraphic 0 Service ❑ 6. API Number: 50-029-20446-01-00 7. If perforating: 8. Well Name and Numb (W "I E I What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU 02-14A • !UI 14 2D 9 Property Designation(Lease Number): 10. Field/Pools: ADL 0028308 . PRUDHOE BAY,PRUDHOE OIL • ,\0 r C 11. PRESENT WELL CONDITION SUMMARY �J Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11880" 8995' • 9121' 8427' 9121',11200' None Casing Length Size '� TVD Burst Collapse Structural Conductor See Attachment See Att ment `/Z See Attachment See vent See Attachment See Attachment Surface See Attachment See At e- See Attachm See achment See Attachment See Attachment Intermediate See Attachment Se A hment achment j ,See achment See Attachment See Attachment •Production See Attachment e Attachme See Attaolfrient t See Attachment See Attachment See Attachment e Liner See Attachment e Attachment ee Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perf n Depth TVD(ft): Jibing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment - 4-1/2",12.6# L-80 8875' Packers and SSSV Type' 7"x 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 88198125' 12 Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch (ZI Detailed Operations Program 0 Exploratory 0 Stratigr�c 0 Development IZI • Service 0 14 Estimated Date for Commencing Operations: 8/1/2015 , 15. Well Status after,proposed work: / Oil 0 Gas 0 WDSPL 0 Suspended ® • 16 Verbal Approval: Date: WINJ ❑/. GINJ ❑ WAG 0 Abandoned ❑ Commission Representative' OpShutdown ID GSTOR 0 SPLUG 0 P 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 Mc Ile //0iZ...v T e Engineering Team Leader Signature Phone 1 907 564 4711 Date 7 4. /„.„...___ 7::,..1,./ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative Tay itness Sundry Number: // 31S-'-121( Plug Integrity 0 BOP Test 0 Mech lcal Integrity Test 0 Location Clearance Other: I 1 V ,/ ;(94 ••• Spacing Exception Required? Yes 0 f� Subsequent Form Required:012 /r APPROVED BYTHE Approved by: ,/ COMMISSIONER P-/\) COMMISSION Date: 5 ORIGINAL '? i6, , / Submit Form and Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval Q o 0 0 0 0 o 0 • NCO CO A- 0 0 N V Ln N- U x 0 0 0 0 0 0 0 i M M N- Ln M M • O) co .— (N m v CO CO N CO 00 O A- V V LU N COCO LO LU O) CO N- CO LO CC) CA N N- 00 00 00 00 O) CO N N N CO 00 M N N- N CO a) Liv co O (3) CO N- C N N CO N CO C) CA CO C.) 0 21111111 Q QN- O V N N • mt N N N CO CO O N N • O I-- 0 rn0 0 co 0 , co co a Z co Oc, J J N CA 00 N - U O M •N N M O t7 d V V C)r- CO 0) N O LU • CO CO V N V co Co G) (-N co CO N CO J W Ct a)O Q Q N O D LLJ U W Z caJQ22 = 0 Uau_ E7 � Z Z L w w Q w m O D I U Z D U w Z Z cn d U) co m 6) (O a0 V O N (Y) IC) OO V LO O M a CO rn o0 C V d O) O O O N O) o 00 0 0 0 0 0 0 c0 c0 O O O O H 0 W .1 CL > < o 0 1- = m 00 (O �.C) ( w W a L N If) . V If) C7 0 W V) w _ a ,— (i (C) O O ce Q W z . 0 0 - O N N O 0 0 0 D J 0 0 CO 00 o 0 0 0 W W Z o J 0 W o co 00 °O O O O co H H- < 2 � 0_ g g H > wW Z_1 O0 I- o W aa < W C 2 0 0 0 cn cn a a> N Ca M t 0 0 0 00 0 0 0 4-+ G 0) O coLC) __ a0 C o 0) ti O O O O O O O 43)E y 19 Y UO 0 a () -2 .a 2 0 co c~ a (I) v) a) can - 5 Q Q o r I- C' F=. 0000 000 • N eo rn M = m co '+r H CU as L o O 2 4- L a) CI- o o w 0 0 c D W 0 g u Q a a. cn a cn m d d d d d d Q O C7 0 J Q Q Q m (0 CO aJ m OW D D Z a Z W 0_ 0_ < W W O a W W W W W W CC CI) z n_ C9 (9 U W W a W o m 0 9 _1 _1 JCL CLOOww < m mEE v (1) a s m m 0) 0) 0) 0) 0) O O o 0 0 0 0 0 o 0 c CD CD o CD 0 O N N N N N N N .R N = 00 00 oO o0 a0 N N N N N a (o (O (O co (O a 0_ v) 0 a N a' W o < m m WJ COCC< U W a a) E Z▪ Nr -4vvv4v C- r- o N N N N N N N CDCDCDCDCDCDCD To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz 0 b p CTD Engineer Date: July 8, 2015 Re: 02-14A Sundry Approval Sundry approval is requested to plug the 02-14A liner perforations as part of the drilling and completion of the proposed 02-14A CTD sidetrack. History and current status: 02-14 was initially drilled as a barefoot completion 1980. The 9-5/8' production casing was set into the Ivishak. A RWO in 1988 installed and cemented a 7" production liner across the barefoot interval. In 2003 the parent well was rig sidetracked to its current location. The rig initially ran a 7" scab liner from the top of the old cut tubing sub at 9290 all the way up to 2827' MD to repair a logged PC leak at 3280' in the 9-5/8" casing. The 7" liner was fully cemented. The crews saw—20 bbls contaminated cement returns, presumably from the top of the 7", and all cementing parameters seemed normal. The top of the 7" also had an LTP installed. The notes form the 2003 sidetrack reflected that they wanted to perf the Put River and install a straddle assembly, but their economics at the time did not allow the extra expense, so they left a gap between their top of 4-1/2" liner, and their tubing tail. In Feb-2011 the well failed a warm TIFL. After DGLV's were set, a subsequent MIT-IA failed losing 1240 psi in the first 15 minutes. An LDL showed a leak to be at 6163' MD (not a • GLM). The well was made non operable for TxIA communication. the well was patched and lasted 4 more months before a subsequent tubing leak happened. Given the poor caliper results, no further non-rig operations were pursued. The well has been SI non-operable since. Proposed plan: After a planned RWO to perform a tubing swap, Nordic 1 Coiled tubing Drilling rig will drill a - through tubing sidetrack on or around Nov 15, 2015. Nordic 2 will set a whipstock at—10,986' and exit into Zone 1 Ivishak formation in the existing 02-14A perforations. The side track will target Zone 1A/1 B reserves. - The proposed sidetrack is a —2,207' horizontal Ivishak Zone 1A/1 B producer. The lateral will be completed with a 3-1/2" x 3-1/4" x 2-7/8" L-80 liner which will be cemented and perforated isolating the current Zone 1A/1 B perforations. This Sundry covers plugging the existing 02-14A perforations via the 02-14B liner cement lob 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. ,'.5 ADr /vie 6 4q� C�*rud/P Of /14"°46/41./ 9y Cogcvr l�i� w�/� c6G STy/ r /45/ eo4 d °� w a) pro 01 w,' r� q V 'lam wAc� fro / e� ,'� w 401- P.46,4 1 of- t� P.46,4 /lid'Cu ref 1 ki/-- e0.A ,°- The I e/( wQKe �e�19�r o�.(� et l�'✓ 4,,„/or i 4 plat"'� 4,, l e/J for re di•'// f Oa? COM/ lloc- fb , /vio✓ed re core"b oy i e �60 �. Pre-Rig Work 1. V Pull BPV 2. S Pull B&R and RHC insert, Dummy off Shear GLV 3. F Pressure test CIBP 4. C Mill 4-1/2" CIBP and Push to PBTD, Dummy WS drift 5. V Pre CTD Tree Work 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 2 414 psi. 2. RIH and set 4-1/2"whipstock Top at-10,986' MD 3. Mill 3.80"window plus 10' of rathole. Swap the well to 8.5-9.5 ppg PowerPro. 4. PU drilling BHA with GR/Resistivity 5. Drill 4.25" hole to TD at-13,174 MD 6. Run 3-1/2" x 3-1/4" x 2-7/8" L-80 liner leaving TOL at-9,650' MD. 7. Pump primary cement bringing TOC to TOL, 24 bbls of 15.8 ppg liner cmt planned* 8. Cleanout liner and run RPM/GR/CCL log if cement job does not go as planned. 9. Test liner lap to 2,400 psi. 10. Perforate liner per asset instructions (up to 1500') 11. Freeze protect well, set TWC, RDMO Post Rig: 1. V: Pull TWC, tree work as necessary. 2. S: LTP if necessary.*and KO GLV's 3. T: ASRC flowback *Approved alternate plug placement per 20 AAC 25.112(i) Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka VVH_LFEAD GRAY 02-14A _ 02-14A & B TV NOTES:WELL E>70 ACTUATOR 02-148 CTD OKB.REV, 64' PROPOSED 1/j LI , BF.ELEV= 34' -14-1/2"HE.SXNP,D=3.813' fvbx Angle= _°@ �� 20'CONDUCTOR 113' I Datum MD= 91.5#,1+40, 282T H 9-5/8"X 7'LNR TOP R<R Datum TVD: 8800'SS D=19.124" GAS LFT MANDRELS 13-3/8"CSG,72#,N-80 BUTT,D=12.347' H 2717' • ST WD TVD DEV TY PE VLV LATCH PORT DATE � 18 •AS ►j 7 7, ►j 6 4. Minimum ID = 4' ►4 5 04 ►# 4 4. ►. 3 of I. 2 1. ► 1 t' ' ,04 : -14-1/THES XNP,D=3.813" •v 1:� f. 8685' 7'X 4-1/2"FES TNT PKR D=3.865" '� NI H4-1/2"HES X NP,D=3.813" _ .! I I -�4-1n"HES x0 SLIDING sLv .1 �►! ' -14-1/2"BLAST JOINTS(_'LONG) I4►�� I�►. 9000' Hr X 4-1/2"HES TNT PKR,D=3.865' ,� ►• ' _ H4-1/THES XNP,D=3.813' 4, �� 9072' J LNR TE E3ACK SLV,D-4.3T 1 4-1/T TBG,12.6#,L-80,.0152 bpf,D=3.958" /4D .y --4-1/2" MEG,LD=3.958" " 04 H B V O TT NOT LOGGED • 4-1/2'EZ DRILL CEP(06/09/15) H 9121'SLMD. ;, '# 9083• _ j7"X 5'BKR ZXP LTP,D=4.370" VVHPSTOCK H -9z18. 1 e9094' -I r X 5'HMC HGR,D=4.410' 9-5/8'CSG,47#,L-80,D=8.681' -1 -9248' �• 9100' HS'X 4 1/2'XO,D=3.90'- 7'SCAB LNR,26#,L-80,D=6.276' -9248' -/'='' MLLOUT VMDOW (02-14A)9248'-9260' TOP OF LNR/CMT -I 9650' _ F.: 9650' _H3.70"DEPLOY SLV,D=3.00' 3-1/2"LNR #,L-80 STL,.0087 bpf,D=2.99? - 10970' 4-1/2"PKR WHIPSTOCK(XX/XX/XX) -{ 10986' 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958' -1 -10986' 10970' H3-1/2"X 3-3/16'XO,D=2.786" PERFORATION SUMti4ARY REF LOG: ON XX/XX/XX 4-1/2"MLLOUT VODOW(02-14B)10986'-_' ANGLE AT TOP PE RF:'Q' Note:Refer to Production DB for historical perf data 11716• H '1T w IRA TAG SIZE SPF '1THNAL Opn/Sgz DATE S[)7 II 8905-8935 3-1/4"LNR,6.6#,L-80 TC11, .0079 bpf,D=2.85" 13134' 13134' -13-3/16"X 2-7/8"X0,D=2.377' PBTD - 2-7/8"LNR,6.5#,L-80 STL, 0058 bpf,D=2.441' -1 13176' I DATE REV BY COMMH'ETS DATE REV BY COMvU'lTS PRUDHOE BAY MIT 06117/80 ?? ORIGINAL COMPLETION L: 02-148 08/13/88 PKR 176 WEI -RWO PERMIT No: 09/08/03 N2E5 SIDETRACK(02-14A) AR No: 50-029-20446-02 06/30/15 JMD RWO&CTD PROPOSED SEC 36,T11N,R14E,567'FNL&851'FML BP Exploration(Alaska) ' TREE= ' . 5'X 7"L FMC 120 WELLHEAD GRAY 02-14A 1Y NOTES:WELL ANGLE>70°@ 9899'. ACJUATOR BAKER C OKB REV 64 LI BF.B.EV= 34' KOP= 9248' ) . Max Angle= 97'@ 11063' 20'CONDUCTOR, — 113' 2194' --{41/2"HES X NP,ID=3.813" Datum MD= 9627 91.5#, -440, Datum TVD= 8800'SS D=19.124' 13-3/8'CSG,72#.N-80 BUTT,D=12.347" — 2717' _I 282T H9-5/8"X 7"LTR TOP FKR 1 GAS LFT MANDRELS r ,• ST MD ND DEV TYPE VLV LATCH PORT DATE Minimum ID =3.725" 8865' •' �• 3 32873286 5 KBG-2 DMY BK 0 03/03/11 1' 11 2 6338 5782 39 KBG-2 DMY BK 0 03/03/11 4-1/2" HES XN NIPPLE t' 1 1 8401 7711 10 KBG-2 DMY BK 0 06/09/15 14 11 1 �' 8800' H 41/2"FEES X NP,ID=3.813" 1' 11 1 ,,� f'/' 8821' --17"X 4-1/2"BKR S-3 PKR,D=3.875" P •;; 8844' —I 4112"FES X NP,D=3.813" t II! ot• �; 8865' H4-1/2"FES XN NP,ID=3.725" o 1 �1 1 1 4-1/2'TBG, 12.6#.L-80..0152 bpf,0=3.958' 8877' r:. 1. 8877' H 41/2'WLEG,ID=3.958" 11 —{ELM)TT NOT LOGGED 1 1 J1 9072' —I LTR 7" TIE-BACK SLV,D=4.3 .- -c 9083' H7"X 5'BKR ZXP LIP D=4.370" 4-1/2'EZ DRILL CSP(06/09!15) —19121'SLMD N ;4 9094' — T X 5'HMC HGR D=4.410' 9100' —15"X 4-1/2"XO,D=3.90" 0 1' 11 9-5/8"CSG,47#.L-80 BTC,0 8-681' ,-L -9260 I 0.4 1 1' 4, tuLLOUT WINDOW (02-14A)9248'-9260' 1� 1� 7"SCAB LNR,26#,L-80,D=6.276' H —9260 A'v11“Trfl • 14 0111111/11111i1►1r 11,X111111111111111. PERFORATION SUMMARY 41 0.111111111111111 ` REF LOG: 11200' —i41/2"CSP(01!06/O6) ANGLE AT TOP F9RF:57°@9680' •N, Note:Refer to Production DB for historical pert data SCE SPF INTERVAL Opn/Sqz SHOT SOZ 2-7/8" 6 9680-9700 0 04/02/10 2-1/2" 6 9910-9930 0 05/10/06 2-7/8" 6 9930-9958 0 03/14/06 ` 2-1/2" 4 10010-10210 0 09/07/03 . 2-1/2' 4 10430-11110 0 09/07/03 2-1/2" 4 11260—11780 C 09/07/03 ;;`;;� PBTD 11792' lay. 4-1/2"LW, 12.6#,L-80,.0152 bpf,ID=3.958" H 11879' • DATE REV BY COPLENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 06/17/80 ?? ORIGINAL COMPLETION 01/02/14 DU/JMJ I HEE C/O(12/22/14) WELL: 02-14A 08/13/88 PKR 176 MO 05/08/15 GS/PJC FULL PATCH,MP RDCR(5/6-5/7/15) PERMIT No: 2031250 09/08/03 N2E5 SIDETRACK(02-14A) 06/29/15 DLH,JM)SET CSP/GLV C/O(06/09/15) AR No: 50-029-20446-01 11/18/13 F T/JM3 PULL FXN PLUG(11/13/13) 06/30/15 JM.) ARE RIG CLEAN UP SEC 36,T11N,R14E 567'Ft't&851'ANL 05/12/14 JLS/PJC SET PATCH(05/10/14) 05/14/14 PJC MN DCORRECTION BP Exploration(Alaska) 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 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 j 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. XHVZE Image Project Well History File Cover Page This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :;;J..Q 3 - LdS Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: (0 I (Count does include cover sheet) Page Count Matches Number in Scanr ing P¡reparation: 7 YES BY: ~ Date: I~ i3 OS Stage 1 If NO in stage 1 page(s) discrepancies were found: Organizing (done) o Two-sided 1111111111111111111 RESCAN DIGITAL DATA ~skettes No. ~ o Other, No/Type: o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: BY: ~ Date: JJ-. 13 oS Project Proofing Date: ~.:} 13 ( DE:' , ~ x30= (do + Date¡:f.- 13jDS BY: ~ Scanning Preparation BY: ~ BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mf 11111111111111 "III fV\P (Pc> /5/ /5/ = TOTAL PAGES (Count does not include cover sheet) \M P /5/ , ' \ 1111111111111111111 NO /5/ VV1ýJ NO YES /5/ 1111111111111111111 1111111111111111111 /5/ Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc RECEIVED • STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION APR 3 0 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development ® Exploratory ❑ r 203 -125 3. Address: P.0. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029 - 20446 -01 -00 7. Property Designation (Lease Number): _ 8. Well Name and Number: ADLO- 028308 PBU 02 -14A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11880 feet Plugs measured 8865, 11200 feet true vertical 8995 feet Junk measured NONE feet Effective Depth measured 11834 feet Packer measured SEE BELOW feet true vertical 8995 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 94# H -40 30' -110' 30' -110' 1530 520 Surface 2689' 13 -3/8" 72# N -80 29' -2717' 29' -2717' 4930 2670 Intermediate 9222' 9 -5/8" 47# L -80 28' -9248' 28' -8554' 6870 4760 Production 6492' 7" 29# L -80 2819'-9248' 2819' -8554' 8160 7020 Liner 2807' 4 -1/2" 12.6# L -80 9072'- 11879' 8378' -8995' 8430 7500 Perforation depth Measured depthSEE ATTACHED feet _ True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24' -8877' 24' -8183' 7" Liner Top Packer 2827' 2827' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm PKR 8821' 8127' 4 -1/2" Baker ZXP Packer 9083' 8389' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SI SI SI SI SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Service ❑ Stratigraphic ❑ 5 Daily Report of Well Operations 16. Well Status after work: Oil Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ SUSP SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nita Summerhays Printed Name Nita Summ -rh:ys Title Data Manager t AP '/ / � Signatu ��� / ar Aw - ;� /� Phone 564 4035 Date 04/30/2012 RRDMS MAY 0120 Form 10-404 Revised 11/2011 ' 4 !✓ g.2 1 2 Submit Original Only 02 -14A 203 -125 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02 -14A 9/7/03 PER 10,010. 10,210. 9,020.56 9,028.96 02 -14A 9/7/03 PER 10,430. 11,110. 9,027.35 9,013.2 02 -14A 9/7/03 PER 11,260. 11,780. 8,999.08 8,994.33 02 -14A 1/6/06 BPS 11,215. 11,780. 9,002. 8,994.33 02 -14A 3/14/06 APF 9,930. 9,958. 9,001.48 9,009.54 02 -14A 5/10/06 APF 9,910. 9,930. 8,995.1 9,001.48 02 -14A 5/21/09 BPS 8,848. 11,260. 8,154.34 8,999.08 02 -14A 6/28/09 BPP 8,848. 11,260. 8,154.34 8,999.08 02 -14A 6/28/09 BPS 11,215. 11,780. 9,002. 8,994.33 02 -14A 4/1/10 APF 9,690. 9,700. 8,896.59 8,901.86 • 02 -14A 4/2/10 APF 9,680. 9,690. 8,891.21 8,896.59 02 -14A 3/14/11 BPS 8,800. 11,260. 8,106.47 8,999.08 02 -14A 6/10/11 BPP 8,800. 11,260. 8,106.47 8,999.08 02 -14A 4/12/12 BPS 8,865. 9,680. 8,171.3 8,891.21 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 02 -14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/11 /2012' ** *WELL S/I ON ARRIVAL * ** (secure well) 'TAG XN NIP 8852' SLM/8865' MD W/3.77" WRP DRIFT ' * * *CONT WSR ON 4- 12 -12 * ** 4/12/2012; T/I/0= 2500/916/0 Temp= S/I Assist Slickline (Eval for IA repressurization) !Pumped 5 bbls meth followed by 200 bbls 110* F crude down TBG to load. SSL I RIH to set plug. Wing shut swab open ssv open master open casing valves open to :gauges Final Whp's= 200/350/50 4/12 /2012; * * *CONT WSR FROM 4- 11 -12 * ** (secure well) !BRUSH X -NIP @ 8831' SLM & XN -NIP @ 8852' SLM W /KJT, 4 -1/2 BRUSH & 3.50" GAUGE RING. LRS LOADED TUBING W /200 BBLS OF CRUDE. SET 4 -1/2" PXN PLUG & PRONG IN XN @ 886.5' MD ! ** *WELL LEFT S /I, DSO NOTIFIED * ** 4/12/2012 T /I /O= xx/350/50 Temp =SI Pumped 9 bbls of crude down tbg to attemp combo. I ** *Continue to next WSR * ** 4/13/2012 ** *Job continue from 4 -12 -12 WSR * ** CMIT -TxIA failed) 2000psi Pumped a total of 9bbls to bring up to test pressure. First 15min lost 46/44, second 15min lost '38/37, for a total loss of 84/81. Bleed back to 500psi. Tags hung. Valve positions= SV, WV, SSV= closed, MV, IA, OA= open Final WHPS= 500/500/50 4/14/2012lT/I/0= SSV /440/20 Temp =SI Repair Leaking Wellhead 1 • •• ...-. -u. .. 2-.1 .. ,.. '.. . -.'... Stung in to ;test port (400 psi). Bled void to 0 psi. Tighten LDS. Pressured test void to 5000 psi. No leaks. Bled void to 0 psi. 4/15/2012 TWO = 500/395/48. Temp = SI. CMIT- • loll • • "-= D - No 'AL. Integral installed on IA, no color code. T FL © 180' (2 bbls). IA FL near surface. Pressured TP to 2010 psi & IAP to 2005 psi with 7.5 bbls of diesel in 20 min. Monitored for 30 min. In the first 15 minutes TP & IAP lost 20 psi. In the 2nd 15 minutes TP & IAP lost 23 psi. Pressured TP to 2008 psi & IAP to 2004 psi. !Monitored for 30 minutes. In 1st 15 minutes TP lost 12 psi, IAP lost 13 psi. In the 'second 15 minutes TP lost 6 psi, IAP lost 5 psi. Monitored for an additional 15 'minutes. In the 3rd 15 minutes TP & IAP lost 6 psi. Bled TP & IAP to 500 psi in 30 'min (5.9 bbls returned). Job complete. Final WHPs = 500/500/48. SV, WV = C. SSV, MV = 0. IA, OA = OTG. 16:00. FLUIDS PUMPED BBLS 10 DIESEL 210 CRUDE 5 METH 225 TOTAL TREE= GRAY III WELLHEAD = GRAY SAF�N ©TES: ACTUATOR = 'AXELSON 0 4A KB. N3i k = - -- - .... fq BF. ELEV = 34' - KOP = 9248' Max Angle = 7• € 11063' Datum MD = - - - 962 2 ' I 2194' H4-1/2" HEJS X NIP, ID = 3.813" Datum TVD = 8800' SS • 2827' ] -19.518" X T LNR TOP PKR 1 113 -3/8" CSG, 72 #, N-80, ID = 12.34T' H 2717' 1•-- GAS LIFT MANDRELS 1 1 ST MD 1VD DEV TYPE VLV LATCH PORT DATE 10.41.' 1�1 3 3287 3286 5 KBG-2 DMY BK 0 03103111 0 1 2 6338 5782 39 KBG -2 DMY BK 0 03/03/11 0 , 4 1 ► 1 1 1 8401 7711 10 KBG-2 DMY BK 0 09/01/03 1i • 0. Minimum ID = 3.725" @ 8865' ,! � 8800' 1 -1 412" HES X NIP, ID = 3.613' i I1 I ■1 4 -112" HES XN NIPPLE o ► 1 i '4 : :� � r 8821' HT' X 4-1/2" BKR S -3 PKR, ID = 3.875" I 4 1 , 1 1 I 8844' H4-1/2" HES X NIP, ID = 3.813" #4 N l8 E.: 1 8865' — 14 -12" HES XN NIP, ID =3.725" 1 1412" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 8876' Vi N� 8865' — 'I4 -12" PXN PLUG (4/12/12) 1 � ► . , I 8877' I — 41/2' / `8 LEG, ID = 3.9" 11 t4 I 1-1 ELMD TT NOT LOGGED 1 • • 'i • 11 9072' I— LNR TIEBACK SLV, ID = 4.37" 0 ' • • 9083' 1- X 412" BKR ZXP LNR TOP PKR 1 1 111 • /4 MILLOUT WINDOW (02 - 14A) 9248' - 9260' 19 -5/8" CSG, 47 #, L-80, ID = 8.681" H — 9260 11 , 1. ► /1 ∎1 4 01 ∎ / 1111•••••■1 ` •••• •11111 1 i1• 17" SCAB LNR, 26 #, L -80, ID = 6 276" H 9303' 1 1 1 4..0.44 ••••• • • � 1 1111111 ` � 1.!:1.1.1. - t:1, 11200' — CIBP PERFORATION SUMMARY ` (01/06/06) REF LOG: ANGLE AT TOP PERF: 57° @ 9680' Vote: Refer to Production DB for historical pert datz' SIZE SPF INTERVAL Opn/Sgz DATE / ` 2 -7/8" 6 9680 - 9700 0 04/02/10 2 -1/2" 6 9910 - 9930 0 05110106 2 -7/8" 6 9930 - 9958 0 03/14/06 4. 2-1/2" 4 10010 - 10210 0 09/07/03 �;�` �: 2-1/2" 4 10430 - 11110 0 09/07/03 1 PBTD H 11792' I 2-1/2" _ 4 11260 - 11780 C 09/07/03 `111, 14-1/2" LNR, 12.6#, L -80, .0152 bpf, ID = 3.958" 11879' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDFIOE BAY UNIT 06117/80 ?? ORIGINAL COMPLETION 06/26/11 MLMI PJC RJLL PX PLUG (6/11/11) WELL; 02 -14A 08113188 PKR 176 LAST WORKOVER ' 04/21/12 RCT/ PJC SET PXN PLUG (4/12/12) PERMIT No: X031250 09108/03 N2ES RIG SIDETRACK (02 -14A) AR No: 50- 029 - 20446 -01 03/06 /11 BSE/PJC GLV C10 (03102/11) SEC 36, T11 N, R14E, 56T FNL & 851' FWL 0326/11 BSE/PJe SET PX PLUG (03/14/11) 03/31/11 JNUPJC LOCATION/ BF CORRECTIONS BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 - 0 wtq , 41 012 G oa Mr. Tom Maunder cos. Alaska Oil and Gas Conservation Commission 4 nch &ag 'ssi• 333 West 7 Avenue Anchorage, Alaska 99501 a Q 3 - 1 I 2-8 Subject: Corrosion Inhibitor Treatments of GPB DS -02 0 I Li- Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 2 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 WELL LOG TRANSMITTAL PRoAcrivE DiAgNosric SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 900 Benson Blvd. Anchorage, Alaska 99508 and a03 3 /c D3 de9O y 7 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C a� ��` ` 3 all Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 27- Mar-11 02 -14A BL / EDE 50-029- 20446 -01 2) RECEIVED Signed : � Date : APR 1 9 2011 Print Name: & e ti . .• PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E -MAIL : pdsanchorage@memorvloa.com WEBSr'E : www.memorvloa.com C:\Documents and Settings\Diane Williams \Desktop\BP_Transmitdocx NOT OPERABLE: Producer 02 -14A (ap# 2031250) Secured With Downholebing Plug Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] 311 6 1 I Sent: Tuesday, March 15, 2011 2:52 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Rico Hernandez, Claudia; King, Whitney Subject: NOT OPERABLE: Producer 02 -14A (PTD# 2031250) Secured With Downhole Tubing Plug All, Producer 02 -14A (PTD #2031250) ) failed a MITIA after dummy gas lift valves were set in the well. A tubing tail plug has been set to secure the well, and the and the well reclassified as Not Operable. The well will 6e evaluated for a leak detection log to determine the location of the TxIA communication, and then re- evaluated for IAxOA communication. Please let us know if there are any questions. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 - 5102 r Cell (907) 752 -0755 MAR 20 Y Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, February 23, 2011 9:34 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Rico Hernandez, Claudia Subject: UNDER EVALUATION: Producer 02 -14A (PTD# 2031250) Sustained casing pressure on the OA All, Producer 02 -14A (PTD# 2031250) has been found to have sustained casing pressure on the OA. On 02/19/11, the wellhead pressures were tubing /IA/OA equal to 1544/1750/1050 psi. The well has been reclassified as Under Evaluation for further diagnostics. The plan forward is as follows: 1. Wellhead: Pack -off test on the IC 2. DHD: OA repressurization test A TIO plot and wellbore schematic have been included for reference. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/16/2011 UNDER EVALUATION: Producer 0,4A (PTD# 2031250) Sustained casing ssure on the OA Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] I�C 7/24//i Sent: Thursday, February 24, 2011 3:26 PM To: Regg, James B (DOA); AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Producer 02 -14A (PTD# 2031250) Sustained casing pressure on the OA Jim, The TxIA communication diagnostic work is currently scheduled to be completed after the OA repressurization test. The plan is to set DGLVs and perform an MITIA if TxIA communication is confirmed. From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, February 24, 2011 1:08 PM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Producer 02 -14A (PTD# 2031250) Sustained casing pressure on the OA I realize the IA pressure has not reached our notification threshold, but the pressure increase is certainly indicative of something going on. Seems appropriate to diagnose (at least bleed and monitor for buildup). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 I I From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIlntegrityCoordinator @bp.com] Sent: Wednesday, February 23, 2011 9:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Rico Hernandez, Claudia Subject: UNDER EVALUATION: Producer 02 -14A (PTD# 2031250) Sustained casing pressure on the OA All, Producer 02 -14A (PTD# 2031250) has been found to have sustained casing pressure on the OA. On 02/19/11, the wellhead pressures were tubing /IA/OA equal to 1544/1750/1050 psi. The well has been reclassified as Under Evaluation for further diagnostics. The plan forward is as follows: 1. Wellhead: Pack -off test on the IC 2. DHD: OA repressurization test A TIO plot and welibore schematic have been included for reference. «02 -14A TIO Plot 02- 23- 11.doc» «02- 14A.pdf» 2/24/2011 UNDER EVALUATION: Producer 044A (PTD# 2031250) Sustained casing ssure on the OA Page 2 of 2 Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 2/24/2011 PBU 02 -14A PTD 2031250 2/23/2011 TIO Pressures Plot Well: 02 -14 4,000 , • 3,000 - —0-- T bg —F IA 2,000 - —A— OA OOA —f-- 00OA O n t000 • r ......... q.• 12/04/10 12/19/10 01/01/11 01/15/11 01 /29/11 02/12/11 TREE= GRAY WELLHEAD = G RAY • SAFETY ES: _.. 02-1 ACTUATOR = AXELSON 4A KB. ELEV = 58 BF. ELEV = 34' KOP = 9248' Max Angle = 97° @ 11063' Datum MD = 9622' I 2194' 1--{4-1/2" HES X NIP, ID = 3.813" 1 Datum TVD = 8800' SS 113 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2717' 1-- 0 12 2827' H 9 -5/8" X 7" LNR TOP PKR 1 I I GAS LIFT MANDRELS 74 0 ST MD TVD DEV TYPE VLV LATCH PORT DATE ► 3 3287 3286 5 KBG -2 DOME BK 16 06/28/09 �'4 2 6338 5782 39 KBG -2 SO BK 20 06/28/09 �� 1 8401 7710 10 KBG -2 DMY BK 0 09/01/03 4 1 1 1 •{ • Minimum ID = 3.725" @ 8865' �� iii I 8800' - 14 -1/2" HES X NIP, ID = 3.813" 1 4 -1/2" HES XN NIPPLE �� 1 1 ; t ■ IA ii I 8821' H 7" X 4 -112" BKR S -3 PKR, ID = 3.875" I +{ iod 8844' H4 -1/2" HES X NIP, ID = 3.813" I i � 8865' 4 -1/2" HES XN NIP, ID = 3.725" 14 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID= 3.958" I 8876' J 8877' I_ 1 4 -1/2" WLEG, ID = 3.958" 1 I-1 ELMD TT NOT LOGGED I PERFORATION SUMMARY R:� � ;4 , 9072' HLNR TIE-BACK SLV, ID = 4.37" 1 REF LOG: 0 9083' H7" X 4 -112" BKR ZXP LNR TOP PKR 1 ANGLE AT TOP PERF: 57° @ 9680' 'i /4 Note: Refer to Production DB for historical pert data 4 X11 SIZE SPF INTERVAL Opn /Sqz DATE 1Al 1 `4 '1 MILLOUT WINDOW 9248' - 9260' 2 -7/8" 6 9680 - 9700 0 04/02/10 11 2 -1/2" 6 9910 - 9930 0 05/10/06 +l 2 -7/8" 6 9930 - 9958 0 03/14/06 1 4�,, 2-1/2" 4 10010 - 10210 0 09/07/03 F4 ���V�� 2 -1/2" 4 10430 - 11110 0 09/07/03 :411 11 /��1111111 2-1/2" 4 11260 - 11780 C 09/07!03 111111110 1 4 1 0 4 11/1 � t SCAB LNR, 2 6 #, L -80, ID = 6.276" I 9303' 1 i j i i i : iJ , 44 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 9625' ` 1 7" LNR, 29 #, L -80, .0371 bpf, ID = 6,1841 9780' /4 1 TD H 9800' ilil I CIBP (1/6/06)1 11200' 4 \�►\T PBTD H 11792' �`R �. 14 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 11879' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/17/80 ORIGINAL COMPLETION 04/06/10 MV /SV ADD PERF (04/02/10) WELL: 02 -14A 08/13/88 LAST WORKOVER PERMIT No: 2031250 09/08/03 DAC /KK RIG SIDETRACK (02 -14A) API No: 50- 029 - 20446 -01 05/10/06 RLM/PAG PERF CORRECTION (03/14/06) SEC 35, T11 N, R14E, 1390.41' FEL & 1434.32' FNL 06/13/09 GJF /TLH WFD WRP SET (05/21 /09) 06/28/09 DTR/TLH GLV C/O & WRP PULLED BP Exploration (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~tECE!!!E[~ APR(t~201~ 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ O t he r ~J ~ ~ y ,~ ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Exte~li9~lPt?' &~~" Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-ent Suspended Well ^ ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development 0 Exploratory ^ 203-1250 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-20446-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number` ADLO-028308 PBU 02-14A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11880 feet Plugs (measured) 11200' feet true vertical 8995.44 feet Junk (measured) None feet Effective Depth measured 11834 feet Packer (measured) 2827 8821 9083 true vertical 8994.95 feet (true vertical) 2827 8127 8389 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 94# h-40 30 - 110 30 - 110 1530 520 Surface 2689 13-3/8" 72# N-80 29 - 2717 29 - 2717 4930 2670 Intermediate Production 9222 9-5/8" 47# L-80 28 - 9248 28 - 8554 6870 4760 Liner 6429 7"29# L-80 2819 - 9248 2819 - 8554 8160 7020 Liner 2807 4-1/2"12.6# L-80 9072 - 11879 8378 - 8995 8430 7500 Perforation depth: Measured depth: SEE attached - _ _ _ - True Vertical depth: _ _ _ _ - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 24 - 8877 24 - 8183 Packers and SSSV (type, measured and true vertical depth) 7" Liner Toa Packer 2827 2827 4-1/2" Baker S-3 Perm Packer "" 8821 8127 4-1/2" Baker ZXP Packer 9083 8389 12. Stimulation or cement squeeze summary: Intervals treated (measured): ` i w~p? ~ ~` ~ z ,-~ '_ ~ ' t ° ~ s t fi a, `' . Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 4/9/2010 02-14A 203-125 PERF ATTOrHMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02-14A 9/7/03 PER 10,010. 10,210. 9,020.56 9,028.96 02-14A 9/7/03 PER 10,430. 11,110. 9,027.35 9,013.2 02-14A 9/7/03 PER 11,260. 11,780. 8,999.08 8,994.33 02-14A 1/6106 BPS 11,200. 11,780. 9,002. 8,994.33 02-14A 5/10/06 APF 9,910. 9,930. .8,995.1 9,001.48 02-14A 4/1/10 APF 9,690. 9,700. 8,896.59 8,901.86 02-14A 4/2/10 APF 9,680. 9,690. 8,891.21 8,896.59 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 02-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/31/2010 ~`*WELL SHUT-IN ON ARRIVAL*"* (ELINE-ADPERF) INITIAL T/I/O = 1900/300/0 ~RU ELINE FOR ADPERF 3 `"""JOB CONTINUED ON 1 APRIL-2010""* 3/31 /2010 ***WELL SI ON ARRIVAL*"* DRIFTED TBG W/ 3 3/8" DUMMMY GUN, TEL, & S.BAILER, LOC TT 8848' SLM/ 8877' MD (+29'corr) S/D & UNABLE TO PASS 9281'SLM/ 9310' MD, STICKY, NO SAMPLE DRIFTED TBG W/ 2 7/8" DUMMY GUN, STOP DUE TO DEVIATION @ 9886' SLM/ 9915' MD ***WELL S/I ON DEPARTURE*"" 4/1/2010 '"'*JOB CONTINUED FROM 31-MARCH-2010*** SAT DOWN AT 9480' WITH 20' 2-7/8" HSD POWERJET. ABLE TO GET DOWN WITH 10' GUN. ADD PERFORATIONS 9690'-9700' WITH 2-7/8" HSD POWERJET 2906 HMX, 6 SPF, 60 DEGREE PHASING, API: ENTRANCE HOLE = 0.38", PENETRATION = 25.3", DEPTH REFERENCED TO SLB MCNL DATED 9- I J U LY-2005. ***JOB CONTINUED ON 2-APRIL-2010*"* 4/2/2010; JOB CONTINUED FROM 1-APRIL-2010 ;ADD PERFORATIONS 9680'-9690' WITH 2-7/8" HSD POWER JET 2906 ~ HMX, 6 SPF, 60 DEGREE PHASING, DEPTH REFERENCED TO SLB MCNL 'DATED 9-JULY-2005. FINAL T/I/O = 2300/340/100 *"*JOB COMPLETE*** FLUIDS PUMPED BBLS 6 2 diesel 8 Total TREE = GRAY WEj.LHEAD = GRAY ACTUATOR= AXELSON KB. ELEV = 58' BF. ELEV = 34' KOP = 9248' Max Angle = 97 @ 11063' Datum MD = 9622' Datum N D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" 02-14A O 2194` ~-~ 4-1 /2" HES X NIP, ID = 3.813" 282- 9-518" X 7" LNR TOP PKR GAS LIFT MANDRELS 7' ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3287 3286 5 KBG-2 DOME BK 16 06/28/09 2 6338 5782 39 KBG-2 SO BK 20 06/28(09 1 8401 7710 10 KBG-2 DMY BK 0 09/01!03 Minimum ID = 3.725"' @ 8865' 4-1/2" HES XN NIPPLE 8800` ~1/2" HES X NIP, ID = 3.813 $$21' 7" X 4-112" BKR S-3 PKR, ID = 3.875" $$44' 4-1/2" HES X NIP, ID = 3.813"~ 8865' 4-1/2" HES XN NIP, ID = 3.725" 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-j $$76` PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 71° @ 9910' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 6 9910 - 9930 O 05!10106 2-718" 6 9930 - 9958 O 03114106 2-112" 4 10010 - 10210 O 09/07/03 2-1 /2" 4 10430 - 11110 O 09/07/03 2-1 /2" 4 11260 - 11780 G 09/07/03 7" SCAB LNR, 26#, L-80, ID = 6.276" ~ 9303' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9625' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9780' n-~ 9800' CIBP{1/6/06) 11200' PBTD 11792' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11879' DATE REV BY COMMENTS DATE REV BY COMMENTS 06!17180 ORIGINAL COMPLETION 05/10106 RLM/PAG PERF CORRECTION (03/14/06) 08113!88 LAST WORKOVER 06113109 GJF/TLH WFD WRP SET {05/21!09) 09!08!03 DAClKK RIG SIDETRACK (02-14A) 06(28/09 DTR/TLH GLV GO & WRP PULLED 09/26/03 JLJ/TLH GLV GO 01/06/06 BMcNlPJ SET' CIBP @ 11200' 05/10106 RRD/PAG PERF PRUDHOE BAY UNIT WELL: 02-14A PERMIT No: 2031250 API No: 50-029-20446-01 SEC 35, T11 N, R14E, 1390.41' FEL & 1434.32' FNL BP 6cploration (Alaska) 8877' -j4-112" WLEG, ID = 3.958" ELMD TT NOT LOGGED 9072` LNR TIE-BACK SLV, ID = 4.37 9(183' 7" X 4-1 /2" BKR ZXP LNR TOP PKR MILLOUT WINDOW 9248' - 9260' I • <--~,._. MICROFILMED 03/01/2008 DO NOT PLACE .~ ,: _. ~,,. ~-- ; ,: . ~; ~ ` „;. __~ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertsiMicrofilm Marker.doc . ~¿ f/;-I/ð.c STATE OF ALASKA ALAS Oil AND GAS CONSERVATION COMMI.N REPORT OF SUNDRY WELL OPERAìfoNS D D o .. 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P' Stratigraphic 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 57.93 KB 8. Property Designation: ADLO-028308 11. Present Well Condition Summary: Total Depth measured 11880 feet true vertical 8995.44 feet Effective Depth measured 11834 feet true vertical 8994.95 feet Casing Length Size MD Conductor 80' 20" 94# H-40 30'-110' Surface 2689' 13-3/8" 72# N-80 29'-2717' Production 9222' 9-5/8" 47# L-80 28'-9248' Liner 6429' 7" 29# L-80 2819'-9248' Liner 2807' 4-1/2" 12.6# L-80 9072'-11879' Perforation depth: Measured depth: 9910' - 11780' True Vertical depth: 8995' - 8994' Tubing: (size, grade, and measured depth) 4-1/2" Packers and SSSV (type and measured depth) RECEIVED SEP 1 3 Z006 Stimulate D WaiverD Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: 203-1250 omrmss on Exploratory Service 6. API Number: 50-029-20446-01-00 9. Well Name and Number: PBU 02-14A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) None Junk (measured) None TVD 30'-110' 28'-2717' 26'-8554' 2819'-8554' 837'8-8995' Burst 1530 4930 6870 8160 8430 Collapse 520 2670 4760 7020 7500 ,rr~í.\.\NEP; StY :BvM''I'h -" 2C0C, ~. C'l JU\,.' .l ((' 12.6# 8877' 7" Liner Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 2827' 8821' 9083' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 35235 0 0 59008 0 0 15. Well Class after oroposed work: Exploratory Development P' 16. Well Status after proposed work: Oil P' Gas r WAG Oil-Bbl 638 1088 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Tubing pressure 1570 639 Service WINJ WDSPl Title Data Engineer Signatur~ Phone 564-4944 Form 1 0-404 Revised 04/2004 ORIGiNAL Date 9/8/2006 BDMS 8Ft SEP 1 4 200fiSubmit Original Only . . ... '. . - . " 02-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/10/2006 PERFORATE 9910-9930' WITH POWERJET OMEGA CHARGES AT 6 SPF in 4- 1/2" 12.6Ib/ft Liner. *** JOB COMPLETE*** FLUIDS PUMPED BBLS I 1 ~ DIESEL FOR REPORT 1 . TOTAL e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 j03-! db r3~q Lo RE: MWD Formation Evaluation Logs 02-14A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 02-14A: LAS Data & Digital Log Images: 50-029-20446-01 1 CD Rom C¡ ,/'I /<~~ }¡ ;hf-/00 ,~='1~~ ~~. ~ î} r~ Ù Schlumberger '=æ 1') ~ 4)i\~L_ r~' ~¿ ~\ÆD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth A~~~¡;~~ "_"¡J¡ ¡ ;UJ!~SjO¡, Well Job# Log Description Date BL 13-31 A .,)05- ¡wO 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 OS 18-03B -903 ~Of·(¡, 11057071 SBHP SURVEY 12102/05 1 NK-43 rQtf-Cð I 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /C¡C¡ - 057 11183463 LEAK DETECTION LOG 01/28/06 1 OS 06-22A ICj?;~C57 N/A SENSAlMEM LDL 01/28/06 1 OS 11-26 It-,w'- 134- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 J 9~"151- 11098756 PROD PROFILE WIDEFT & GHOST 01/30/06 1 L5-05 )~7-C(cC¡' 11058541 RST 11/11/05 1 Z-29 ie:q-c(~Ç- 11051081 RST 08/10/05 1 L5-09 I C¡C - /-\>4-'- 11090725 RST 11/11/05 1 15-44 ,qr...c - / {D 11194155 RST 01/15/06 1 C-20B ";¿O{-I 14- 11075913 MCNL 08/29/05 1 02-14A Q03 4/~5 11075901 MCNL 07/29/05 1 Z-21A -901- iO , 11076449 RST 06/30/05 1 F-27 A d05- /;)4- 10928641 MCNL 09/01/05 1 MPH-15 -?CS" ISO, 11076486 USIT 12/15/05 13 -31 A -:::)CS-llOb 11133211 SCMT 12/23/05 WGI-04 J 7'1 - cSt; 11183461 USIT 01/26/06 WGI-04 /"7'1 -CSt> 11211566 US IT 02/03/06 WGI-08 I '-1D'" 044 10987559 USIT 01/02/06 WGI-08 ,tto - C'4Q 11058259 USIT 01/12/06 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~t:-...¡.,..~lN,bC FEB: 2; h 2006 Q\a?M,!,\\.k= ~ Date Delivered: n i ........---- { C· . .-J" r'¿ /. (-I 02/09/06 NO. 3677 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ç Field: Prudhoe Bay a03- \ y Color CD ~ 1 1 1 1 1 1 1 1 ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 :::veBde:y: t~QÜö ) ) STATE OF ALASKA l FEB 0 2 ALAb..Á OIL AND GAS CONSERVATION COMrvlov;:,ION 2 006 REPORT OF SUNDRY WELL OPERATIONSAlaska Oil & Gas Cons. Commission o Stimulate D Other []\nChorag8 D Waiver D Time Extension D D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory C, 203-1250 Service D! 6. API Number: 50-029-20446-01-00 9. Well Name and Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 57.93 KB 8. Property Designation: ADL-028308 11. Present Well Condition Summary: Total Depth measured 11880 true vertical 8995.44 Effective Depth measured 11792 true vertical 8994.48 Casing Conductor Surface Production Liner Liner Length 80 2689 9222 6429 2807 Size 20" 94# H-40 13-3/8" 72# N-80 9-5/8" 47# L-80 7" 29# L-80 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 10010 - 10210 True Vertical depth: 9020.56 - 9028.96 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 620 x t~.I::: \." t: I V t: u Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development [;?1' Stratigraphic D 02-14A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) 11200 None feet feet ~CANNEO fEB 0 1 2006 MD 30 - 11 0 28 - 2717 26 - 9248 2819 - 9248 9072 - 11879 TVD 30 - 11 0 28 - 2716.8 26 - 8553.71 2818.76 - 8553.71 8377.83 - 8995.43 Collapse 520 2670 4760 7020 7500 Burst 1530 4930 6870 8160 8430 1 0430 - 11110 9027.35 - 9013.2 Closed 11260 - 11780 Closed 8999.08 - 8994.33 4-1/2" 12.6# L-80 24 - 8877 7" Liner Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 2827 8821 9083 RBDMS BFl, FER 0 6 20D6 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 34339 0 700 SHUT-IN 15. Well Class after Droposed work: Exploratory [" Development r;¡ 16. Well Status after proposed work: Oil r;¡ Gas r' WAG [" Tubing pressure 1567 Service r WDSPL r GINJ r WINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Printed Name Sharmaine Vestal / Signatur~ s:h~J ~~v / '-7~~ ,'-,\ [) I GIN A L Contact Sharmaine Vestal Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 1/27/2006 Submit Original Only · ,.. IT ,..- ., ,.--...... ) ) 02-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 1/2/2006 *** WELL FLOWING UPON ARRIVAL *** DRIFT W/ 3.70" CENT, TEL, SB. TAG TT @ 8850' SLM. DRIFTED TO DEV @ 10,000' SLM. TURN WELL OVER TO DSO. *** MOVE TO DS 2-15*** 1/5/2006 CTU #9, Set CIBP; MIRU unit. MU WFD MHA with PDS Gamma/CCL in carrier and 3.65" JSN. ... Job in Progress - Cant' on WSR 01/06/2006 ... 1/6/2006 CTU #9, Set CIBP; ... Cant' from WSR 01/05/2006... Kill well with 1% KCL. RIH. Log interval 10900-11300 ctmd. Flag pipe at 11225' ctmd. POOH. MU/ RIH w/ CIBP. Tie into flag, set CIBP @ 11,215' ctmd. POOH. RDMO. FLUIDS PUMPED BBLS 121 1 % KCL 106 60/40 Meth 227 TOTAL ~ Ó~ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031250 Well Name/No. PRUDHOE BAY UNIT 02-14A Operator BP EXPLORATION (ALASKA) INC s,eJ. ]1 A.;, ~" . API No. 50-029-20446-01-00 MD 11880-- TVD 8995 ,. Completion Date 9/8/2003 .-- Completion Status i-OIL Current Status 1-01L UIC N ------~-----,_.- -~-~..~.... -_.._--~_._.- REQUIRED INFORMATION Name Interval Start Stop Samples No Directional su~ Yes~ -----..- (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH/ . Scale Media No Start Stop CH Received Comments 5 Slu 1 9200 11696 Case 10/19/2005 MEMORY PPROF and IPROF MEM LEE GR/CCL/STP 9 Jul 2005 (Culled) 9155 11814 Open 1 0/1 0/2003 EWR4, CNP, SLD, ROP 9155 11814 Open 1 0/1 0/2003 EWR4, CNP, SLD, ROP 9155 11814 Open 1 0/1 0/2003 EWR4, CNP, SLD, ROP 9155 11814 Open 1 0/1 0/2003 EWR4, CNP, SLD, ROP 9155 11814 Open 1 0/1 0/2003 EWR4, CNP, SLD, ROP 9155 11814 Open 1 0/1 0/2003 EWR4, CNP, SLD, ROP 9155 11814 Open 1 0/1 0/2003 EWR4, CNP, SLD, ROP 9155 11814 Open 1 0/1 0/2003 EWR4, CNP, SLD, ROP . 9193 11880 9/24/2003 9193 11880 9/24/2003 9193 11880 9/24/2003 MWD 9193 11880 9/24/2003 MWD Sample Set Sent Received Number Comments Mud Log No __m..____'""_.__._"___ -~-----,----~-,- DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, ASI Well Log Information: Log/ Data Digital ~ed/Frmt Log Electr Dataset Number Name Production kt~ \J,,,: ~~ ~ ~~ \\: --- E=;iY D Las 12204 I nd uction/Resistivity Rpt Induction/Resistivity .d) D Las 12204 Neutron . Qrt Neutron ".RJ D Las 12204 Sonic Rpt Sonic ,....á) D Las 12204 Rate of Penetration I1µ'l Rate of Penetration ~ D .¡;¡,Qf ", Co Directional Survey .,,- Rpt Directional Survey ¡-ED D ~4J\' Directional Survey ~Pt Directional Survey I Well Cores/Samples Information: DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031250 Operator BP EXPLORATION (ALASKA) INC Well Name/No. PRUDHOE BAY UNIT 02-14A MD 11880 Completion Status i-OIL Current Status i-OIL TVD 8995 Completion Date 9/8/2003 ADDITIONAL INFORMATION Well Cored? Y / ~ Daily History Received? ~ ~N Chips Received? ~y fN Formation Tops Analysis Received? ~ ._~-_......_-_..'-----'-~~-'~- ._~-~ ~_._~- -~-,-._._-~----~,_._---" Comments: _.-"'--'---~ -----~----=-~- Date: Compliance Reviewed By: API No. 50-029-20446-01-00 UIC N ~~~---,-~----~ ---...----..--- )~y-:-- . . Scbrumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth Well MPC-41 MPG-05 MPL·33 P-06A DS 02-25 ---rr.s.09-10 B-20 Y-25 PSI-10 P-26 02-14A F-12 04-35 15-09A 15-09A .5-09A " J-13 D.S. 09-29 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 10889195 10715440 11058514 11132061 10987525 11058237 10980591 10928605 10715447 10928634 11075901 NA 10889172 10889183 NA 10919942 10877750 10980596 J1 Log Description SBH SURVEY MPSP INJECTION PROFILE INJECTION PROFILE LDL INJECTION PROFILE INJECTION PROFILE 't>~"!V\~~ ~ LDL MEM PPROF W/DEFT MPSP IPROF & WARMABACK MEM PPROF W/DEFT MEM PPROF & IPROF LDL SBHP SURVEY OIL PHASE BOTTOM HOLE SAMPLE OIL PHASE BOTTOM HOLE SAMPLE OIL PHASE BOTTOM HOLE SAMPLE LDL PPROF W/DEFT o&- ~~- Date 12/24/04 11/09/04 06/03/05 10/12/05 06/24/05 08/16/05 08/05/05 11/20/04 01/01/05 06/02/05 07/09/05 06/03/05 10/10/04 11/04/04 02/02/05 02/13/05 06/29/04 08/10/05 NO. 3503 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503- 8 ATTN: Bèth Received by: ~~>- (J...\- 10/18/05 . . ð!ÆJ p:/~ . . St53 --/,&5 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska October 03,2003 RE: MWD Fonnation Evaluation Logs 02-14A, AK-MW-2631997 1 LDWG formatted Disc with verification listing. /'dC)C\q ilPI#: 50-029-20446-01 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: -~ \... Signed: \\.e'\~j"'-\ ~~ ... ~-.,' U -R ~~\'\\.~ a STATE OF ALASKA a ALAS~L AND GAS CONSERVATION COM"'ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 1m Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 567' SNL, 851' EWL, SEC. 36, T11 N, R14E, UM Top of Productive Horizon: 1182' SNL, 1621' WEL, SEC. 35, T11N, R14E, UM Total Depth: 1421' SNL, 134' EWL, SEC. 36, T11N, R14E, UM 40. Location of Well (State Base Plane Coordinates): Surface: x- 687592 y- 5950634 Zone- ASP4 TPI: x- 685137 y- 5949958 Zone- ASP4 Total Depth: x- 686897 y- 5949761 Zone- ASP4 18. Directional Survey 1m Yes 0 No 21. Logs Run: MWD, DIR, GR, RES, ABI 22. 20" 94# 13-3/8" 72# 9-5/8" 47# 7" 26# 4-112" 12.6# CASING, LINER AND CEMENTING RECORD SETTING DEPTH BOTTOM 100' 2717' 9248' 9248' 11879' H-40 N-80 L-80 L-80 L-80 Surface Surface Surface 2819' 9072' One Other 5. Date Comp., Susp., or Aband. 9/8/2003 6. Date Spudded 8/31/2003 7. Date T.D. Reached 9/5/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 57.93' 9. Plug Back Depth (MD+ TVD) 11834 + 8995 Ft 10. Total Depth (MD+TVD) 11880 + 8995 Ft 11. Depth where SSSV set (Nipple) 2194' MD 19. Water depth, if offshore N/A MSL 1b. Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-125 13. API Number 50- 029-20446-01-00 14. Well Number PBU 02-14A 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028308 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 30" 17-1/2" 12-1/4" Scab Lnr 6-1/8" CeMEN,.INéRECORD 431 sx Arcticset 2300 sx Fondu, 400 sx PF 'C' 1100 sx Class 'G', 300 sx PF 'C' 356 sx Class 'G', 348 sx Class 'G' 348 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 4spf MD TVD MD TVD 10010' - 10210' 9021' - 9029' 10430' - 11110' 9027' - 9013' 11260' - 11780' 8999' - 8994' 26. Date First Production: September 21,2003 Date of Test Hours Tested Flow Tubing Casing Pressure Press. 27. None ?ß4~! .~ V~D ! ,. ...Lre.z:-~.. ': :..:.,_....-._.+-~,.....~.~,"....¡ Form 10-407 Revised 2/2003 SIZE 4-112", 12.6#, L-80 DEPTH SET (MD) 8877' PACKER SET (MD) 8821' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BsL GAs-McF WATER-BsL PRODUCTION FOR TEST PERIOD + CALCULATED + 24-HoUR RATE OIL-BSL CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r.:, SEP 2 Q ,nn, -I fØ)MS BFL GAs-McF WATER-BsL u~-(\G\NAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 28. GEOLOGIC MARKEe NAME MD TVD 29. .ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sadlerochit 9204' 8510' None Zone 3 (Top CGL) Zone 2C (Base CGL) Zone 2B (23SB) Zone 2A (21TS) 9390' 8688' 9465' 8754' 9565' 8825' 9734' 8919' Zone 1 B 9851' 8974' Zone 1 A 9942' 9005' I ¡,-;, 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~~ J ~ _ Title Technical Assistant Date (fl·~·O,~ PBU 02-14A 203-125 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "No9 R \ G \ \\j A L Form 10-407 Revised 2/2003 of 1 1 Page BP EXPLORATION Leak-Off Test Summary EMW (ppg) .---.. 10.00 Leak Off Pressure (BHP) ...-- -- - _.---- - ~ -". ..~--_... ---.... 4,443 (psi) Surface Pressure 710 (psi AMW 8.40 (ppg) Test Depth (TVD) 8,554.0 (ft) Test Depth (TMD) .-....--...-..----........-..-...-...... 9,248.0 (ft) 02-14 02-14A Test Type Legal Name: Common Name Test Date 8/30/2003 FIT . c ....3... r' .J ~.>~. ):> I . 0:16:20 AM 5/2003 9/ Printed: I . BP EXPLORATION Operations Summary Report Page 1 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-14 02-14A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 8/25/2003 9/8/2003 Spud Date: 5/21/1980 End: 9/8/2003 Date From - To Hours Task Code NPT Phase Description of Operations . ". ....- -- -.-.... 8/24/2003 16:30 - 00:00 7.50 MOB P PRE RID rig floor and top drive. Bridle up the derrick. Move camp, shop and pit / pump module to 02-14A location. LID derrick and move rig substructure to DS 2. 8/25/2003 00:00 - 01 :00 1.00 MOB P PRE Move rig sub to 02-14A. On location at 01:00. 01 :00 - 02:00 1.00 RIGU P PRE Lay Herculite, spot sub base over 2-14. 02:00 - 03:00 1.00 RIGU P PRE PJSM. Raise and pin derrick. 03:00 - 06:30 3.50 RIGU P PRE RlU floor. Spot shop, camp, pit / pump module, Mud and Geo shacks. 06:30 - 07:30 1.00 RIGU P PRE Bridle down. 07:30 - 08:30 1.00 RIGU P PRE Berm and clean around rig. ACCEPT rig at 08:30 hrs. 08:30 - 09:30 1.00 RIGU P PRE Pre spud safety meeting. Install secondary annulus valve. 09:30 - 12:00 2.50 WHSUR P DECOMP R/U DSM lubricator and pull BPV. RlU circulating lines and test to 3,500 psi. 12:00 - 16:30 4.50 WHSUR P DECOMP Kill well with 9.5 ppg brine through choke at 3 bpm and 60 psi. Verify well is dead. o psi on tubing and annulus. Losses of 130 bbl while circulating to kill well. 16:30 - 20:00 3.50 WHSUR P DECOMP Install BPV with DSM lubricator. Test from below to 80 psi. RID lubricator. Nipple down tree and adapter. Verify tubing hanger threads are 5 3/4" RH ACME. 20:00 - 22:00 2.00 BOPSURP DECOMP N/U BOPE 22:00 - 00:00 2.00 BOPSUR P DECOMP Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of test waived by Jeff Jones of the AOGCC. 8/26/2003 00:00 - 02:00 2.00 BOPSURP DECOMP Complete BOPE and related valves test. 02:00 - 03:00 1.00 WHSUR P DECOMP RlU DSM lubricator and pull TIP and BPV. 03:00 - 06:00 3.00 WHSUR P DECOMP P/U Baker spear. Stab into hanger and pup. Back out LDS. Pumped 25 bbl to fill hole prior to pulling hanger. Pull hanger free with 200K. Pull to 150K to part tubing. 132K string weight. LID tubing hanger and 5 1/2" pup. Pumped another 75 bbl 9.5 ppg brine to keep hole full after pulling hanger free. Loss rate initially 100 bph. RlU to circulate LCM pill. Pumped 20 bbl at 10 ppb Mix II with Flo-Vis. Pumped another 20 bbl LCM pill at -30 ppb Mix II. 06:00 - 08:00 2.00 PULL P DECOMP PJSM. RlU 4 1/2" tubing handling equipment. RlU Cameo Schlumberger spooling unit. Incorporate Herculite and berm under and around unit. 08:00 - 12:00 4.00 PULL P DECOMP Pull and LID 41/2" X 3 1/2" tubing string from cut at 9,322' to 7,300'. Spool dual encapsulated Chemical injection lines and dual SSSV stainless control lines. Filling backside with LCM pill. Losses continually slowing from 60 bph to 20 bph. Total fluid loss for tour 330 bbl. 12:00 - 00:00 12.00 PULL P DECOMP LID 4 1/2" tubing from 7,300' to 6,328'. C/O elevators. LID 3 1/2" tubing from 6,328' to 1,100'. Loss rate at 6 bph. Total fluid loss for tour 65 bbl. 8/27/2003 00:00 - 04:30 4.50 PULL P DECOMP LID 31/2" tubing from 1,100'. LID two Chemical Injection mandrels. Retrieved a total of 70 full joints 41/2", 12.6# tubing, 201 full joints 31/2",9.2# tubing, and a 15.05' cut off, 2 - GLM, and 2- Chemical injection mandrels, 126 - SS bands and 268 - Clline clamps. 04:30 - 06:00 1.50 PULL P DECOMP RID tubing equipment. Clean and clear rig floor. 06:00 - 09:00 3.00 BOPSURP TIEB1 C/O 3 1/2" X 6" VBR to 7"(top set). RlU and test upper and Printed: 9/15/2003 10:21:07 AM . . Page 2 of 11 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-14 02-14A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date , From - To Hours Task I Code NPT Phase 8/27/2003 06:00 - 09:00 3.00 BOPSURP TIEB1 09:00 - 10:30 1.50 CASE P TIEB1 10:30 - 12:00 1.50 CASE P TIEB1 12:00 - 17:00 5.00 CASE P TIEB1 17:00 - 20:30 3.50 CASE P TIEB1 20:30 - 23:30 3.00 CASE P TIEB1 23:30 - 00:00 0.50 CASE P TIEB1 00:00 - 01 :00 1.00 CASE P TIEB1 01 :00 - 02:00 1.00 CASE P TIEB1 02:00 - 03:00 1.00 EVAL P TIEB1 03:00 - 03:30 0.50 EVAL P TIEB1 03:30 - 05:00 1.50 EVAL P TIEB1 05:00 - 06:00 1.00 CASE P TIEB1 06:00 - 07:00 1.00 CASE P TIEB1 07:00 - 14:00 7.00 CASE P TIEB1 8/28/2003 14:00 - 14:30 0.50 CASE P TIEB1 14:30 - 15:00 0.50 CASE P TIEB1 15:00 -16:30 1.50 CASE P TIEB1 16:30 - 17:00 0.50 CASE P TIEB1 17:00 - 18:00 1.00 CASE P TIEB1 18:00 - 20:30 2.50 CEMT P TIEB1 20:30 - 21 :00 0.50 CEMT P TIEB1 Start: Rig Release: Rig Number: Spud Date: 5/21/1980 End: 9/8/2003 8/25/2003 9/8/2003 Description of Operations ...- ---.-..-.--- ________n__ lower rams to 250 psi low and 3,500 psi high. Install wear bushing. M/U 8 1/2" bit and BHA to 939'. M/U 4" drill pipe, 1 X 1, from 939' to 2,555'. RIH with drill pipe from 2,555' to 9,307'. Fill pipe every 3,000'. Tag stump at 9,307'. Circulate and condition 9.5 ppg brine to 9.1 ppg at 6 bpm and 950 psi. POOH with drill pipe from 9,307' to 938'. Spot 30 bbl LCM pill at 3,000'. C/O elevators. Stand back BHA from 938' to 385'. Stand back BHA from 385'. Clear rig floor. P/U and M/U HES 9 5/8" RTTS. RIH with drill pipe. Set RTTS at 2,870'. Test 9 5/8" casing to 3,500 psi for 15 minutes and record. Good test. BID surface equipment. POH with drill pipe. LID RTTS. R/U to run 7" liner. PJSM. M/U float equipment. Check floats. M/U and RIH with 7", 26#, L-80, BTC-M liner to 6,460'. Fill every 5 joints. Run a total of 157 joints 7", 26#, L-80, BTC-M liner. Average M/U torque 7,750 ft-Ibs. Used Best-O-Life 2000 thread compound. M/U hanger / packer and one stand drill pipe to 6,605'. Circulate one liner volume at 6 bpm and 210 psi. RIH with drill pipe from 6,605' to 9,307'. Fill every 10 stands. Tag stump at 9,307'. P/U to place shoe at 9,290'. M/U rotary cement head, manifold, and circulating hoses. Stage pump rate to 6 bpm and 640 psi. Circulate 1.5 times casing volume. PJSM with crew. Pump 5 bbl water and test lines to 4,500 psi. Pump 10 bb18.34 ppg CW-100 and 35 bb110.1 ppg MudPUSH. Pump 114 bbl13.5 ppg lead slurry, followed by 72 bb115.8 ppg tail slurry. Wash lines, drop dart, displace with rig pumps with 9.1 ppg brine. Total displacement 280 bbl. Bump plug. CIP at 19:41 hrs 8/28/2003. Increase pressure to 3,300 psi to set hanger at 2832'. Slack off and increase pressure to 4,200 psi to set packer at 2826'. Good surface indication of hydraulic setting tool shear. Repeat process twice to confirm packer set. Rotate to release from hanger. Increase pump pressure to 1,000 psi and sting out of sleeve. Circulate at 13 bpm and 2,000 psi. Reciprocate pipe. Approximately 20 bbl contaminated cement return. No losses experienced during cement pump or displacement. Top of Tieback Sleeve at 2819', Landing Collar at 9278', Float Shoe at 9303' LID rotary cement head and circulating lines. Clean flow line and shakers. Printed: 9/15/2003 10:21 :07 AM ~. . BP ExpLORATION Operations Summary Report Legal Well Name: 02-14 Common Well Name: 02-14A Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES I i I Date I From - To ! Hours Task! Code NPT; Phase ! i i .----..-- . .~-- --.~._._. ---- 21 :00 - 22:30 1.50 CEMT P 22:30 - 00:00 1.50 CEMT P 00:00 - 02:00 2.00 BOPSURP 8/28/2003 TIEB1 TIEB1 TIEB1 8/29/2003 02:00 - 03:00 1.00 EVAL P TIEB1 03:00 - 04:00 1_00 EVAL P TIEB1 04:00 - 07:30 3.50 EVAL P TIEB1 07:30 - 09:30 2.00 EVAL P TIEB1 09:30 - 12:30 3.00 EVAL P TIEB1 12:30 - 13:30 1.00 EVAL P TIEB1 13:30 - 15:00 1.50 STWHIP P WEXIT 15:00 - 19:30 4.50 STWHIP P WEXIT 19:30 - 20:30 1.00 STWHIP P WEXIT 20:30 - 22:30 2.00 STWHIP P WEXIT 22:30 - 23:30 1_00 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 8/30/2003 00:00 - 01 :30 1.50 STWHIP P WEXIT 01:30-12:00 10.50 STWHIP P WEXIT 12:00 - 12:30 0_50 STWHIP P WEXIT 12:30 - 13:30 1.00 EVAL P WEXIT 13:30 - 16:30 3.00 STWHIP P WEXIT 16:30 - 18:00 1_50 STWHIP P WEXIT 18:00 - 19:00 1.00 DRILL P PROD1 19:00 - 21 :00 2.00 DRILL P PROD1 21 :00 - 23:00 2.00 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 8/31/2003 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 05:00 2.00 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P PROD1 05:30 - 08:00 2_50 DRILL P PROD1 Page 3 of 11 Start: Rig Release: Rig Number: Spud Date: 5/21/1980 End: 9/8/2003 8/25/2003 9/8/2003 Description of Operations ...........--.--...-.-. Slip and cut drilling line. Service top drive. POOH from 2,806'. LID running tool. Clear rig floor. C/O 7" rams to 31/2" X 6" VBR.. Pull wear bushing. Test to 250 psi low and 3,500 psi high. Install wear bushing. R/U and test 9 5/8" X 7" scab liner to 3,500 psi for 30 minutes. Record test. UCA Compressive Strength reading on cement after 4 hours was 900 psi. P/U 6 1/8" bit and string mill assembly to 962'... C/O handling equipment. RIH with drill pipe from 962' to 9,276'. Tag landing collar / plug at 9,276'. Pump 100 bbl water, 25 bbl spacer, and displace well to 8.4 ppg Flo-Pro milling fluid at 12 bpm and 1800 psi. Slug pipe, B/D surface equipment. POOH with drill pipe from 9,276' to 962'. C/O elevators. Stand back BHA from 962'_ Clear rig floor. PJSM with all personnel. M/U whipstock assembly to 1,006'_ RIH with drill pipe from 1,006' to 9,182'. P/U weight 180K, S/O weight 160K_ PJSM regarding e-line / Gyro RlU. RlU SSDS E-line equipment and Gyrodata tool. RIH with last stand drill pipe. P/U Gyrodata tool. RIH with Gyrodata tool on e-line_ Orient whip stock to 268 degrees with gyro. Set whip stock on L/C at 9,276'_ Set down 15K to set bottom trip anchor. POOH with Gyro tool. POOH with gyrodata tool. RID gyro and e-line equipment. P/U single. Shear off milling assembly with 45K down weight. Mill window. TOW at 9,247', BOW at 9,260'. Recovered 101 Ibs_ metal. Drill / mill new hole to 9,274'. P/U weight 180K, S/O weight 170K, Rot 160K. Torque 3 - 6K. Circulate Hi Vis sweep around at 180 spm and 1,820 psi. Perform FIT at 9,248' with 8.4 ppg mud to 10.0 ppg EMW (710 psi). Monitor hole, pump dry job, remove blower hose. B/D surface equipment. POOH from 9,274' to 977' with drill pipe. POOH with BHA from 977' to 451', LID BHA from 451'. Upper mill in gauge. Clear rig floor. Pull wear bushing, flush BOPE stack, install wear bushing. M/U 6 1/8" kick-off assembly to 138'. Up load MWD and surface check at 250 gpm and 840 psi. PJSM. Install RAS. M/U BHA from 138' to 2,159'. C/O handling equipment. P/U 4" drill pipe from 2,159' to 3,030'. Fill pipe. RIH with drill pipe, 1 X 1, from 3,303' to 3,649' (87 joints). Continue in hole with drill pipe from derrick to 9,218'. Fill pipe at 6,949' and 9,158'. R/U SSDS e-line equipment and Gyrodata tool. RIH with gyrodata tool on e-line. Seat in UBHO. Confirm seat. Tighten and test packoff. Mad pass from 9,220 to 9,250'. Directional drill from 9,264' to 9,327'. Printed: 9/15/2003 10:21 :07 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ,., .. Page 4 of 11 BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: NPT I Phase ! 02-14 02-14A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES 8/31/2003 05:30 - 08:00 From - To Hours i Task Code Date --.-........-. 08:00 - 08:30 08:30 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 00:00 9/1/2003 00:00 - 06:00 2.50 DRILL P 8/25/2003 9/8/2003 Spud Date: 5/21/1980 End: 9/8/2003 Description of Operations ._n__.__ PROD1 ART = 0.00 hrs, AST = 1.49 hrs, ADT = 1.49 hrs P/U weight 190K, S/O weight 150K 0.50 DRILL P 1.50 DRILL P 0.50 DRILL P 1.50 DRILL P PROD1 PROD1 PROD1 PROD1 Slide 63' (9,264' - 9,327') Slide at TF 270 LHS to initiate kickoff from whip stock. Flow rate 250 gpm, on btm 1,800 psi. Monitor well. POOH from 9,327' to 9,218'. POOH with e-line / gyro. RID SSDS e-line unit and Gyrodata tool. RIH from 9,218' to 9,327'. Directional drill from 9,327' to 9,345'. ART = 0.00 hrs, AST = 0.74 hrs, ADT = 0.74 hrs P/U weight 190K, S/O weight 150K Slide 18' (9,327' - 9,345') 12.00 DRILL P Slide at TF HS to continue build. Flow rate 250 gpm, on btm 1,800 psi. PROD1 Directional drill from 9,345' to 9,560'. ART = 0.00 hrs, AST = 9.27 hrs, ADT = 9.27 hrs P/U weight 190K, S/O weight 150K Slide 215' (9,345' - 9,560') 6.00 DRILL P Slide at TF 50 to 90 RHS to build and turn. Flow rate 250 gpm, on btm 1,900 psi. PROD1 Directional drill from 9,560' to 9,661'. ART = 0.00 hrs, AST = 15.85 hrs, ADT = 15.85 hrs 06:00 - 09:00 3.00 DRILL P PROD1 09:00 - 12:00 3.00 DRILL P PROD1 12:00 - 15:00 3.00 BOPSUR P PROD1 P/U weight 185K, S/O weight 145K Slide 101' (9,560' - 9,661') Slide at TF 60 to 90 RHS to maintain inclination and continue RH turn. Flow rate 250 gpm, on btm 1,900 psi. ROP 15 fph Necessary to 'waggle' the BHA to negate excessive dogleg tendencies. Monitor well. Pump dry job. POOH with drill pipe from 9,661' to 2,159'. Stand back BHA. Remove RAS, download MWD. Clear rig floor. Pull wear bushing. R/U to test BOPE. Test BOP and all related valves to 250 psi low and 3,500 psi high. Witness of test waived by Chuck Sheve of the AOGCC. Printed: 9/15/2003 10:21 :07 AM // -- .. '.... BP EXPLORATION Operations Summary Report Page 5 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-14 02 -14A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/25/2003 Rig Release: 9/8/2003 Rig Number: Spud Date: 5/21/1980 End: 9/8/2003 Date From -To Hours Task Code NPT Phase Description of Operations .----..---.. .----......-....- ----.- 9/1/2003 15:00 - 15:30 0.50 BOPSURP PROD1 Install wear bushing. BID surface equipment. 15:30 -16:30 1.00 DRILL P PROD1 Service top drive. 16:30 - 20:00 3.50 DRILL P PROD1 M/U BHA. Change motor BH setting from 2.12 to 1.83 degrees. Upload and surface check MWD. Install RAS. 20:00 - 23:00 3.00 DRILL P PROD1 RIH with drill pipe from 2,158' to 9,157'. SLM on trip in. Accurate strap, no correction. Fill pipe every 3,000'. 23:00 - 00:00 1.00 DRILL P PROD1 Cut and slip 102' drilling line. Inspect brakes. 9/2/2003 00:00 - 00:30 0.50 DRILL P PROD1 RIH With 61/8" Directional BHA No.4 From 9,157' To 9,624' With No Problems - As Precaution Wash To Bottom At 9,661' - No Fill 00:30 - 00:00 23.50 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 9,661' to 10,180' WOB Rotating 15,000# - 25,000#, WOB Sliding 20,000# To 25,000#, RPM 25, Motor RPM 82, Torque Off Bottom 5,000 ft / Ibs - On Bottom 7,000 ft / Ibs, Pump Rate 272 gpm, SPP Off Bottom 1,900 psi, On Bottom 2,110 psi. String Weight Up 190,000#, String Weight Down 150,000#, String Weight Rotating 165,000# - ART = 3.96 Hrs. - AST = 13.49 Hrs. Lithologies Encountered 09/03/2003 9500-9700 Zone 2B 80-90% Sand, mostly fine-grained, cherty, fair to good porosity, GAS Zone. 10-20% Chert, minor silt and shale 9700-9850 Zone 2A Predominately Sand with cherty zones, very fine to fine-grained, fair to good porosity, GAS Zone (9842: Gas / Oil Contact, as recorded by Nukes) 9850-9950 Zone 1 B 90% Sand, very fine to fine-grained, occasionally silty with numerous silty zones, fair porosity, fair oil shows minimally oil productive. 10% silt and shale 9950-10000 Zone 1A 50% Sand, very fine grained, silty and moderately tight. 50% Silt and shale, sandy. Not likely productive. 10000-10160 Zone 1A 90-95% Sand; very fine to fine-grained, medium to well (Target Sands) sorted, becoming cleaner and more porous, 40-50 API GR with 15-20 ohms resistivity. Good oil shows. Oil productive. 9/3/2003 00:00 - 11 :30 11.50 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 10,180' to 10,371' WOB Rotating 15,000# - 25,000#, WOB Sliding 20,000# To 25,000#, RPM 25, Motor RPM 82, Torque Off Bottom 5,000 ft / Ibs - On Bottom 7,000 ft / Ibs, Pump Rate 272 gpm, SPP Off Bottom 1,900 psi, On Bottom 2,110 psi. String Weight Up 190,000#, String Weight Down 150,000#, String Weight Rotating 170,000# - ROP Slowed Down At 10,215' MD And 9,029' TVD From 32 FPH To 12 FPH With Good Differential Pressure Transfered To The Bit While Sliding To Make Turn - Rotated Ahead With Same ROP No Change - Pump Sweep With Beads And Work Into Wall Of Formation - Slide At 85 Degrees Right Of High Side - Continue With Turn Printed: 9/15/2003 10:21 :07 AM ~ . BP EXPLORATION Operations Summary Report Page 6 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-14 02 -14A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 8/25/2003 9/8/2003 Spud Date: 5/21/1980 End: 9/8/2003 Date From - To Hours· Task. Code NPT Phase Description of Operations "·····___·___n_... -.----.---.. . 9/3/2003 00:00 - 11 :30 11.50 DRILL P PROD1 And Raise Geological Target Up 3 Feet To 9,028 TVD To Get Back Into Better ROP Formation - ART = 1.03 Hrs. - AST = 6.87 Hrs. 'NOTE' Stopped Drilling At 10,371' Due To Loss Of MWD Pulse Lithologies Encountered 09/04/2003 10160-10220 Zone 1A 100% Sand, very fine grained, with silt and clay matrix, moderately tight and well cemented. Poor to fair oil shows. Most likely too tight for productivity. 10220-10280 Zone 1A Silty and shaly Sand, high GR, very fine grained poor porosity Likely too tighUimpermeable. 11:30-13:00 1.50 DRILL P 10280-10370 Zone 1A Sand; very fine to fine grained, medium to well sorted, becoming friable to disaggregated, fair to good porosity, fair to good oil shows, 60 API GR, moderately Oil productive. PROD1 Circulate Hi-Vis Sweep At 6.5 BPM With 2,350 Psi. While Rotating And Reciprocating Drill String PROD1 Monitor Well Bore (Static) - POH With Directional BHA No.4 From 10,371' To 9,157' - 25 K Over Pull From 10,080' To 10,060' Work Thru And Clean Up Area Continue To POH To Window With No Problems PROD1 Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment PROD1 POH With Directional BHA No.4 From 9,157' To 198' PROD1 Held PJSM For Radioactive Sources - Pulled BHA To Rig Floor And Removed Sources - Down Load Sperry Sun MWD/LWD Tools - POOH And Laid Down Remainder Of BHA NO.4 - Removed Smith 6 1/8" XR20 Bit And Lay Down Sperry Mud Motor - Clear Rig Floor - Inspected Sperry Sun MWD Pulser Tool It Had Mechanical Failure PROD1 Pick Up 6 1/8" Directional BHA NO.5 - Make Up Sperry Sun 5" Motor With 1.50 Degrees Bent Housing And Orient To MWD Tools - Make Up Security 6 1/8" FM2643 Bit - Initalize MWD Tools And Surface Test - RIH With Directional Drillihg BHA NO.5 RIH With BHA NO.5 On 4" Drill Pipe From Mast To 6,055' - Fill Drill String Every 3,000' RIH With BHA No.5 On 4" Drill Pipe From 6,055' To 9,226' - Fill Drill String Every 3,000' Service Top Drive And Traveling Blocks RIH With BHA NO.5 On 4" Drill Pipe From 9,226' Tag Bridge At 10,100' - Connect Top Drive And Establish Circulation - Wash And Clean Up Area From 10,075' To 10,160' - RIH From 10,160' To 10,308' With No Problems - Take Benchmark Survey At 10,308' - As Precaution Wash To Bottom From 10,308' To 10,371' PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 10,371' to 11,317' WOB Rotating 5,000# - 13,000#, WOB 13:00 - 13:30 0.50 DRILL P 13:30 - 14:00 0.50 DRILL P 14:00 - 18:00 18:00 - 20:30 4.00 DRILL P 2.50 DRILL P 20:30 - 23:30 3.00 DRILL P 23:30 - 00:00 0.50 DRILL P PROD1 9/4/2003 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 01 :30 0.50 DRILL P PROD1 01 :30 - 02:30 1.00 DRILL P PROD1 02:30 - 00:00 21.50 DRILL P Printed: 9/15/2003 10:21:07 AM ~ . BP EXPLORATION . Operations Summary Report Page 7 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-14 02-14A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 8/25/2003 9/8/2003 Spud Date: 5/21/1980 End: 9/8/2003 Date From - To ; Hours Task Code NPT Phase Description of Operations ; 9/4/2003 02:30 - 00:00 21.50 DRILL P PROD1 Sliding 5,000# To 8,000#, RPM 10 To 60, Motor RPM 251, Torque Off Bottom 5,000 ft / Ibs - On Bottom 7,000 ft / Ibs, Pump Rate 326 gpm, SPP Off Bottom 2,640 psi, On Bottom 2,950 psi. String Weight Up 185,000#, String Weight Down 145,000#, String Weight Rotating 165,000# - ART = 8.69 Hrs. - AST = 3.74 Hrs. 'NOTE' Bottoms Up Mud Weight Was Cut From 8.5 PPG To 8.0 PPG 10220-10280 Silty zone, light brown gray, sandy/shaly 10280-10770 Zone 1A (13P) 90-100% Sand, 5-10% Siltstone. Sand: very fine grained, medium to well sorted, generally unconsolidated to friable fair to good oil shows, fair porosity. Ocassional slightly tight 40-50 API GR, 15-20 ohms Res. Oil Productive 10770-11100 Zone 1 A (13P) 95-100% Sand; very fine to fine grained, well sorted, friable to disaggregated, clean, fair to good porosity, fair to good oil shows. Occasional silty streaks. Avg 50 API GR, 17-20 ohms res. Oil productive 11100-11300 (14N) Dark gray silty shale, minor very fine grained sand zones. 11300-11350 Zone 1 B (14P) Sand; fine grained, well sorted, clean, fair to good porosity, generally disaggregated, fair to good oil shows. 30-40 api GR, 20-25 ohms res. Oil Prod. 9/5/2003 00:00 - 07:00 7.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11,317' to 11,880' WOB Rotating 5,000# - 13,000#, WOB Sliding 5,000# To 8,000#, RPM 10 To 60, Motor RPM 251, Torque Off Bottom 5,000 ft / Ibs - On Bottom 7,000 ft / Ibs, Pump Rate 326 gpm, SPP Off Bottom 2,640 psi, On Bottom 2,950 psi. String Weight Up 185,000#, String Weight Down 145,000#, String Weight Rotating 165,000# - ART = 2.8 Hrs. - AST = 1.25 Hrs. Lithologies Encountered 09/05/2003 11350-11550 Zone 1 B Sand; mostly fine-grained, medium to well sorted, mostly unconsolidated, clean, 30-40 API GR, 20-25 ohms res, good porosity, Oil productive 11550-11700 Zone 1 B Mostly sand, as above with silty zones, mostly fine grained, mostly disaggregated, Oil productive. 11700-11880 Zone 1 B Sand; generally fine-grained, some very fine and medium grained, trace tripolitic chert, good porosity & oil shows, clean, generally unconsolidated, 30-45 GR. Oil productive. 07:00 - 08:30 1.50 DRILL P PROD1 Circulate Hi-Vis Sweep At 8 BPM With 2,730 Psi. While Printed: 9/15/2003 10:21:07 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ . Page 8 of 11 BP EXPLORATION Operations Summary Report 02-14 02-14A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES _____m ----..- From - To Hours Task Code 9/5/2003 07:00 - 08:30 08:30 - 10:00 10:00 - 11 :00 11:00 -11:30 11 :30 - 12:30 12:30 - 15:30 15:30 - 17:00 17:00 - 20:00 20:00 - 20:30 20:30 - 21 :30 21 :30 - 23:30 9/6/2003 23:30 - 00:00 00:00 - 00:30 00:30 - 03:30 03:30 - 04:45 04:45 - 05:00 05:00 - 08:00 08:00 - 08:30 08:30 - 09:30 09:30 - 10:00 1.50 DRILL P 1.50 DRILL P 1.00 DRILL P 0.50 DRILL P 1.00 DRILL P 3.00 DRILL P 1.50 DRILL P 3.00 DRILL P 0.50 DRILL P 1.00 DRILL P 2.00 DRILL P 0.50 CASE P 0.50 CASE P 3.00 CASE P 1.25 CASE P 0.25 CASE P 3.00 CASE P 0.50 CASE P 1.00 CASE P 0.50 CASE P Spud Date: 5/21/1980 End: 9/8/2003 Start: Rig Release: Rig Number: NPT I Phase 8/25/2003 9/8/2003 Description of Operations PROD1 Rotating And Reciprocating Drill String PROD1 Monitor Well Bore (Static) - POH With Directional BHA No.5 From 11,880' To 9,225' Above Whipstock Window With No Problems PROD1 Circulate Across Top Of Hole - Slip And Cut 68 Feet Of 1 1/4" Drilling Line PROD1 Service Top Drive And Traveling Blocks PROD1 RIH With Directional BHA No.5 From 9,225' To 11,842' With No Problems - As Precaution Connect Top Drive And Wash To Bottom From 11,842' To 11,880' PROD1 Circulate Hi-Vis Sweep At 8 BPM With 2,640 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) - Spot Liner Running Pill - Pump Dry Job PROD1 POH Laying Down 60 Joints Of 4" Excess Drill Pipe From 11,880' To 9,972' PROD1 POH Standing Back 4" Drill Pipe In Mast With Directional BHA NO.5 From 9,972' To 3,534' PROD1 Change Out Handling Equipment - POH Laying Down 23 Joints Of 3 1/2" HWDP, Circulation Sub, Drilling Jars, And Cross Over Subs From 3,534' To 2,789' - Change Out Handling Equipment PROD1 POH Standing Back 4" Drill Pipe In Mast With Directional BHA NO.5 From 2,789' To 176' PROD1 Flush Out BHA With Fresh Water - POH Laying Down Directional BHA NO.5 - Lay Down Cross Over Sub, And (3) Flex Drill Collars - Down Load Sperry Sun MWD/LWD Tools - Lay Down Hang Off Collar, MWD/LWD Tools, And Float Sub - Drain Mud Motor And Remove Security 6 1/8" FM2643 Bit - Lay Down Sperry Mud Motor - Clear Rig Floor - Monitor Well Bore Static Loss Rate At 3 BPH COMP Rig Up Casing Tools And Equipment To Run 41/2" Liner COMP Rig Up Casing Tools And Equipment To Run 4 1/2" Production Liner COMP P / U And Made Up 4 1/2" 12.6# L-80 Liner With IBT-M Connections - P / U Shoe Track And Baker Lock Connections To Baker Landing Collar - Make Up To Diamond Torque At 3,900 ftllbs - Verified Floats Holding - Pick Up 67 Total Joints And RIH To 2,773' COMP Change Out Handling Equipment To 31/2" DP Elevators - M / U Baker HMC Liner Hanger, ZXP Packer w/ HR Profile, Liner Tie Back Sleeve, And Running Tool - Mix Up Pal/Mix For Running Tool And Allow Time To Set Up - Change Out Handling Equipment P / U Cross Over, (2) 4" Drill Pipe Pup Joints, RIH w/ 1 Stand 4" Drill Pipe From Mast COMP Circulate 4 1/2" Liner Volume At 252 GPM With 180 Psi. - Recorded Liner Weight At 34,000# COMP RIH w/ 67 Jts, 4 1/2" 12.6# Liner On 4" Drill Pipe From 2,927' To 9,242' - Filled 4" Drill Pipe Every 10 Stands COMP Circulate Drill Pipe Volume At Window 6 BPM With 600 Psi. COMP RIH w/ 67 Jts, 4 1/2" 12.6# Liner On 4" Drill Pipe From 9,242' To 11,854' With No Problems - Filled 4" Drill Pipe On The Fly COMP Pick Up And Make Up Baker Cementing Head - Install Circulating Manifold And Hoses - Stage Up Pump Rate And Printed: 9/15/2003 10:21:07 AM 10:00-11:30 11 :30 - 14:00 14:00 -15:00 15:00 - 15:30 15:30 - 19:30 19:30 - 20:00 20:00 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 9/7/2003 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:00 02:00 - 05:30 ~ . BP EXPLORATION Operations Summary Report 1.50 CASE 2.50 CEMT 1.00 CASE 0.50 CASE 4.00 CASE 0.50 CASE 1.00 CASE 0.50 PERF 2.50 PERF 0.50 PERF 1.00 PERF 0.50 PERF 3.50 PERF COMP P COMP Legal Well Name: 02-14 Common Well Name: 02-14A Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date From - To ' Hours I Task Code NPT I Phase .. ........ ..... u__ .... _ 1____. 9/6/2003 09:30 - 10:00 0.50 CASE P P COMP P COMP P COMP P COMP P P COMP COMP P COMP P COMP P P COMP COMP P P COMP COMP .. Page 9 of 11 Start: Rig Release: Rig Number: 8/25/2003 9/8/2003 Spud Date: 5/21/1980 End: 9/8/2003 Description of Operations .........--..-.----- --- Establish Circulation - Up Weight At 190,000#, Down Weight At 140,000# - Tag Bottom At 11,880' With No Fill Circulate And Condition Mud - Reciprocate 4 1/2" Liner Started Getting Sticky After About 15 Minutes (Park Liner) - Stage Up Pump Rate To 5 BPM With 770 Psi. - Hold PJSM Regarding Cementing Operation - Batch Mix 15.8 PPG Cement Shut Down And Turn Over To Dowell - Flood Surface Lines With Water - Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Clear Lines With CW-100 Prior To Going Down Hole - Pump 15 BBLS CW-100 Followed With 25 BBLS Of 9.5 PPG Mud Push And 72 BBS (348 Sacks) 15.8 PPG Class "G" Tail Cement At 4.0 BPM - Wash Up Cement Lines To Floor With Perf Pill - Drop Dart And Displace With 79 BBLS Perf Pill And 52.9 BBLS Of 8.6 PPG Flo-Pro Mud At 5.0 BPM - Slow Rate And Latch Liner Wiper Plug With 89.6 BBLS Pumped Away - Increase Rate To 5.0 BPM Continue To Displace - Slow Rate To 3.7 BPM With Final Circulating Pressure At 1720 Psi. - Bump Liner Plug With A Total Of 131.6 BBLS Pumped - Cement In Place At 13: 1 0 Hours - Pressure Up To 4,000 Psi. To Set Liner Hanger - Bleed Pressure Off And Check Floats (OK) - Release From Liner - Swap Over To Rig Pumps And Pressure Up To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To Maximum Rate And Circulate Cement Up Hole 30 BBLS - Reduce Pump Rate Slack Off String With 50,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process - Increase Pump Rate And Continue To Circulate Out 20 BBLS Cement To Surface At 13 BPM With 2,460 Psi. Top Of Liner At 9079', Landing Collar At 11791', Float Collar At 11834', Float Shoe At 11,877' Displace Well To 8.6 PPG Sea Water At 13.0 BPM With 2,460 Psi. Pump Dry Job - Break Down Circulating Lines And Lay Down Baker Cementing Head POH With Baker 4 1/2" Liner Running Tool From 9,079'- Service Baker Running Tool And Lay Down - Clear And Clean Rig Floor Service Top Drive, Traveling Blocks, And Crown Sheaves Held PJSM - Verify Compressive Strength Of Cement Above 500 Psi. - Test 4 1/2" Liner X 7" Liner X 95/8" Casing At 3,500 Psi. For 30 Minutes Test Good - Hold Pre-Job Safety Meeting Regarding Peforation Gun Handling Operation During This Phase Rig Up Handling Tools And Equipment To Run Perforating Guns Pick Up 1,770' Of 2 1/2" Millennium Guns - 1 ,400' Charges Loaded With 4 SPF At 60 Degree Phase And 370' Of Blanks- Make Up Firing Head And Cross Overs Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment RIH With 2 1/2" Millennium Guns Picking Up 31 Joints Of 2 7/8" Pac Drill Pipe To 2,752' Rig Down 2 7/8" Handling Tools, Power Tongs And Equipment Install Cross Overs - RIH With 21/2" Millennium Guns On 4" Printed: 9/15/2003 10:21 :07 AM ..... .. Page 10 of 11 BP EXPLORATION Operéltions Summary Report Start: Rig Release: Rig Number: NPT I Phase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 02-14 02-14A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - ~o . Hours I Task Code . ..._--------------- 9/7/2003 02:00 - 05:30 3.50 PERF P COMP 05:30 - 06:00 0.50 PERF P COMP 06:00 - 07:00 1.00 PERF P COMP 07:00 - 07:30 0.50 PERF P COMP 07:30 - 11 :30 4.00 PERF P COMP 11 :30 - 12:00 0.50 PERF P COMP 12:00 - 13:00 1.00 PERF P COMP 13:00 - 14:00 1.00 PERF P COMP 14:00 -14:30 0.50 PERF P COMP 14:30 - 15:30 1.00 PERF P COMP 15:30 - 19:00 3.50 PERF P COMP 19:00 - 19:30 0.50 PERF P COMP 19:30 - 20:00 0.50 WHSUR P COMP 20:00 - 21 :00 1.00 RUNCOMP COMP 21 :00 - 00:00 3.00 RUNCOMP COMP 9/8/2003 00:00 - 04:30 4.50 RUNCOMP COMP 04:30 - 05:00 0.50 RUNCOMP COMP 05:00 - 05:30 0.50 RUNCOMP COMP 05:30 - 08:00 2.50 RUNCOMP COMP 08:00 - 10:00 2.00 RUNCOMP COMP 8/25/2003 9/8/2003 Spud Date: 5/21/1980 End: 9/8/2003 Description of Operations HT-40 Drill Pipe From 2,752' To 11,789' (Top Of Landing Collar At 11,791' - 2' For Wiper Plugs) Hold Pre-Job Safety Meeting - Place Perf Guns On Depth w/ Bottom Shot At 11,780', Top Shot At 10,010', Spaced Out Throughout The Interval w/ 1,400' Of Loaded Guns At 4 SPF, 60 Degree Phasing- Close Upper Pipe Rams - Pressure Up To 3,200 Psi. And Fire Perf Guns - Bleed Pressure To 0 Psi. - Open Upper Rams POH With 19 Stands Of 4" Drill Pipe In Mast Placing Perf Guns Above Top Shot At 10,010' - From 11,780' To 10,003' Monitor Well Bore Static Loss Rate At 3 BPH - Pump Dry Job - Blow Down Top Drive POH With 2 1/2" Millennium Guns Laying Down 4" Drill Pipe From 10,003' To 2,939' RIH With 4" Drill Pipe From Mast From 2,939' To 4,898' Cut And Slip 95' Of 1 1/4" Drilling Line POH With 2 1/2" Millennium Guns Laying Down 4" Drill Pipe From 4,898' To 2,752' Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment Break Out Cross Overs And POH With 2 1/2" Millennium Guns Laying Down 31 Joints Of 27/8" Pac Drill Pipe From 2,752' To 1,793' Lay Down 1 ,793' Of 2 1/2" Millennium Guns, Firing Head And Cross Overs - All 1 ,400' Charges Fired At 4 SPF At 60 Degree Phase Perforation Intervals: 10,010' To 10,210' 10,430' To 11,110' 11,260' To 11,780' Wash Off And Clear Rig Floor Of Haliburton Tools And Equipment Rig Up And Pull Wear Bushing Rig Up 4 1/2" Tubing Handling Tools, Power Tongs And Equipment Run 41/2" Completion - Pick Up Tail Pipe Assembly Baker Lock Connections Below Baker S -3 Packer - RIH With 4 1/2" (45 Joints) L-80 12.6 lb. IBT-M Tubing To 1,981' -Torque To 3,900 ft/lbs. RIH With 41/2" (209 Joints) L-80 12.6 lb. IBT-M Tubing From 1,981' To 8,847' -Torque To 3,900 ft/lbs. Make Up Gray Gen II Tubing Hanger And Landing Joint - Tubing String Weights With Out Block Weight - Up Weight At 85,000 Ibs. Down Weight At 100,000 Ibs. Land Gray Gen II Tubing Hanger - Run In Lock Down Studs Rig Up Circulating Lines - Reverse Circulate Sea Water And Corrossion Inhibitor At 3 BPM With 170 Psi. Drop Ball And Rod - Pressure Up On The Tubing To 3500 Psi To Set The Packer - Hold The Pressure For 30 Minutes On Chart Recorder For Tubing Test - Bleed The Pressure To 1500 Psi. - Pressure Annulus To 3500 Psi For 30 Mininutes For Packer Test On The Chart Recorder - Bleed Off The Tubing Printed: 9/15/2003 10:21:07 AM / -~- . ~ BP EXPLORATION Operations Summary Report Page 11 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-14 02-14A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/25/2003 Rig Release: 9/8/2003 Rig Number: Spud Date: 5/21/1980 End: 9/8/2003 Date FrOm - To ~ Hours Task Code NPT Phase Description of Operations --...----..--- .--.-----.....- 9/8/2003 08:00 - 10:00 2.00 RUNCOMP COMP Pressure To Shear The DCK Valve Set At 2500 Psi. 10:00 - 10:30 0.50 WHSUR P COMP Install Back Pressure Valve - Test From Below To 1,000 Psi. (Good Test) 10:30 - 11 :00 0.50 BOPSUR P COMP Blow Down Surface Lines And Equipment 11 :00 - 13:00 2.00 BOPSURP COMP Nipple Down 135/8 BOP Stack And Related Equipment 13:00 - 14:30 1.50 WHSUR P COMP Nipple Up Tubing Head Adapter And Production Tree - Test Tubing Head Adapter To 5,000 Psi. (Good Test) 14:30 - 15:00 0.50 WHSUR N SFAL COMP Attempt To Test Production Tree To 5,000 Psi. (No Good) 15:00 - 16:00 1.00 WHSUR N SFAL COMP Rig Up DSM Lubricator And Pull Tree Test Dart - Redress And Reinstall 16:00 - 16:30 0.50 WHSUR P COMP Test Production Tree To 5,000 Psi. (Good Test) 16:30 - 19:00 2.50 RUNCOMP COMP Test Surface Lines At 3,500 Psi. (Test Good) - Reverse Circulate 155 BBLS Diesel Freeze Protection Down Inner Annulus At 2 BPM With 2,000 Psi. 19:00 - 20:30 1.50 RUNCOMP COMP U Tube Diesel Into Tubing From Inner Annulus 20:30 - 22:30 2.00 WHSUR N SFAL COMP 3 Attempts Made To Install BPV - Change Out BPV And Install 22:30 - 23:00 0.50 WHSUR P COMP Test BPV From Below To 1,000 Psi (Test Good) 23:00 - 23:30 0.50 WHSUR P COMP Break Down Surface Equipment - Remove Secondary Annulus Valve 23:30 - 00:00 0.50 WHSUR P COMP Install Tree Cap And Gauges - Secure Well Rig Released From Well Work On DS 02-14A At 24:00 Hours On 09/08/2003 Printed: 9/15/2003 10:21:07 AM e AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 e Re: Distribution of Survey Data for Well 2-14A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,193.93 I MD 9,248.00 I MD 11,880.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Survey Manager Attachment(s) ~~~~~."" ~ 803 ~iQ5 17 -Sep-03 DEFINITIVE Sperry-Sun Drilling Services North S/Ðj BP . PBU_EOA·DS·02 02-14>-2-14A ''-- 2003 sùrveyed: 5 September, Job No. AKZZ0002631997, Survey:Report ,~ 16 Sept~mbf r . 2003 W) Your Ref:A"/~292044601 Surface Coordinates: 5950633.54 N, 687592.00E (70016' 11.8836" N, 148028' 58.0814" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Survey Ref: svy3088 Surface Coordinates relative to proJéCt H Reference: 950633.54 N, 187592.00 E (Grid) Surface Coordinates relative to Structure Reference: 1834.41 N, 2.52 W (True) Kelly Bushing: 57.93ft above Mean Sea Level Elevation relative to Project V Reference: 57. 93ft Elevation relative to Structure Reference: 57. 93ft ....,... I' .y....UI"1 DAILLING SERVices A Halliburton Company Sperry-Sun·· Drilliñg> Services Survey Report for PBU_EOADS 02·02-14 - 2-14A Your Ref: API 500292044601 Job No. AKZZ0002631997, Surveyed: 5 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DDft) 9193.93 2.390 283.070 8441.75 8499.68 866.68 S 2218.79 W 5949711.83 N 685395.50 E 2073.35 Tie On Point AK-6 BP _IFR-AK 9248.00 1.930 280.430 8495.78 8553.71 866.26 S 2220.78 W 5949712.20 N 685393.50 E 0.870 2074.29 Window Point 9278.66 7.410 271.560 8526.32 8584.25 866.11 S 2223.27 W 5949712.29 N 685391.01 E 17.975 2075.74 9310.21 17.670 270.040 8557.08 8615.01 866.05 S 2230.11 W 5949712.18 N 685384.17 E 32.534 2080.02 9341.56 23.960 269.470 8586.37 8644.30 866.11 S 2241.24 W 5949711.84 N 685373.04 E 20.074 2087.09 . 9372.28 25.050 269.060 8614.32 8672.25 866.27 S 2253.98 W 5949711.36 N 685360.31 E 3.591 2095.27 9406.24 24.420 268.280 8645.17 8703.10 866.60 S 2268.19 W 5949710.68 N 685346.11 E 2.089 2104.49 9437.53 30.870 283.770 8672.91 8730.84 864.88 S 2282.49 W 5949712.04 N 685331.78 E 30.714 2112.19 9465.68 35.900 298.990 8696.45 8754.38 859.15 S 2296.75 W 5949717.42 N 685317.37 E 34.588 2116.76 9499.93 43.550 310.310 8722.80 8780.73 846.61 S 2314.58 W 5949729.50 N 685299.24 E 30.670 2118.30 9529.28 45.330 311.210 8743.76 8801.69 833.19 S 2330.15 W 5949742.53 N 685283.34 E 6.433 2117.73 9559.78 51.650 307.460 8763.97 8821.90 818.76 S 2347.82 W 5949756.52 N 685265.32 E 22.668 2117.70 9593.49 55.910 308.740 8783.88 8841.81 801.97 S 2369.21 W 5949772.77 N 685243.51 E 13.003 2118.20 9623.58 55.420 309.250 8800.85 8858.78 786.34 S 2388.52 W 5949787.91 N 685223.82 E 2.147 2118.28 9650.37 53.650 315.870 8816.41 8874.34 771.61 S 2404.59 W 5949802.24 N 685207.39 E 21.177 2117.00 9684.68 57.480 321.410 8835.81 8893.74 750.36 S 2423.25 W 5949823.01 N 685188.21 E 17.371 2112.32 9715.46 59.660 328.910 8851.88 8909.81 728.82 S 2438.22 W 5949844.18 N 685172.71 E 21.958 2105.07 9744.50 58.780 336.100 8866.76 8924.69 706.71 S 2449.73 W 5949865.99 N 685160.64 E 21.482 2095.21 9778.03 60.770 343.450 8883.65 8941.58 679.55 S 2459.72 W 5949892.89 N 685149.98 E 19.844 2080.46 9804.65 63.090 348.550 8896.18 8954.11 656.77 S 2465.39 W 5949915.53 N 685143.75 E 19.016 2066.37 9837.64 66.040 353.380 8910.36 8968.29 627.36 S 2470.05 W 5949944.81 N 685138.36 E 15.959 2046.52 9868.29 67.380 0.240 8922.49 8980.42 599.27 S 2471.60 W 5949972.85 N 685136.10 E 21.015 2025.73 . 9899.09 70.490 6.680 8933.57 8991.50 570.61 S 2469.85 W 5950001.55 N 685137.14 E 21.965 2002.40 9930.72 71.870 13.100 8943.78 9001.71 541.14 S 2464.71 W 5950031.14 N 685141.54 E 19.700 1976.30 9961.75 75.210 19.560 8952.58 9010.51 512.60 S 2456.33 W 5950059.88 N 685149.21 E 22.678 1948.89 9993.58 78.640 25.210 8959.78 9017.71 483.96 S 2444.52 W 5950088.81 N 685160.30 E 20.371 1919.22 10023.48 83.690 30.610 8964.38 9022.31 457.87 S 2430.69 W 5950115.23 N 685173.47 E 24.566 1890.26 . 10058.29 87.160 38.370 8967.16 9025.09 429.30 S 2411.06 W 5950144.28 N 685192.39 E 24.352 1855.71 10089.48 89.140 44.590 8968.17 9026.10 405.96 S 2390.42 W 5950168.13 N 685212.44 E 20.917 1824.58 10117.55 89.010 50.940 8968.62 9026.55 387.10 S 2369.65 W 5950187.50 N 685232.73 E 22.624 1796.84 16 September, 2003 - 9:09 Page 2 of 5 DrillQuest 3.03.02.005 Sperry-Sun Drill!flgServices Survey Report for PBU...EOADS 02 - 02-14. 2-14A Your Ref: API Sð0292044601 Job No. AKZZ0002631997,. Surveyed: 5 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordlnatés Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs NOrthlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 10152.22 87.160 58.720 8969.78 9027.71 367.16 S 2341.35 W 5950208.14 N 685260.53 E 23.053 1763.50 10181.39 89.200 65.270 8970.71 9028.64 353.48 S 2315.62 W 5950222.46 N 685285.90 E 23.506 1736.65 10211.08 89.510 70.950 8971.04 9028.97 342.41 S 2288.09 W 5950234.20 N 685313.16 E 19.158 1710.68 10244.29 90.680 78.010 8970.99 9028.92 333.53 S 2256.11 W 5950243.88 N 685344.90 E 21.548 1683.59 10275.64 90.490 84.730 8970.67 9028.60 328.83 S 2225.13 W 5950249.35 N 685375.75 E 21.443 1660.38 ,,~ . 10303.26 91.850 93.320 8970.10 9028.03 328.36 S 2197.55 W 5950250.51 N 685403.32 E 31.481 1642.60 10341.92 90.490 104.220 8969.31 9027.24 334.25 S 2159.41 W 5950245.58 N 685441.59 E 28.407 1623.07 10372.02 89.260 110.480 8969.38 9027.31 343.22 S 2130.69 W 5950237.32 N 685470.52 E 21.195 1611.89 10422.70 90.490 114.880 8969.49 9027.42 362.75 S 2083.95 W 5950218.96 N 685517.74 E 9.015 1597.50 10465.50 90.430 115.730 8969.14 9027.07 381.05 S 2045.25 W 5950201.63 N 685556.88 E 1.991 1587.25 10513.76 90.370 115.850 8968.81 9026.74 402.04 S 2001.80 W 5950181.73 N 685600.84 E 0.278 1576.08 10557.94 90.310 115.750 8968.54 9026.47 421.27 S 1962.03 W 5950163.50 N 685641.08 E 0.264 1565.86 10607.76 90.310 113.950 8968.27 9026.20 442.21 S 1916.82 W 5950143.69 N 685686.80 E 3.613 1553.54 10652.15 90.190 111.740 8968.08 9026.01 459.44 S 1875.92 W 5950127.49 N 685728.12 E 4.986 1541.07 10701.62 89.880 112.520 8968.05 9025.98 478.08 S 1830.09 W 5950110.00 N 685774.39 E 1.697 1526.57 10746.63 90.680 111.560 8967.83 9025.76 494.97 S 1788.37 W 5950094.15 N 685816.52 E 2.776 1543.31 10795.75 90.680 109.950 8967.25 9025.18 512.37 S 1742.44 W 5950077.90 N 685862.87 E 3.277 1497.80 10841.16 89.940 106.490 8967.00 9024.93 526.57 S 1699.32 W 5950064.78 N 685906.33 E 7.792 1481.56 10891.60 89.570 106.740 8967.22 9025.15 540.99 S 1650.99 W 5950051.57 N 685955.01 E 0.885 1462.22 10935.12 89.320 106.710 8967.64 9025.57 553.51 S 1609.31 W 5950040.09 N 685996.99 E 0.579 1445.60 10966.22 90.680 107.470 8967.64 9025.57 562.65 S 1579.58 W 5950031.69 N 686026.93 E 5.009 1433.91 11000.15 93.400 106.460 8966.43 9024.36 572.55 S 1547.15 W 5950022.61 N 686059.60 E 8.551 1421.10 11028.18 95.250 106.110 8964.32 9022.25 580.38 S 1520.33 W 5950015.45 N 686086.61 E 6.716 1410.23 . 11062.57 96.800 106.270 8960.71 9018.64 589.92 S 1487.48 W 5950006.73 N 686119.68 E 4.531 1396.88 11093.43 96.560 106.390 8957.12 9015.05 598.54 S 1458.07 W 5949998.85 N 686149.30 E 0.868 1384.98 11120.82 96.060 106.100 8954.11 9012.04 606.15 S 1431.93 W 5949991.89 N 686175.62 E 2.107 1374.38 11155.33 96.120 105.990 8950.45 9008.38 615.64 S 1398.95 W 5949983.23 N 686208.83 E 0.362 1360.90 11186.08 96.180 106.020 8947.15 9005.08 624.07 S 1369.57 W 5949975.53 N 686238.41 E 0.218 1348.87 11214.47 96.060 10f...940 8944.13 9002.06 631.84 S 1342.43 W 5949968.44 N 686265.74 E 0.507 1337.76 11249.45 92.350 106.910 8941.56 8999.49 641.70 S 1308.97 W 5949959.41 N 686299.43 E 10.961 1324.27 11280.11 91.670 105.930 8940.49 8998.42 650.36 S 1279.58 W 5949951.49 N 686329.03 E 3.889 1312.42 11308.09 90.740 106.020 8939.90 8997.83 658.06 S 1252.69 W 5949944.46 N 686356.10 E 3.339 1301.41 11342.45 91.910 106.510 8939.10 8997.03 667.68 S 1219.71 W 5949935.67 N 686389.31 E 3.692 1288.04 11373.95 92.100 106.320 8938.00 8995.93 676.58 S 1189.52W 5949927.53 N 686419.72 E 0.853 1275.86 11402.45 91.850 107.220 8937.02 8994.95 684.80 S 1162.24 W 5949919.99 N 686447.18 E 3.276 1265.01 ------ 16 September, 2003 - 9:09 Page 3 0'5 DrillQuest 3.03.02.005 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11451.68 90.560 107.750 8935.98 8993.91 11495.25 90.490 107.880 8935.58 8993.51 11541.81 90.490 107.840 8935.19 8993.12 11588.15 90.430 110.250 8934.81 8992.74 11635.64 89.570 110.800 8934.81 8992.74 11682.29 89.320 112.040 8935.27 8993.20 11733.11 89.380 111.910 8935.84 8993.77 11775.18 89.260 113.910 8936.34 8994.27 11812.72 89.380 114.420 8936.79 8994.72 11880.00 89.380 114.420 8937.51 8995.44 Sperry-SunQI1/~lftg.$érv;ces Survey Report for PBU;'EOADSrJ2· 02·14 . 2-14A Your Ref: API 800292044601 Job No. AKZZ0002631997, Surveyed: 5 September, 2003 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 699.58 S 1115.30 W 5949906.38 N 686494.48 E 2.833 1246.82 712.91 S 1073.82 W 5949894.08 N 686536.28 E 0.339 1230.95 727.19 S 1029.51 W 5949880.91 N 686580.94 E 0.086 1214.03 742.31 S 985.71 W 5949866.89 N 686625.10 E 5.202 1198.09 758.96 S 941.23 W 5949851.35 N 686669.98 E 2.150 1182.91 776.00 S 897.81 W 5949835.41 N 686713.81 E 2.711 1168.69 . 795.01 S 850.68 W 5949817.57 N 686761.40 E 0.282 1153.67 811.39 S 811.94 W 5949802.17 N 686800.54 E 4.762 1141.89 826.76 S 777.69W 5949787.66 N 686835.16 E 1.396 1132.17 854.57 S 716.43 W 5949761.38 N 686897.09 E 0.000 1115.04 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Wen Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 219.170° (True). Magnetic Declination at Surface is 25.841°(28-Aug-03) .' Based upon Minimum Curvature type calculations, at a Measured Depth of 11880.00ft., The Bottom Hole Displacement is 1115.15ft., in the Direction of 219.975° (True). 16 September, 2003 - 9:09 . Page 4 0'5 DrillQuest 3.03.02.005 North Slope Alaska Comments Measured Depth (ft) \..... 9193.93 9248.00 11880.00 Sperry-SlJn~'\' /t1L·, ..~rservíces Survey Report for PBU;;.EÔA,·Þ.JJf2- 02-14 - 2-14A Your Ref: API5Ø02IJ2044601 Job No. AKZZ0002631997, Surveyed: 5 September, 2003 Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) 8499.68 8553.71 8995.44 Comment 866.68 S 866.26 S 854.57 S 2218.79 W 2220.78 W 716.43 W Tie On Point Window Point Projected Survey Survey too/prOgram for 02-14 - 2·14A From Measured Vertical Depth Depth (ft) (ft) 0.00 9193.93 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9193.93 8499.68 11880.00 8499.68 BP High Accuracy Gyro - AK-1 BP _HG (02-14) 8995.44 AK-6 BP _IFR-AK (2-14A) 16 September, 2003 - 9:09 Page 50f5 BPXA . .~ .., DrillQuest 3.03.02.005 e AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 e ðú3 "-;,95 17 -Sep-03 Re: Distribution of Survey Data for Well 2-14A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,193.93' MD 9,248.00 I MD 11,880.00 I MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Survey Manager Attachment(s) ~~~v\" ~ ('\r··n . . ."L....,.... 2.. "'... ...;1. '0> ~<, . Services North S/'ffJ,,~~ldaska SPJfA PBU _êQJS.iiDS~.02 02-14 - 2..14AMWD Sperry-Sun \...... Job No. AKMW0002631997, Surveyed: 5 September, 2003 SurvéyRéport 16 September, 2003 . W) Your Ref: API 500292044601 Surface Coordinates: 5950633.54 N, 687592.()(JE(70016'11.8836" N, 148°28'58.0814" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: 5vy4097 Surface Coordinates relative to Project HReference: 950633.54 N, 187592.00 E (Grid) Surface Coordinates relative to StructurèReferencè : 1834.41 N, 2.52 W (True) Kelly Bushing: 57. 93ft aboVè Mean Sea Level Elevation relative to Project V Réference: 57.93ft Elevation relative to Structure Reference: 57. 93ft !!Ii --I ·1 .\I--u, DRILL.ING SEU=tV'CSS A H.lliburton Comp.ny " Sperry-StJn.!{~\ Survey Report for PBU_etJ 'i2iJ;f4601 Your Ref: API Job No. AKMW0002631997, . Sûrvej1ed: 5 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9193.93 2.390 283.070 8441.75 8499.68 866.68 S 2218.79 W 5949711.83 N 685395.50 E 2073.35 Tie On Point MWD Magnetic 9248.00 1.930 280.430 8495.78 8553.71 866.26 S 2220.78W 5949712.20 N 685393.50 E 0.870 2074.29 Window Point 9278.66 7.410 271.560 8526.32 8584.25 866.11 S 2223.27 W 5949712.29 N 685391.01 E 17.975 2075.74 9310.21 17,670 270 040 8557.08 8615.01 866.05 S 2230.11 W 5949712.18 N 685384.17 E 32.534 2080.02 '.........- 9341.56 23.960 269.470 8586.37 8644.30 866.11 S 2241.24 W 5949711.84 N 685373.04 E 20.074 2087.09 . 9372.28 25.050 269.060 8614.32 8672.25 866.27 S 2253.98 W 5949711.36 N 685360.31 E 3.591 2095.27 9406.24 24.420 268.610 8645.17 8703.10 866.56 S 2268.19 W 5949710.72 N 685346.11 E 1.936 2104.46 9437.53 30.870 284.610 8672.91 8730.84 864.69 S 2282.46 W 5949712.24 N 685331.80 E 31.271 2112.02 9465.68 35.900 300.430 8696.45 8754.38 858.67 S 2296.60 W 5949717.90 N 685317.51 E 35.588 2116.29 9499.93 43.550 311.810 8722.81 8780.74 845.68 S 2314.10 W 5949730.45 N 685299.69 E 30.747 2117.28 9529.28 45.330 312.020 8743.76 8801.69 831.95 S 2329.39 W 5949743.79 N 685284.07 E 6.085 2116.29 9559.78 51.650 308.130 8763.97 8821.90 817.29 S 2346.88 W 5949758.01 N 685266.22 E 22.809 2115.97 9593.49 55.910 308.750 8783.89 8841.82 800.38 S 2368.17 W 5949774.38 N 685244.51 E 12.724 2116.31 9623.58 55.420 309.700 8800.86 8858.79 784.67 S 2387.42 W 5949789.61 N 685224.88 E 3.074 2116.29 9650.37 53.650 316.400 8816.41 8874.34 769.80 S 2403.36 W 5949804.08 N 685208.57 E 21.408 2114.83 If/! 9684.68 57.480 322.160 8835.82 8893.75 748.35 S 2421.78 W 5949825.06 N 685189.62 E 17.779 2109.83 9715.46 59.660 330.360 8851.89 8909.82 726.53 S 2436.33 W 5949846.51 N 685174.54 E 23.802 2102.10 9744.50 58.780 337.030 8866.76 8924.69 704.19 S 2447.38W 5949868.57 N 685162.93 E 19.961 2091.76 9778.03 60.770 344.060 8883.66 8941.59 676.89 S 2457.00 W 5949895.62 N 685152.63 E 19.059 2076.68 9804.65 63.090 349.310 8896.19 8954.12 654.04 S 2462.40 W 5949918.33 N 685146.67 E 19.459 2062.37 9837.64 66.040 353.690 8910.36 8968.29 624.59 S 2466.79 W 5949947.66 N 685141.55 E 14.955 2042.31 9868.29 67.380 0.860 8922.49 8980.42 596.49 S 2468.12 W 5949975.72 N 685139.52 E 21.924 2021.37 . 9899.09 70.490 7.430 8933.57 8991.50 567.85 S 2466.02 W 5950004.40 N 685140.90 E 22.316 1997.84 9930.72 71.870 13.450 8943.79 9001.72 538.43 S 2460.59 W 5950033.95 N 685145.59 E 18.534 1971.60 9961.75 75.210 19.990 8952.59 9010.52 509.95 S 2452.03 W 5950062.63 N 685153.45 E 22.896 1944.11 9993.58 78.640 25.690 8959.79 9017.72 481.40 S 2439.99 W 5950091.48 N 685164.77 E 20.501 1914.37 10023.48 83.690 31.430 8964.39 9022.32 455.48 S 2425.86 W 5950117.74 N 685178.24 E 25.394 1885.35 10058.29 87.160 38.750 8967.17 9025.10 427.11 S 2405.93 W 5950146.60 N 685197.46 E 23.208 1850.77 10089.48 89.140 45.100 8968.17 9026.10 403.93 S 2385.11 W 5950170.29 N 685217.70 E 21.315 1819.65 10117.55 89.010 51.580 8968.63 9026.56 385.28 S 2364.15 W 5950189.45 N 685238.18 E 23.087 1791.96 16 September, 2003·9:21 Page 20f5 Dríl1Quest 3.03.02.005 Sperry-SunPtllf(, .ervices Survey Report for PBU_EOA D$:02 ~'02;1'¡- 2-14A MWD Your Ref: AP/5ðo2Ø2044601 Job No. AKMWOO02631991, Surveyed: 5 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10152.22 87.160 59.430 8969.79 9027.72 365.67 S 2335.62 W 5950209.77 N 685266.22 E 23.249 1758.73 10181.39 89.200 64.470 8970.71 9028.64 351.97 S 2309.90 W 5950224.11 N 685291.59 E 18.631 1731.86 10211.08 89.510 70.870 8971.05 9028.98 340.70 S 2282.45 W 5950236.06 N 685318.75 E 21.580 1705.78 10244.29 90.680 75.780 8970.99 9028.92 331.17 S 2250.65 W 5950246.38 N 685350.30 E 15.198 1678.31 10275.64 90.490 83.330 8970.67 9028.60 325.49 S 2219.84 W 5950252.82 N 685380.96 E 24.089 1654.45 10303.26 91.850 90.210 8970.11 9028.04 323.94 8 2192.29 W 5950255.06 N 685408.47 E 25.386 1635.84 . 10341.92 90.490 101.360 8969.32 9027.25 327.83 8 2153.90 W 5950252.13 N 685446.94 E 29.048 1614.61 10372.02 89.260 113.390 8969.38 9027.31 336.80 8 2125.22 W 5950243.88 N 685475.83 E 40.174 1603.45 10422.70 90.490 111.690 8969.49 9027.42 356.22 S 2078.42 W 5950225.62 N 685523.11 E 4.140 1588.95 10465.50 90.430 109.510 8969.15 9027.08 371.28 8 2038.36 W 5950211.57 N 685563.53 E 5.095 1575.32 10513.76 90.370 101.910 8968.81 9026.74 384.34 8 1991.94 W 5950199.67 N 685610.26 E 15.748 1556.12 10557.94 90.310 111.330 8968.55 9026.48 396.96 S 1949.65 W 5950188.11 N 685652.85 E 21.322 1539.20 10607.76 90.310 103.560 8968.28 9026.21 411.89 S 1902.16W 5950174.37 N 685700.70 E 15.596 1520.77 10652.15 90.190 102.850 8968.09 9026.02 422.03 S 1858.94 W 5950165.31 N 685744.15 E 1.622 1501.34 10701.62 89.880 105.160 8968.06 9025.99 434.00 8 1810.95 W 5950154.54 N 685792.43 E 4.711 1480.30 10746.63 90.680 112.460 8967.84 9025.77 448.50 S 1768.37 W 5950141.11 N 685835.36 E 16.315 1484.65 10795.75 90.680 115.840 8967.25 9025.18 468.59 8 1723.56 W 5950122.14 N 685880.66 E 6.881 1451.93 10841.16 89.940 106.320 8967.01 9024.94 484.90 8 1681.24 W . 5950106.88 N 685923.37 E 21.027 1437.84 10891.60 89.570 111.670 8967.22 9025.15 501.32 8 1633.56 W 5950091.67 N 685971.44 E 10.632 1420.45 10935.12 89.320 109.200 8967.64 9025.57 516.51 S 1592.79 W 5950077.49 N 686012.58 E 5.704 1406.48 10966.22 90.680 107.140 8967.64 9025.57 526.21 8 1563.24 W 5950068.54 N 686042.36 E 7.937 1395.33 11000.15 93.400 108.150 8966.44 9024.37 536.48 S 1530.93 W 5950059.07 N 686074.92 E 8.551 1382.89 11028.18 95.250 108.430 8964.32 9022.25 545.25 8 1504.39 W 5950050.96 N 686101.67 E 6.675 1372.93 . 11062.57 96.800 108.450 8960.71 9018.64 556.07 8 1471.95 W 5950040.96 N 686134.37 E 4.507 1360.83 11093.43 96.560 107.210 8957.12 9015.05 565.46 S 1442.77 W 5950032.30 N 686163.77 E 4.066 1349.67 11120.82 96.060 107.500 8954.11 9012.04 573.58 S 1416.79 W 5950024.83 N 686189.95 E 2.107 1339.56 11155.33 96.120 109.150 8950.45 9008.38 584.37 S 1384.21 W 5950014.86 N 686222.78 E 4.757 1327.34 11186.08 96.180 107.110 8947.16 9005.09 593.88 S 1355.16W 5950006.07 N 686252.06 E 6.599 1316.37 11214.47 96.060 106.620 8944.13 9002.06 602.07 8 1328.14 W 5949998.56 N 686279.27 E 1.767 1305.66 11249.45 92.350 107.090 8941.56 8999.49 612.188 1294.76 W 5949989.28 N 686312.90 E 10.690 1292.41 11280.11 91.670 102.210 8940.49 8998.42 619.93 S 1265.13 W 5949982.27 N 686342.72 E 16060 1279.70 11308.09 90.740 96.920 8939.90 8997.83 624.57 S 1237.55 W 5949978.3'1 N 686370.40 E 19.192 1265.88 11342.45 91.910 104.870 8939.10 8997.03 631.06 S 1203.85 W 5949972.67 N 686404.25 E 23.380 1249.63 11373.95 92.100 105.230 8938.00 8995.93 639.24 S 1173.45 W 5949965.26 N 686434.85 E 1.292 1236.76 11402.45 91.850 101.150 8937.02 8994.95 645.73 S 1145.72 W 5949959.45 N 686462.73 E 14.334 1224.29 16 September, 2003 - 9:21 Page 3 of 5 DrillQuest 3.03.02.005 r - North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11451.68 90.560 101.810 8935.98 8993.91 11495.25 90.490 105.620 8935.58 8993.51 11541.81 90.490 104.650 8935.19 8993.12 11588.15 90.430 105.170 8934.81 8992.74 .,,-- 11635.64 89.570 103.300 8934.81 8992.74 11682.29 89.320 108.210 8935.27 8993.20 11733.11 89.380 108.450 8935.84 8993.77 11775.18 89.260 108.660 8936.34 8994.27 11812.72 89.380 103.020 8936.79 8994.72 11880.00 89.380 114.420 8937.52 8995.45 Sperry-Sun ....~l!.. .. Survey Report for PBU 'PA Your Rel;AR Job No. AKMW0002631997,q;$ti~;· .,.,'" Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 655.53 S 1091.49 W 5949950.86 N 686511.19 E 665.86 S 1055.17W 5949941.59 N 686553.75 E 678.01 S 1010.23 W 5949930.56 N 686598.98 E 689.94 S 965.45 W 5949919.76 N 686644.05 E 701.61 S 919.42 W 5949909.23 N 686690.35 E 714.28 S 874.54 W 5949897.69 N 686735.54 E 730.26 S 826.30 W 5949882.92 N 686784.16 E 743.64 S 786.42 W 5949870.53 N 686824.36 E 753.88 S 750.32 W 5949861.19 N 686860.70 E 775.44 S 686.71 W 5949841.22 N 686924.83 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 219.170° (True). Magnetic Declination at Surface is 25.841°(28-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11880.000., The Bottom Hole Displacement is 1035.80ft., in the Direction of 221.527° (True). "-~." 16 September, 1003· 9:11 Page 4 0'5 BPXA Dogleg Vertical Rate Section Comment (0/100ft) 2.943 1201.42 8.746 1182.69 2.083 1163.73 1.130 1144.69 4.334 1124.67 10.538 1106.14 . 0.487 1088.06 0.575 1073.25 15.026 1058.39 16.943 1034.92 Projected Survey þ . DrillQuest 3.03.01.005 I . North Slope Alaska Comments Measured Depth (ft) 9193.93 9248.00 11880.00 Sperry-Sun. ices Survey Report for PÐU_S ~'2-14A MWD Your Ref: API 1 Job No. AKMWOO02631991, Surveyed: 5 September, 2003 Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) 8499.68 8553.71 8995.45 Comment 866.68 S 866.26 S 775.44 S Tie On Point Window Point Projected Survey 2218.79 W 2220.78 W 686.71 W Survey tool prOf/ram for 02·14 - 2·14A MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 9193.93 ,,--, To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9193.93 8499.68 11880.00 8499.68 BP High Accuracy Gyro· AK-1 BP _HG (02-14) 8995.45 MWD Magnetic (2-14A MWD) 16 September, 2003 - 9:21 Page 50'5 BPXA . " . DrillQuest 3.03.02.005 . (ill lÆ ~!Æ~ . !Æ FRANK H. MURKOWSKI GOVERNOR ~',.4.SKA OILAlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field 02-14A BP Exploration (Alaska) Inc. Permit No: 203-125 Surface Location: 567' SNL, 851' EWL, SEC. 36, T11N, R14E, UM Bottomhole Location: 141O'SNL, 163' EWL, SEC. 36, T11N, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, Sarah Palin Chair ~~~ BY ORDER OF THE COMMISSION DATED this i5t<.day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end. Exploration, Production and Refineries Section 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 687592, Y = 5950634 567' SNL, 851' EWL, SEC. 36, T11N, R14E, UM At top of productive interval x = 685215. Y = 5950136 1005' SNL, 1538' WEL, SEC. 35, T11 N, R14E, UM At total depth x = 686926, Y = 5949773 1410' SNL, 163' EWL, SEC. 36, T11N, R14E, UM 12. Distance to nearest property line 113. Distance to nearest well ADL 028311, 3869' MD 02-108 is 487' away at 10358' MD 16. To be completed for deviated wells _ Kick Off Depth 9275' MD Maximum Hole Angle 18. CaSingJ;~gram Specifications Hole Casina Weight Grade CouDlina N/A 7" 26# L-80 BTC 6-1/8" 4-1/2" 12.6# L-80 IBT . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 11 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 59.2' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool -' ADL 028308 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / 02-14A 9. Approximate spud d~ 08/10/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11880' MD / 8994' TVD 17. Anticipated pressure {s78 20 AAC 25.035 (e) (2)} 98 0 Maximum surface 2450 psig, At total depth (TV D) 8500' / 3300 psig Setting Depth Top Bottom MD TVD MD TVD 2800' 2800' 9320' 8626' 9170' 8476' 11880' 8994' W GIt- 1 / I~ /l.-OQ 3 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Lenath 6520' 2710' Quantity of Cement (include paae data) 592 sx Class 'G' 322 sx Class 'G' , 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9800 feet 9105 feet 9762 feet 9067 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 431 sx Arctic Set 100' 100' 2300 sx Fondu, 400 sx PF 'C' 2717' 2717' 1100 sx Class 'G', 300 sx PF 'C' 9625' 8930' 225 sx Class 'G' 9408' - 9780' 8714' - 9085' 100' 20" 2717' 13-3/8" 9625' 9-5/8" 372' 7" Perforation depth: measured Open: 9587' - 9593', 9668' - 9678', 9686' - 9695', 9705' - 97301\ Sqzd: 9695' - 9696', 9730' - 9736' true vertical Open: 8892' - 8898', 8973' - 8983', 8991' - 9000', ~10'-9035' Sqzd: 9000' - 9001', 9035' - 9041' 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 1120 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I ~erebY certify that the foregoing is ¡rue and correct to the be~t of my ~nowl~~ge . I Signed BiIIlsaacson I.JK-. l. l ~ Title Senior Drilling Engineer Date 1/ ,~Ó "3 ?~;~'/.2.." 1 ~'O~~.o, . ~I!oiii· AI>I;~6o/;~ I :" =e~::"'ents Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required [J Yes m No Hydrogen Sulfide Measures I8J Yes 0 No Directional Survey Required IS! Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU ¿Other:.~:V.· BoPE to 'SSOV' J~". Approved By 12--;rcv_ '. ,_ 5 ". . ¿ . t~ ~~if~N ^ ~tY o~~~:ifssion Date )11 ç1 t7 Form ,0-40, Rev. .qf,8s U" 0 I 1'\ SUbmJ In Triplicate · . 1 Well Name: I DS2-14A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 1 A /1 B Bottom Hole Location: x = 687,592 Y = 5,950,634 566' FNL, 851' FWL Sec. 36, T11 N, R14E Umiat X = 685,215 Y = 5,950,136 TVDss 8956' 1005' FNL, 1538' FEL Sec. 35, T11N, R14E Umiat X = 686,926 Y = 5,949,773 TVDss 8935' 1410' FNL, 163' FWL Sec. 36, T11N, R14E Umiat / / / I AFE Number: I PBD4P2036 I I Rig: 1 Nabors 2ES / I Estimated Start Date: 1 08/10/03 I Operating days to complete: 120.5 / I MD: 111,880 1 I TVD: 18,994' I 1 BF/MS: 130.7' I KB: 128.5' I I KBE: 159.2' I Well Design (conventional, slim hole, etc.): I Horizontal Sidetrack I Objective: I Zone 1 A / 1 B CasingITubing pro£ ram Hole Size Csg/ WtlFt G~e Co~ Length Top Btm Tbg O.D. MDITVD MDITVD 9 5/8 csg 7" tieback 26.0# L-80 STC 6520' 2800 I 2800' 9320 I 8626' 61/8" 4 }2" 12.6# L-80 1ST 2710' 9100' I 8580' 11 ,880 I 8994' Tubing 4 }2" 12.6# L-80 1ST 8850' GL 8880 I 8430' Directional KOP: I 9275' MD Maximum Hole Angle: Close Approach Well{s): Survey Program: _43° at 5500' MD (above window) _2° at the whipstock setting depth -97.7° in 61/8" horizontal section All wells pass major risk criteria. The closest well is DS2-10S at ctr-ctr distance of 487' and allowable deviation of 280' at reference MD of 10,358'. MWD Standard, plus gyro for kickoff Logging Program 61/8" Production: Sample Catchers - over entire interval, samples described and discarded. Drilling: MWD Dir/GRlRes + ABI- Real time GR/Res throughout entire interval. Open Hole: None Cased Hole: Post Rig memory CNL DS2-14A Sidetrack Page 1 Formation Markers Formation Tops (wp05) CM1 THRZ BHRZfTKLB PUT RIVER LCUfT JB TJA TSGR TSHU TSADfTZ4B KOP @ 9275 MD IN Z4B TCGUfZ3 BCGUfZ2C 23SBfTZ2B 21TSfTZ2A TZ1B TDF (TZ1 A)fTOP 13N BSAD AT LANDING PT . TDVss -7443 -7853 -8044 -8147 -8178 -8233 -8325 -8361 -8434 -8517 -8615 -8682 -8757 -8848 -8906 -8934 -8973 TVDbkb 7507 7917 8108 8211 8242 8297 8389 8425 8498 8581 8679 . MD 8194 8610 8801 8905 8936 8991 9083 9119 9192 9275 9373 Comments 9.9 ppg EMW / Land in 13P @ 8956 55, 5' TVD above HOT 10,050 10,960 11,140 InvertfToe up into Z1 B TOP 13P SAND -8943 TDF (TZ1 A)fTOP 13N -8929 TD Criteria: Well needs -800' 'perfable' Zone 1 A and -300 'perfable' Zone 1 B. Absolute TD may be extended, following consultation with town staff, as needed. Mud Program Section Milling Mud Properties: QUIKDRIL-n Density (ppg) I Viscosity I PV I 8.4 - 8.5 45 - 55 4 - 7 Production Mud Properties: QUIKDRIL-n Density (ppg) I Viscosity I PV 8.4 - 8.5 45 - 55 4 - 7 I Whip Stock Window 7" 26# YP I MBT I 25 - 30 <3 pH 8.5 - 9.0 API FI N/C 161/8" hole section YP I MBT 20 - 28 <3 I I pH 8.5 - 9.0 API FI N/C Cement PrOQram I Casing Size Basis: Lead: None Tail: Based on full 6520' of 7" x 9 5/~nnulus with 20 bbls excess + 85' shoe Tail TOC: 2800' MD (leak at 3280') I Fluid Sequence & Volumes: Pre Flush 5bbls CW100 Spacer 30 bbls MudPUSH XL at 10.0 ppg Tail 190 bbls, 1065 ft3, 592"S~cks Class G @ 13.5 ppg, 1.80 ft3/sk 7" 26# L-80 Tieback Liner I Casing Size Basis: Lead: None Tail: Based on 2605' of 4 W' x 61/8" open hole annulus with 40% excess + 85' shoe + 150 liner lap + 200' DP x 7" liner ~nulus Tail TOC: 9125' MD 7 8431' TVD-bkb (Top of Liner) I Fluid Sequence & Volumes: Pre Flush 15bbls CW100 Spacer 20 bbls MudPUSH XL at 9.5 ppg Lead None DS2-14A Sidetrack 4 112" 12.6#, L-80 Solid Liner Page 2 . . Tail ,,/ 167 bbls, 376 ft3, 322 sacks Class G wi Gas-Block @ 15.8 ppg, 1 .17 ft3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing/7" Liner Test Planned completion fluids 13-5/8", 5M, 3 MPL Gates with Annular (Hydril- 13-5/8" GK) 3300 psi (7.5 ppg @ 8500' TV D) 2450 psi (.10 psi/ft gas gradient to surface) Infinite Rams test to 3,500 psi/250 psi. /' Annular test to 2,500 psi/250 psi 3500 psi surface pressure 8.6 ppg Seawater I 7.2 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Com-! lete Procedure Summarï Pre-riCl Operations: In preparation for the sidetrack the following pre-work has been performed: ,/ PPPOT-T Passed 5000 psi, PPPOT-IC Passed 3000 psi 4/19/03 ~ Passed an outer annulus pressure test to 2000 psi on 6/24/03 Remaining Work: 1. Rig up slick line, Remove the 4 W' Camco Bal-O SSSV. Drift 5 W' x 4 W' x 3 W' tubing and tag PBTD at - 9,762' MD. 2. RU e-line and run Schlumberger RST log in gravel pack mode from packer to determine top of fill from the cretaceous leak. 3. R/U coil tubing unit. Plug and abandon the 7" production liner, perforations, and 3 W' tubing up to -9,375' MD with cement. 4. Drift and tag the top of the cement to confirm the tubing is clear to the required cut depth of approximately 9,320'. 5. Fluid-pack the 5 W' x 4 W' x 3 W' tubing and the 9 5/8" x tubing annulus to surface. 6. R/U E-line. RIH with a chemical cutter and cut the 3 W' tubing at -9320' MD, in the middle of the first full joint above the packer I seal assembly (±60' below the Camco chemical injection mandrel at 9,261' MD; or higher as required from RST log results). Top Sag River is 9083' MD. 7. Circulate the well to clean seawater through the tubing cut. Record SICP to determine the kill weight brine to the cretaceous leak. 8. Function all Lock Down Screws. 9. Freeze protect to 2,200', install BPV with lubricator. If necessary, level the pad. Please provide total well preparation cost on the handover form. DS2-14A Sidetrack Page 3 . . RiQ Operations: 1. MIRU Nabors 2ES 2. Circulate out freeze protection and displace well to kill weight brine. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. /' 4. Pull 5 W' x 4 W' x 3 W' tubing from the cut. 5. M/U 8 W' milling BHA. RIH and drift down to the remaining tubing stump. 6. RIH with 9-5/8" test packer to 2800' MD and test 9-5/8" casing back to surface to verify integrity (for / upcoming tie-back liner to repair Cretaceous leak). 7. Run and cement a 7" 26# L-80 tie-back scab liner to cover Cretaceous interval. Liner is planned to /' extend from top of the cut tubing stub at 9320' up to -2800' MD (±85' below the surface casing shoe). 8. RIH with 6-1/8" milling assembly to the landing collar in the tie-back liner. Test 9-5/8" casing and 7" liner above to 3500 psi. / 9. Drill out the landing collar and shoe tract to ±9290'. Re-test the casing to 3500 psi. Change mud over to 8.4 ppg QuickDRILn. 10. RIH with 7" bottom-trip whipstock and milling assembly. Set the whipstock with desired orientation using wireline gyro. / 11. Mill the window and drill 20' of new formation. Perform FIT to 10.0 ppg EMW. 12. Kick off and drill the 61/8" section, per directional plan, to ±10,400' MD end of build and turn. POOH. 13. UD Den/Neu sensors at bit trip. P/U PDC bit and RIH with Dir/GR/Res/ABI assembly. Drill to TD according to directional program. POOH. /'/ 14. Run and cement a 4 W', 12.6#, L-80 production liner. POOH. 15. Test the 9 5/8" X 4 W' liner to 3,500psi for 30 minutes. /é 16. R/U and RIH with Halliburton 2 W' dpc perforating guns. Perforate ±1100' per Halliburton recommendation. Circulate well to seawater, POOH. 17. Run a 4 1/2", 12.6#, L-80 completion, leaving a minimum of 100' above the liner top to access Put ,..-- River for future perforations (tubing WLEG <8880' MD). 18. Set the 7" production packer, test the tubing and annulus to 3,500psi for 30 minutes. /' 19. Nipple down the BOPE. Nipple up and test the tree to 5,000psi. 20. Freeze protect the well to -2,100' and secure the well. 21. Rig down and move off. Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. Run memory CNL. 2. Install well house and instrumentation. Job 1: MIRU Hazards and Contingencies þ> No wells will require shut-in for the rig move onto DS2-14A. The well is located on 60' center from DS2-33A to the south (0"!þdriller's side) and 120' center from DS2-15A to the north. þ> DS2 is not an H:ß site. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: 2-33A 6 ppm 2-10B 6 ppm 2-15A 4 ppm 2-23 5 ppm The maximum level recorded of H2S on the pad was 100 ppm on 02-29A and in 1992. ~ Post Permit to Drill in camp prior to spud. Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP DS2-14A Sidetrack Page 4 . . Job 2: De-complete Well Hazards and Contingencies ~ NORM test all retrieved well head and completion equipment. ~ The well will have pressure from the cretaceous leak at ±3300' MD. The correct brine weight (0.1 ppg overbalance) will be determined during the pre-rig work. ~ In the event of fill behind pipe, the tubing cut may be as high as 9125' MD and still allow for a window at the top Sag River. Reference RP .:. "De-completions" RP / Job 3: Run and Cement 7" Tieback Hazards and Contingencies ~ The cretaceous leak was tested at 4 BPM at 900 psi surface pressure. The relatively large leak may require LCM to reduce losses until cement is in place Reference RP .:. "Whipstock Sidetracks" RP ~'--.mr.T.' Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. ~ The 9 5/8" S-95 casing was cemented with 1100 sacks of 15.8 ppg class G, or roughly 4100' of t"'" gauge annular volume. The 9 5/8" x 13 3/8" annulus was down-squeezed with 300 sacks PFC followed by 125 bbls lightweight Arctic Pack. ~ Be prepared for a second-mill run, though only one of the eight two-string windows milled on the slope has required a second mill run to-date. Reference RP .:. "Whipstock Sidetracks" RP Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies ~ No fault crossings are expected on this well, though the original well experienced slight losses (4 bph) in zone 4 at approximately KOP depth. ~ Based upon real-time log evaluation the well may be extended to obtain sufficient footage in Z1 A reservoir or toe-up into the Z1 B. The "toe-up" depth into Z1 B depends on the footage of good quality Z1 A sands, based on MWD GR/cuttings. ~ Northern and eastern polygon boundaries are hardlines due to potential production interference with the 02-1 OB and 02-04A. The northern boundary is also constrained by a small NW -SE trending fault to the northeast of the PBHL. The western and southern boundaries are not hardlines. They are defined by the area we would like to target, and are not defined by any observed faults. ~ KICK TOLER If: In the worst-case scenario of 8.8 ppg pore pressure in the Ivishak, a fracture gra . nt of .6 ppg at the 7" casing window, and 8.6 ppg mud in the hole, the kick tolerance i Infinit DS2-14A Sidetrack Page 5 . . Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4 1f2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.6ppg mud will be -700psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Due to the length and relatively large amount of directional work required, getting the production liner to bottom may be difficult. The liner run will be modeled on Well Plan to determine if HWDP will be needed to help push the liner down.. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" '.. . '''''''~.",";''...........''''.'~~~.'';~.~ Job 1 0: DPC Perforate Production Liner Hazards and Contingencies ~ Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. "DPC Perforating" RP Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease RiQ Hazards and Contingencies ~ There are no identified hazards particular to this phase of the operation. Reference RP .:. "Freeze Protecting an Inner Annulus" RP DS2-14A Sidetrack Page 6 ,TREE = , WELLHEAD= Gray ~,,~.~A__O_~_~~ ACTUATOR= Axelson KÊ!:ELÉV = 64.0' BF. ELEV = 32.0' ~~~~~,~,~~,~._."m'''~' KOP = 3600' Max Angle = 43° @ 5100' ~u~u~m un u mn m m ummu~u"mn~nu." Datum MD = 9,559' Datum lVD= 8800' SS 151/2" TBG-PC, 17.0#, L-80, ID = 4.892" H · 02-14 Curren~ 113-3/8" CSG, 72#, N-80, ID = 12.347" H 14 1/2" TBG-PC, 12.6#, L-80, ID = 3.958" H 2995' Minimum ID = 2.750" @ 9435' 3 1/2" OTIS 'XN' Landing nipple 131/2" Baker Model G Seal Assembly, ID = 3.00" l-i 195/8" X 31/2" Baker DB Packer, ID = 4.75" l-i 1 Top of 7" Liner 13 1/2" TBG-PC, 9.3#, L-80, ID = 2.99" H H ." ··ì 19-5/8" CSG, 47#, L-80, IDT'ê.~8ÿ// H V I PBTO H I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H TO H DATE 06/17/80 08/13/88 12/27/00 01/18/01 02/16/01 REV BY COMMENTS Original Completion Last Workover SIS-SL T Converted to Canvas SIS-MD Final TP Corrections 47' 1/'- I-~ . 2717' L - ~ 9344' 9345' I í ì 1-:8: Z 9407' 9447' I-I" I 9625' I -.. 9,762' 9780' 9,800' I- I- 1- I :3=:: ::::s:::: :3=:: :3=:: ::::s:::: DATE REV BY COMMENTS 08/06/02 DEW Recreate in Canvas 7 47' l-f 5 1/2" X 4 1/2" Crossover I ~ 2196' H4 1/2" Cameo BAL-O SSSV NIP, ID = 3.813" 2995' H 41/2" X 31/2" Crossover I GAS LIFT / Chemicallnj. MANDRELS ST MD lVD DEV TYÆ VLV LATCH SIZE DATE 1 3287 3286 5° MC-1" BK 2 6527 5937 31° CA 1 1/2" BK 3 9148 8454 2° KBUG 4 9261 8567 2° KBUG BK BK 9435' H3 1/2" OTIS 'XN' Nipple, ID = 2.75" 9447' H3 1/2" Tubing Tail 9440' H ELMD Tubing Tail .. ÆRFORA IDN SUMMARY REF LOG: BHCS 06/07/80 ANGLEATTOPÆRF: 2° @ 9587' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2 1/8" 4 9587 - 9593 0 07/06/97 21/2" 6 9668 - 9678 0 09/04/98 2 5/8" 10 9686 - 9696 0 02/11/91 2 5/8" 4 9706 - 9730 0 02/11/91 25/8" 4 9730 - 9736 S 07/25/90 PRUDHOE BAY UNIT WELL: DS 02-14 ÆRMIT No: 1800180 API No: 50-029-20446-00 Sec. 35, T11N,R14E BP Exploration (Alaska) 02-14A Pro~osed Completi!n 1 Top of 7" Tieback H -2700 1133/8'" 72.0#, N-80 11 2717' I~ Casing,I.D. = 12.347" 17" tieback liner top H -2800' 14 1/2" 12.6# L-80 IBTtubing 3.958" ID Sad MD 17" 26# L-80 BTC 6.276" IDH 9320' Icru P&A Cement H -9,375' 1 1 Top of 7" Liner H 9407' 195/8",47.0#, L-80 11 Casing, J.D. = 8.681" 9625' 17", ~9.0#, L~80, Liner, 11 9780' I.D. -6.184 DATE 06/17/80 08/13/88 12/27/00 01/18/01 02/16/01 REV BY Original Completion Last Workover SIS-SL T Converted to Canvas SIS-MD Rnal TP Corrections ~ <' - ~ -1 ) 8 I I I~ I . ~ I .- I .. .. ;,>,, ~ ....~" ,,~':~'. t{ ==æe<;"~.~',.\~o: ;:" ~~"" ~~.~. '.~:." ' ~;'.....'......: :;W: ~:; I -rr:.}!" ~~~1:,,'''.:''~: ¡,;:..~_.;;:~"':¡!i>'.,,, 2200' H4 1/2" 'X' Nipple ID = 3.813" TREE = erN 4" 5K WELLHEAD= Gray AtruA TOR;"'·~'·~~@ Axels'ön KB. ELEV = 60.5' BF. ELEV = 32.0' - ~~~-,<-~<~,., KOP= 8.150' Max Angle = 90o@ 10,120' DatumMD= 10,115' Datum 1VD= 8,956' SS GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH SIZE DATE 3 TBD TBD DCK 1" 2 TBD TBD DV 1" 1 TBD TBD DV 1" 8830' H41/2" 'X' Nipple, ID = 3.813" 1 8845' H 7" X 4 1/2" Baker S-3 Pkr. 8860' H4 1/2" 'X' Nipple, ID = 3.813" 8870' H4 1/2" 'X' Nipple, ID = 3.813" 8880' H4 1/2" WLEG 11 7" X 4 1/2" ZXP liner top packer, II 9100' 'HMC' Inr hngr w / TBS 9160' 1-14 1/2" 'XN' Nipple, ID = 3.725" 1 9275' H Top of whipstock 1/ 00000000 00000000 . ../ 141/2",12.6#, L-80, Liner IBT-~-i 11880' 1 TO H 9,800' 1 COMMENTS DATE 08/06/02 03/06/03 REV BY DEW PGS COMMENTS Recreate in Canvas 7 Proposed cornpl.No Straddle PRUDHOE BA Y UNIT WELL: OS 02-14A ÆRMIT No: API No: 50-029-20446-01 Sec. 35, T11N,R14E BP Exploration (Alaska) SURVEY PROGRAM P1an: 2-14A wp05 (02-14/Plan 2~14A) Deplh I'm Deplh To Survey/Plan Tool Created By: Ken Allen Date: 10/3012002 9275.00 11880.07 Planned: 2-14A wp05 V9 MWD Checked: Date Reviewed: Date:_ WELL DETAILS Name +N/-S +E/-W Northing Easling Ullitude Longitude Slot 02·141833.87 -0.74 5950633.54 687592.00 70"16'11.884N 148"28'58.081W N/A TARGET DETAILS Name lVD ~Nf-S +EI~W Northing Easting Shape 2·14A 1"3a 8990.20 -603.70 -1286.52 5949998.00 686321.00 Point 2-14AT4a 8994.20 -843.72 -687.28 5949773.00 686926.00 Point 2-14A Poly 9015.20 -168.88 -2597.17 5950400.00 685000.00 Polygon 2·14ATla 9015.20 -438.17 -2388.81 5950136.00 685215.00 Point 2-14A 9015.20 -532.53 -1492.83 59500(J4.00 686113.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Targel 1 9275.00 1.72 278.55 8580.69 -866.07 -2221.58 0.00 0.00 2074.55 2 9295.00 4.11 281.47 8600.67 -865.88 -2222.58 12.00 5.00 2075.04 3 9325.00 8.91 284.17 8630.47 -865.10 -2225.89 /16.00 5.00 2076.52 4 9551.64 55.59 292.76 8816.94 -822.22 -2335.26 20.65 9.74 2112.35 . 5 9556.10 55.59 292.76 8819.46 -820.79 -2338.66 0.00 0.00 2113.39 6 10052.35 89.92 38.00 9015.20 -438.17 -2388.81 20.65 98.82 1848.40 2-14A Tla 7 10402.79 89.92 108.09 9015.77 -342.22 -2074.12 20.00 90.06 1575.27 8 10960.75 89.92 108.09 9016.57 -515.44 -1543.73 0.00 0.00 1374.60 9 11014.47 93.00 109.03 9015.20 -532.53 -1492.83 6.00 17.00 1355.70 2-14A T2a 10 11092.99 97.71 109.Q3 9007.87 -558.02 -1418.94 6.00 0.03 1328.79 II 11179.96 97.71 109.03 8996.20 -586.12 -1337.47 0.00 0.00 1299.13 12 11234.19 95.00 109.04 8990.20 -603.70 -1286.52 5.00 179.84 1280.58 2-14A na 13 11408.63 88.81 112.26 8984.40 -665.16 -1123.48 4.00 152.44 1225.27 14 11880.07 88.81 112.26 8994.20 -843.72 687.28 0.00 0.00 1088.22 2-14A T4a Size 4.500 TZ3 BCGLlTZ2C TZ2B/23 SB TZ2N21 TS TZIB TZIA/13N shale Top 13P REFERENCE INFORMA nON Well Centre: 02-14, True North 2-14A@59.20ASL59.20 Slot- (O.OON,OJXlE) 2-14A@59.20ASL 59.20 Minimum Curvature CASING DETAILS FORMATION TOP DETAILS Formation Name 1/2' MDPath 9370.03 9444.69 9550.34 9709.84 9828.00 9906.11 9940.63 4 880.06 MD TVDPath 8674.20 8741.20 8816.20 8907.20 8965.20 8993.20 9002.20 Co-ordinate (N/E) Reference: Vertical (TVD) Refcnmcc: Section (VS) Reference: Measured Depth Reference: Calculation Method: 8994.20 TVD No. I 2 3 4 5 6 7 No. COMPANY DETAILS 8P Amoco Minimum Curvature ISCWSA T rav Cylinder North EJliptical+Casing Rules8ased '/~ .,. '""....;11'" -' ", 'Itò /' CalculatiooMetbod: Error System: Scan Method: ElTOrSurface: Warnin~Method: l ;' I , I I -I ;1 ; l l~# ;" 8400- 8550 e I)" 121100' 9275' MD, 8580.69'TVD "" 16/100' . 9295' MD, 8600.67'TVD 9325' MD, 8630.47'TVD Dir : 9551.64' MD, 8816.94' TVD >:." Dir 20.65/100' : 9556.1' MD. 88 I 9.46'TVD " I 2250 20.65/100' ,02-14) 00 I> ..¡:::, , ¡ ~ .... ).~. ; '¡" :.-{ -. / ;w ç. , " 1 Ii 'I. I. , 950 800 50ft/in] [I 1650 Vertical Section at 219.17 500 350 200 1 050 900 d ~ 8700 -5 Q. Ö ] '€ " > 2 f-< 9000 8850 (02-l41PIan 2-l4A) Date: 10/30/2002 Date Dale:_ Plan; 2-14A wpO Created By: Ken Allen Checked: Tool MWD SURVEY PROGRAM Depth Fm Depth To Survey/Plan 9: ]880,07 Planned: 2·]4A '''1'05 V9 REFERENCE INFORMATION Well Centre: 02-14, True North 2-14A@59.20ASL59.2U Slot - (O.OON,O.OOE) 2-14A@59.20ASL 59.: Minimum Curvature Co-ordinate (N/E) Reference: Vertical (TVD) Refermce: Section (VS) Reference: Measured Depth Reference: Cakulation Method: COMPANY DETAILS BP Amoco Minimum Curvature ISCWSA Trav Cylinder North Elliptical + Casing Rules Based Calculation Method: Error System: Scan Method: ErrorSurtåce: Wamin¡¡; Method: Name +N/-S +E/-W Norl Easting Latitude Longitude Slol 02-141833.87 -0.74 5950633.. 687592.00 70°l6'11,884N 148Q28'58.081W NIA TARGET DETAILS N,= lVD +N/-S +EJ-W Northing Easting Shape 2-14A TJa 8990.20 -603.70 -1286.52 5949998.00 6&6321.00 Point 2-14A 1'4a 8994.20 -843,72 -.687.28 5949773.00 ¡86926.00 Point 2.14APo]y 90]5.20 -168.88 -2597.17 5950400.00 ,85000,00 Polygon 2-]4A Tla 9015.20 -438.17 -2388.81 5950136.00 ,85215.00 Point 2·]4A 90]5.20 -532.53 -1492.83 5950064.00 ,86113.00 Poiut SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSee Target I 9275.00 1.72 278.55 8580.69 -866.07 -2221.58 0.00 0.00 2074.55 2 9295.00 4.11 281.47 8600.67 -865.88 -2222.58 12.00 5.00 2075.04 3 9325.00 8.91 284.17 8630.4 7 -865.10 -2225.89 16.00 5.00 2076.52 4 9551.64 55.59 292.76 8816.94 -822.22 -2335.26 20.65 9.74 2112.35 5 9556.10 55.59 292.76 8819.46 -820.79 -2338.66 0.00 0.00 2113.39 6 10052.35 89.92 38.00 9015.20 -438.17 -2388.81 20.65 98.82 1848.40 2-14A 1Ia 7 10402.79 89.92 108.09 9015.77 -342.22 -2074.12 20.00 90.06 1575.27 8 10960.75 89.92 108.09 9016.57 -515.44 -1543.73 0.00 0.00 1374.60 9 11014.47 93.00 109.03 9015.20 -532.53 -1492.83 6.00 17.00 1355.70 2-14A T:a 10 11092.99 97.71 109.03 9007.87 -558.02 -1418.94 6.00 0.03 1328.79 II 11179.96 97.71 109.03 8996.20 -586.12 -1337.47 0.00 0.00 1299_13 12 11234.19 95.00 109.04 8990.20 -603.70 -1286.52 5.00 79.84 1280.58 2-14A 1:'a 13 11408.63 88.81 112.26 8984.40 -665.16 - ¡ 123.48 4.00 52.44 1225.27 14 11880.07 88.81 112.26 8994.20 -843.72 -687.28 0.00 0.00 1088.22 2-14A T4a CASING DETAILS No. TVD MD Name Size 8994.20 1880.06 41/2' 4.500 .... .... ,. \. FORMATION TOP DETAILS l ;I I I I I ,;P ,I ¡P l l All TVD depths are ssTVD plus 59.2'for RKBE. Formation TZ3 BCGUrZ2C TZ2B123SB TZ2N21 TS TZIB TZINI3N shale Top 13P t MD, 8994.2' TVD I -300 MDPath 9370.03 9444.69 9550.34 9709.84 9828.00 9906.1 I 9940.63 880.07' \1IJ_ ,. I) , \1IJ ,,;,~ -' I VD ~otal Depth />~...... / ...........,.................. .;¡ ~ 14\ wp05 --"ì I ~ / / I I I ~/ -600 TVDPath 8674.20 8741.20 8816.20 8907.20 8965.20 8993.20 9002.20 I i 2 -1..\ (..:., ~ , 1 No. I 2 3 4 5 6 7 , MD, 0960.75' ) t:-~n::!.7~J' \iD. ,){). ~"] l' I\' _._.__.._~- ; .ì:-' \1D. ~'I \. t- ---___. ---- _. ! ~..._..._..._.....__. West(-)!East(+) [300ft/in] 00' ), :-'1 , - 00' . >,1:\ "h. I' \11), k~i·J-I.( ~I(';\1IJ'i<~I('.'J4'1\'1) ! '. . - . - . - . : I ~ ì S:;l;"1 þi;:··ïfïiui···:j·i'~: \i ¡)~ ·k~fõ(;~7i\":ì S:a:1 D!r 1(. lUll' :J2:J5 \11>. 'I((I(jI~{.7"1 \ ) :-;1.111 Dlli20 (,~ ()()" 'J3¿:-· \11>. g(~ J0..-rr I V - . · , - - - - - - ~- . - - · - - - - - - - - - ! i · - - - - - - - - - - - · . - - - - - , · , - - - - · - · - i ¡ u... t.... ~ . .......... - . - - · i · - · . · , ~ ~ · - · . - , · . , - i , , I -210' -IXl , 20(.:' /'.~', ); . ), ), I SI I ,I i / }.-- .¡ ''11; i I I ~ _~ii4(.(j2 ¡ I -?~IIO , I)(} -2700 E ~ o Ë +' 15 8 ~ 15 :; o VJ . BP KW A Planning Report MAP -~-_.__..-.'......._--_.._. ..' .'.'-...'--------------..------.... Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 02 02-14 Plan 2-14A Date: 10/30/2002 Time: 09:37:42 Page: Co-ordinate(NE) Reference: Well: 02-14, True North Vertical (TVD) Reference: 2-14A @ 59.20 ASL59.2 Section (VS) Reference: Well (0.00N,0.00E,219.17Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: . _.__..N'~' '~'" . ... .....___.____ Alaska, Zone 4 Well Centre BGGM2002 Site: PB DS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northing: 5948800.37 ft Latitude: 70 15 53.847 N From: Map Easting: 687638.44 ft Longitude: 148 28 58.060 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: 02-14 Slot Name: 02-14 Well Position: +N/-S 1833.87 ft Northing: 5950633.54 ft Latitude: 70 16 11.884 N +E/-W -0.74 ft Easting : 687592.00 ft Longitude: 148 28 58.081 W Position Uncertainty: 0.00 ft Wellpath: Plan 2-14A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 2-14A @ 59.20 ASL 8/1/2002 57541 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 59.20 ft Plan: 2-14A wp05 Date Composed: Version: Tied-to: Principal: Yes Casing Points MD TVD Diameter Hole Size Name ft ft in in 11880.06 8994.20 4.500 6.125 41/2" Formations MD TV ) Formations Lithology ft ft -_.....------- 0.00 CM1 0.00 THRZ 0.00 TKLB 0.00 TPTR 0.00 TJB 0.00 TJA 0.00 TSag 0.00 TShu 0.00 TSad 9370.03 8674.20 TZ3 9444.69 8741.20 BCGL/TZ2C 9550.34 8816.20 TZ2B/23SB 9709.84 8907.20 TZ2A/21TS 9828.00 8965.20 TZ1B 9906.11 8993.20 TZ1A/13N shale 9940.63 9002.20 Top 13P 02-14 9275.00 ft Mean Sea Level 26.24 deg 80.82 deg Direction deg 219.17 10/1/2002 9 From: Definitive Path I>ip Angle ... deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 _....··____w._____·_........__.. Dip Oirection. deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Company: Field: Site: Well: Wellpath: Targets Name 2-14A T3a 2-14A T4a 2-14A Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 2-14A T1a 2-14A T2a BP Amoco Prudhoe Bay PB DS 02 02-14 Plan 2-14A __u.'_._._......__.'. __~__"'_.._..m_.... ". . BP KW A Planning Report MAP . Date: 10/30/2002 Time: 09:37:42 Page: 2 Co-ordinate(NE) Reference: Well: 02-14, True North Vertical (TVD) Reference: 2-14A @ 59.20 ASL 59.2 Section (VS) Reference: Well (0.00N,0.00E,219.17Azi) Survey Calculation Method: Minimum Curvature Db: Oracle .....--- ._._~_... ...nn ------..---- Description TVD Dip. l>ir. ft 8990.20 Map Map <-- Latitude --> <- Longitude ---> +"I/-S +E/-W Northing Easting Deg Min Scc Deg Min Sec ft ft ft ft .................. ..... ..--.-..-......-...¥¥....- ........-..-........--...- -603.70 -1286.52 5949998.00 686321.00 70 16 5.945 N 148 29 35.530 W Plan Section Information \<1/) ft 9275.00 9295.00 9325.00 9551.64 9556.10 10052.35 10402.79 10960.75 11014.47 11092.99 11179.96 11234.19 11408.63 11880.07 Snrvey MD ft 9275.00 9295.00 9300.00 9325.00 9350.00 9370.03 9375.00 9400.00 9425.00 9444.69 9450.00 9475.00 9500.00 9525.00 9550.34 9551.64 9556.10 9575.00 9600.00 9625.00 Incl deg 1.72 4.11 8.91 55.59 55.59 89.92 89.92 89.92 93.00 97.71 97.71 95.00 88.81 88.81 Incl deg 1.72 4.11 4.91 8.91 14.02 18.14 19.16 24.31 29.46 33.52 34.62 39.78 44.94 50.10 55.33 55.59 55.59 55.09 54.70 54.63 Azim deg 278.55 281.47 284.17 292.76 292.76 38.00 108.09 108.09 109.03 109.03 109.03 109.04 112.26 112.26 Azim deg 278.55 281.47 282.28 284.17 287.77 289.21 289.47 290.47 291.13 291.53 291.62 291.99 292.29 292.54 292.75 292.76 292.76 297.47 303.76 310.09 TVD ft 8580.69 8600.67 8630.47 8816.94 8819.46 9015.20 9015.77 9016.57 9015.20 9007.87 8996.20 8990.20 8984.40 8994.20 TVD ft 8580.69 8600.67 8605.65 8630.47 8654.96 8674.20 8678.91 8702.13 8724.42 8741.20 8745.60 8765.51 8783.97 8800.85 8816.20 8816.94 8819.46 8830.21 8844.60 8859.07 8994.20 9015.20 9015.20 9015.20 9015.20 9015.20 9015.20 9015.20 9015.20 -843.72 -687.28 5949773.00 686926.00 5950400.00 685000.00 5950400.00 685000.00 5950249.99 685756.00 5950138.99 686186.00 5949778.00 687190.00 5949378.99 687067.00 5949600.00 685000.00 70 16 3.585 N 148 29 18.086 W 70 16 10.218 N 70 16 10.218 N 70 16 8.560 N 70 16 7.364 N 70 16 3.570 N 70 15 59.677 N 70 16 2.352 N 148 30 13.685 W 148 30 13.685 W 148 2951.791 W 148 29 39.357 W 148 29 10.400 W 148 29 14.268 W 148 30 14.257 W -438.17 -2388.81 5950136.00 685215.00 70 16 7.570 N 148 30 7.617 W -168.88 -168.88 -337.69 -459.38 -845.31 -1241.15 -968.68 -2597.17 -2597.17 -1845.10 -1417.97 -423.22 -556.14 -2617.11 -532.53 -1492.83 5950064.00 686113.00 70 16 6.645 N 148 2941.535 W 9015.20 +;'\1/-8 ft -866.07 -865.88 -865.10 -822.22 -820.79 -438.17 -342.22 -515.44 -532.53 -558.02 -586.12 -603.70 -665.16 -843.72 Sys TVD ft 8521.49 8541.47 8546.45 8571.27 8595.76 8615.00 8619.71 8642.93 8665.22 8682.00 8686.40 8706.31 8724.77 8741.65 8757.00 8757.74 8760.26 8771.01 8785.40 8799.87 +E/-W ft -2221.58 -2222.58 -2225.89 -2335.26 -2338.66 -2388.81 -2074.12 -1543.73 -1492.83 -1418.94 -1337.47 -1286.52 -1123.48 -687.28 MapN ft 5949712.42 5949712.59 5949712.66 5949713.29 5949714.57 5949716.20 5949716.69 5949719.64 5949723.39 5949726.90 5949727.92 5949733.18 5949739.14 5949745.74 5949753.04 5949753.43 5949754.77 5949761.01 5949770.97 5949782.80 ...... ...............,.............-....-.. DLS Build Turn deg/100ft deg/100ft deg/10Oft 0.00 12.00 16.00 20.65 0.00 20.65 20.00 0.00 6.00 6.00 0.00 5.00 4.00 0.00 -- 0.00 11.98 15.97 20.60 0.00 6.92 0.00 0.00 5.74 6.00 0.00 -5.00 -3.55 0.00 MapE ft 685392.83 685391.82 685391.43 685388.50 685383.70 VS ft 2074.55 2075.04 2075.22 2076.52 2078.45 685378.40 685376.89 685368.12 685357.46 685347.79 2080.40 2080.94 2083.97 2087.53 2090.67 685345.00 685330.83 685315.09 685297.88 685279.09 2091.57 2096.08 2101.01 2106.32 2112.05 685278.10 685274.67 685260.44 685242.60 685226.01 2112.35 2113.39 2117.16 2120.20 2121.00 0.00 14.58 9.00 3.79 0.00 21.21 20.00 0.00 1.76 0.00 0.00 0.01 1.85 0.00 TFO deg 0.00 5.00 5.00 9.74 0.00 98.82 90.06 0.00 17.00 0.03 0.00 179.84 152.44 0.00 DLS TFO deg/10OO deg 0.00 0.00 12.00 5.00 16.00 5.00 16.00 4.19 20.65 9.74 20.65 20.65 20.65 20.65 20.65 20.65 20.65 20.65 20.65 20.65 20.65 0.00 20.65 20.65 20.65 1.82 0.00 98.82 96.14 92.52 Target 2-14A T1a 2-14A T2a 2-14A T3a 2-14A T4a Tool/Comment MWD MWD MWD MWD MWD 6.21 4.83 4.58 3.65 3.05 2.72 2.64 2.35 2.12 1.96 TZ3 MWD MWD MWD BCGL/TZ2C MWD MWD MWD MWD TZ2B/23SB MWD MWD MWD MWD MWD . BP . KW A Planning Report MAP -~~_...- ~-~.~.._._.~ ,.-----..----- Company: BP Amoco Date: 10/30/2002 Time: 09:37:42 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) ·Reference: Well: 02-14, True North Site: PB DS 02 Vertical (TVD) Reference: 2-14A @ 59.20ASL 59.2 Well: 02-14 Section (VS) Reference: Well (0.00N,O.00E,2t9.17Azi) Wellpath: Plan 2-14A Survey Calculation Method: Minimum Curvature Db: Oracle Survey .~.... - ....-....--...- . ....-..-.......--.----..-.- Tool/Comment !VID Incl Azim TVD Sys TVD MapN MapE VS DLS TFO ft deg deg ft ft ft ft ft deg/100ft deg .._.n_.__..._._.".__ _w..____·._·····___·_._.___._______._ 9650.00 54.90 316.40 8873.50 8814.30 5949796.40 685210.81 2119.55 20.65 88.85 MWD 9675.00 55.49 322.65 8887.78 8828.58 5949811.67 685197.11 2115.85 20.65 85.21 MWD 9700.00 56.40 328.79 8901.79 8842.59 5949828.48 685185.04 2109.95 20.65 81.64 MWD 9709.84 56.84 331.16 8907.20 8848.00 5949835.49 685180.75 2107.03 20.65 78.20 TZ2A/21TS 9725.00 57.60 334.77 8915.41 8856.21 5949846.69 685174.68 2101.89 20.65 76.90 MWD 9750.00 59.07 340.59 8928.54 8869.34 5949866.16 685166.13 2091.73 20.65 74.94 MWD 9775.00 60.80 346.21 8941.07 8881.87 5949886.72 685159.45 2079.56 20.65 71.89 MWD 9800.00 62.75 351.64 8952.90 8893.70 5949908.21 685154.69 2065.47 20.65 69.07 MWD 9825.00 64.91 356.86 8963.93 8904.73 5949930.46 685151.90 2049.58 20.65 66.50 MWD 9828.00 65.18 357.48 8965.20 8906.00 5949933.18 685151.69 2047.56 20.65 64.19 TZ1B 9850.00 67.24 1.90 8974.08 8914.88 5949953.29 685151.09 2032.02 20.65 63.93 MWD 9875.00 69.72 6.77 8983.25 8924.05 5949976.50 685152.28 2012.94 20.65 62.15 MWD 9900.00 72.34 11.48 8991.38 8932.18 5949999.92 685155.45 1992.48 20.65 60.36 MWD 9906.11 72.99 12.60 8993.20 8934.00 5950005.65 685156.52 1987.29 20.65 58.83 TZ1A/13N shale 9925.00 75.06 16.05 8998.40 8939.20 5950023.35 685160.58 1970.81 20.65 58.49 MWD 9940.63 76.81 18.84 9002.20 8943.00 5950037.92 685164.76 1956.72 20.65 57.55 Top 13P 9950.00 77.87 20.50 9004.25 8945.05 5950046.60 685167.62 1948.11 20.65 56.87 MWD 9975.00 80.75 24.86 9008.89 8949.69 5950069.48 685176.53 1924.56 20.65 56.50 MWD 10000.00 83.69 29.15 9012.28 8953.08 5950091.82 685187.22 1900.35 20.65 55.69 MWD 10025.00 86.65 33.39 9014.38 8955.18 5950113.41 685199.61 1875.68 20.65 55.11 MWD 10052.35 89.92 38.00 9015.20 8956.00 5950136.00 685215.00 1848.40 20.65 54.76 2-14A T1a 10075.00 89.92 42.53 9015.23 8956.03 5950153.63 685229.20 1825.77 20.00 90.06 MWD 10100.00 89.91 47.53 9015.27 8956.07 5950171.73 685246.43 1800.91 20.00 90.05 MWD 10125.00 89.91 52.53 9015.31 8956.11 5950188.26 685265.18 1776.36 20.00 90.04 MWD 10150.00 89.91 57.53 9015.35 8956.15 5950203.09 685285.29 1752.32 20.00 90.04 MWD 10175.00 89.90 62.53 9015.39 8956.19 5950216.11 685306.62 1728.97 20.00 90.03 MWD 10200.00 89.90 67.53 9015.44 8956.24 5950227.22 685329.01 1706.48 20.00 90.02 MWD 10225.00 89.90 72.53 9015.48 8956.28 5950236.33 685352.28 1685.03 20.00 90.01 MWD 10250.00 89.90 77.53 9015.52 8956.32 5950243.39 685376.25 1664.77 20.00 90.00 MWD 10275.00 89.90 82.53 9015.56 8956.36 5950248.33 685400.75 1645.87 20.00 89.99 MWD 10300.00 89.90 87.53 9015.61 8956.41 5950251.11 685425.58 1628.47 20.00 89.99 MWD 10325.00 89.91 92.53 9015.65 8956.45 5950251.72 685450.57 1612.69 20.00 89.98 MWD 10350.00 89.91 97.53 9015.69 8956.49 5950250.15 685475.51 1598.67 20.00 89.97 MWD 10375.00 89.91 102.53 9015.73 8956.53 5950246.42 685500.22 1586.50 20.00 89.96 MWD 10400.00 89.92 107.53 9015.76 8956.56 5950240.54 685524.51 1576.28 20.00 89.95 MWD 10402.79 89.92 108.09 9015.77 8956.57 5950239.75 685527.18 1575.27 20.00 89.95 MWD 10500.00 89.92 108.09 9015.91 8956.71 5950211.89 685620.31 1540.31 0.00 0.00 MWD 10600.00 89.92 108.09 9016.05 8956.85 5950183.22 685716.10 1504.34 0.00 0.00 MWD 10700.00 89.92 108.09 9016.19 8956.99 5950154.56 685811.90 1468.38 0.00 0.00 MWD 10800.00 89.92 108.09 9016.34 8957.14 5950125.89 685907.70 1432.41 0.00 0.00 MWD 10900.00 89.92 108.09 9016.48 8957.28 5950097.23 686003.50 1396.45 0.00 0.00 MWD 10960.75 89.92 108.09 9016.57 8957.37 5950079.81 686061.69 1374.60 0.00 0.00 MWD 11000.00 92.17 108.78 9015.85 8956.65 5950068.34 686099.22 1360.70 6.00 17.00 MWD 11014.47 93.00 109.03 9015.20 8956.00 5950064.00 686113.00 1355.70 6.00 17.01 2-14A T2a 11050.00 95.13 109.03 9012.68 8953.48 5950053.28 686146.78 1343.50 6.00 0.03 MWD 11092.99 97.71 109.03 9007.87 8948.67 5950040.36 686187.50 1328.79 6.00 0.03 MWD 11100.00 97.71 109.03 9006.93 8947.73 5950038.26 686194.12 1326.40 0.00 0.00 MWD 11179.96 97.71 109.03 8996.20 8937.00 5950014.30 686269.64 1299.13 0.00 0.00 MWD 11200.00 96.71 109.04 8993.69 8934.49 5950008.29 686288.59 1292.29 5.00 179.84 MWD 11234.19 95.00 109.04 8990.20 8931.00 5949998.00 686321.00 1280.58 5.00 179.84 2-14A T3a 11300.00 92.67 110.26 8985.80 8926.60 5949977.47 686383.36 1258.65 4.00 152.44 MWD 11408.63 88.81 112.26 8984.40 8925.20 5949940.63 686485.51 1225.27 4.00 152.53 MWD Company: Field: Site: Well: Wellpath: Survey MI> ft 11500.00 11600.00 11700.00 11800.00 11880.07 BP Amoco Prudhoe Bay PB DS 02 02-14 Plan 2-14A Inel deg 88.81 88.81 88.81 Azim deg 112.26 112.26 112.26 88.81 88.81 112.26 112.26 . BP KW A Planning Report MAP . _.._--_.-.--'".~--_._- ~ "---. Date: 10/30/2002 Time: 09:37:42 Page: 4 Co-ordjnate(N~;) Reference: Well: 02-14, True North Vertical (TVD) Reference: 2-14A@ 59.20 ASL 59.2 Section (VS) Reference: Well (0.00N,0.00E,219.17Azi) Survey Calculation Method: Minimum Curvature Dh: Oracle "'n._.______ TVD Sys TVD MapN Map <: VS DLS TFO Tool/Comment ft ft ft ft ft deg/10OO deg ··.··.····,··_·vv·v -------"----. 8986.30 8927.10 5949908.14 686570.88 1198.70 0.00 0.00 MWD 8988.38 8929.18 5949872.58 686664.32 1169.64 0.00 0.00 MWD 8990.46 8931.26 5949837.03 686757.75 1140.57 0.00 0.00 MWD 8992.54 8933.34 5949801.47 686851.19 1111.50 0.00 0.00 MWD 8994.20 8935.00 5949773.00 686926.00 1088.22 0.00 0.00 2-14A T4a p055089 DATE 6/9/2003 I I CHECK NO. 055089 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 6/9/2003 INV# CK0604031 PERMIT TO DRILL FEE JUL 1 "1 2003 () (it 01..-1~--A THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK995.19-6612 PAY: TO THE ORDER OF: NATIONAL CITY BANK Ashland, Ohio No. p 055089 56-389 412 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT *****t~$iQo. 00*******1 1110 5 508 Ii III I: 0... ~ 2 0 ~ 8 Ii 5 i ~ 0 ~ 2 78 Ii b III H . . . . TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing weD ~ Permit No, API No. Production should continue to be reported as a function· of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals through target zones. _I Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT 02-14A Program DEV Well bore seg D _, '" . ~¡t;J' ·m«i'<i! ~ PTD#: 2031250 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial Class/Type DEV / 1-01L _ GeoArea W!L Unit 11650 On/Off Shore ~ Annular Disposal D Administration Permit fee attached . Yes. - - - - ~ 2 .Leasenumberappropri¡¡te . - - - - Yes. 3 .UÐtque weltn.ame .aDd lJuJl1b.er . . . . . . . . . . . . . . . . . . . . . . Yes. - - - - - - - - - - - - - - - - - ~ - - - - - - - - - 4 WelUoc¡¡ted ina defineøpool - - - - - - - Yes. - - - - 5 We.IUocated proper distance from driJling unitb.oundary . . . . . . . Yes. - - - - 6 WeJUoc¡¡ted proPer .dtstance. from otheJ wells . . . . . . Yes 7 S.utficient ¡¡creageayail¡¡ble in dJilJilJg unit. Yes. - - - - - - - - - - - 8 Jfdeviated, js. weJlbore platincJuded . . . . . . Yes. - - - - - - - - - - - - 9 Operator on.ly affected party. - - - - - - · Yes. . . - - - - - - 10 .Operator bas. appropriate. b.ond tnJorce. . . . . . . . . . . . . . . . . . · yes............ - - - - - - - - - - - - - 11 Permit caD be issu.ep without conservation order. . . . . . Yes.. . Appr Date 112 Permit caD be tssu.ep without admini$trativ:e.appr9vaJ . Yes. - - - - - - - - - - - - - - RPC 7/14/2003 113 Can permit be approved before 15-day wait Yes . 114 We.ll Jocated wtthin area and.strata .authorized by InjectiolJ Order # (put 10# in comments) (For. NA - - - - - 15 AJI wells.within Jl4.mite.are.a.of review jdelJtified (For $.ervice well Ollly). . . . . . . . . . . . . . . NA . - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - 16 Pre.-produçed injector; øur¡¡tionof pre-.proøuGtiolJ tess than 3 mOl1ths. (For.servtce well onJy) . NA 17 ACMP F"illding of Con.si.$tency.has beeni$.sued for.tbis project NA - Engineering 18 .C.ODQu.ctor $ttillgpJovided . - - - - - - - - - - NA 19 .S.urface.ca$.il1gpJotect$. alfknown USQW$ . - - - - - NA... 20 .CMT v.ol adequ.ate.to circ.utate.oÐconductor 8. SUJfc.$g . . . . NA 21 CMT vol adequate to tie-tnJongstring to.surf csg . . NA - - - - - - - - - - - 22 .CMTwill coyeraJlklJoWÐ.Pro.ductiye borizons . - - - - - - - - Yes... . 23 .C.asing designs ad.eQuate. for CoT, B& permafrost . . . . · Yes - - - - - - - - - - - - - - - - 24 AØequ¡¡te.t¡¡n.kage.oJ re.seTYe pit. - - - - - Yes. Nabors.2.ES. . 25 JfaJe-ørilL bas a 10A0;3 for ¡¡banponment beeo ¡¡PPJoved . Yes. * - - - - - - - - - - - - - 26 Aøequ¡¡te .Y@!I/:1ore.. separ¡¡tjo.n .Pfopo$eø. . . . . . . . . . . . . . . . . . . . . . . . . . . . yes......................... . 27 Jfdiveåer Je.qjJire.d, does it meet regulations. . . - - - - - - - - - - - - - - NA - - - - - - Appr Date 28 .DJiUiog fluid prograllJ sc;hematic& eq.uipJistadequ¡¡te - - - - - - Yes. . . . . . Max MW.8,5 ppg. WGA 7/15/2003 29 .B.OPEs, d.o .they meet regula.tion . Yes. . 130 .BOPEpre..ss raliog appropriate; test to (put pSig in.comments) Yes. . . . . . Test to 3500. psi. .MSF> 24.50 psi 31 C.hokemanifold cOllJplies w/API RF>-53. (May 64). - - - - - - Yes. 32 Work will occur withoutoperationsbutdown . . . . . . . . - - - - - Yes. [33 .1& pre&ence Qf H2S gªs. prob.able . - - - - - No 34 Meçha.nic¡¡l.cood.it[on of we.lIs wtthil1 AOR. verified (For servjce WelJ only) . NA Geology 135 Permit c;aD be issu.ep w/o hYProgen s.ulfide meas.ures. No I - - - - - - - - - - - - 136 .D.ata.PJeseoted on. pote.ntial oveJpre$.sure .zone.$. - - - - NA... . Appr Date 37 .S.eismlc.analysjs of shallow gas.zooes NA - - - - RPC 7/14/2003 138 Seabep .conditioo survey (if off-shore) . . NA 139 - - - - - I Contact name/phone.forweekly progressreport$ [exploratory only] . . . . . . . . NA Geologic Date: Engineering Date Public #? .~...--/.. '. Commissioner: Commissioner Commission .. ate (J ~ 9r.5 7//~/3 ~. é'3 e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . (7C3 ~ 1f9!3 ) ?-- ?.ù '-\ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Oct 03 08:32:32 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name.......UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2-14A 500292044601 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 03-0CT-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002631997 T. GALVIN R. BORDES / MWD RUN 2 MW0002631997 T. GALVIN R. BORDES / MWD RUN 3 MW0002631997 J. BOBBITT L. VAUGHN/ D # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 UN 14E 4713 851 .00 57.93 32.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 9260.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. A WHIPSTOCK WAS POSITIONED AND A WINDOW MILLED PRIOR ~~~,\\~ . . TO MWD RUN 1. THE TOP OF THE WHIPSTOCK WAS AT 9248'MD, AND THE BOTTOM WAS AT 9260'MD. 4. MWD RUNS 1 AND 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED THERMAL NEUTRON POROSITY (CTN); AND STABILIZED LITHO- DENSITY (SLD). 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH DGR AND EWR4. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 13' SHALLOWER PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 9/12/03. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL 2-14A WITH API#: 50-029-20446-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11880'MD/8995'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.4 - 8.5 PPG MUD SALINITY: 3300 - 3600 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............. STSLIB. 001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/10/03 Maximum Physical Record..65535 File Type... ........ .....LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 .. FILE SUMMARY PBU TOOL CODE GR FCNT NPHI NCNT PEF FET RPX RPS RPM RPD DRHO RHOB ROP $ . START DEPTH 9155.0 9173.5 9174.5 9174.5 9188.0 9222.5 9222.5 9222.5 9222.5 9222.5 9244.0 9244.0 9261.5 . STOP DEPTH 11814.0 10270.5 10270.5 10270.5 10285.0 11821.5 11821.5 11821.5 11821.5 11821.5 10285.0 10285.0 11867.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9155.0 11867.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 9168.0 11880.0 BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 9168.0 9661.5 10371.5 MERGE BASE 9661.5 10371. 5 11880.0 # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point............. . Undefined Frame Spacing. . . . . . . . . . . . . . . . . . . . . 60 .lIN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9155 11867 10511 5425 9155 11867 ROP MWD FT/H 0.37 300.1 84.3271 5212 9261.5 11867 GR MWD API 12.56 199.72 51.4088 5319 9155 11814 RPX MWD OHMM 1.28 1836.06 20.1181 5199 9222.5 11821.5 RPS MWD OHMM 0.83 1973.04 24.4345 5199 9222.5 11821.5 RPM MWD OHMM 0.06 1906.65 28.7964 5199 9222.5 11821.5 RPD MWD OHMM 0.11 2000 40.7045 5199 9222.5 11821. 5 FET MWD HOUR 0.22 21.17 2.13353 5199 9222.5 11821. 5 NPHI MWD PU-S 10.29 53.06 23.4866 2193 9174.5 10270.5 FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD CNTS CNTS G/CM G/CM BARN . 144.6 16261.8 1.975 -0.323 1. 43 1820.9 43718.8 3.402 0.937 19.17 697.25 30299.8 2.3377 0.0412688 2.98386 2195 2193 2083 2083 2195 First Reading For Entire File..........9155 Last Reading For Entire File...........11867 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .03/10/03 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/03 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FCNT NCNT NPHI PEF RPX RPS RPM RPD FET DRHO RHOB ROP $ 2 . 9173.5 9174.5 9244 9244 9188 10270.5 10270.5 10285 10285 10285 header data for each bit run in separate files. 1 .5000 START DEPTH 9168.0 9186.5 9187.5 9187.5 9201. 0 9235.5 9235.5 9235.5 9235.5 9235.5 9257.0 9257.0 9274.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD STOP DEPTH 9609.5 9573.5 9573.5 9573.5 9588.0 9616.5 9616.5 9616.5 9616.5 9616.5 9588.0 9588.0 9661.5 01-SEP-03 Insite 66.37 Memory 9661. 0 9274.0 9661. 0 1.9 55.9 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN TOOL NUMBER 62456 110059 . CTN EWR4 $ COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ............... . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O . 100547 73634 6.125 9260.0 FLO-PRO 8.50 48.0 9.6 3300 8.2 1. 200 .740 .980 .950 70.0 118.4 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 NPHI MWD010 PU-S 4 1 68 32 9 FCNT MWD010 CNTS 4 1 68 36 10 NCNT MWD010 CNTS 4 1 68 40 11 RHOB MWD010 G/CM 4 1 68 44 12 DRHO MWD010 G/CM 4 1 68 48 13 PEF MWD010 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9168 9661.5 9414.75 988 9168 9661.5 ROP MWD010 FT/H 0.37 82.9 27.6301 775 9274.5 9661. 5 GR MWD010 API 12.56 121. 51 28.4949 884 9168 9609.5 RPX MWD010 OHMM 1. 28 1836.06 36.4526 763 9235.5 9616.5 RPS MWD010 OHMM 0.83 1973.04 56.7693 763 9235.5 9616.5 RPM MWD010 OHMM 0.06 1906.65 78.5825 763 9235.5 9616.5 RPD MWD010 OHMM 0.11 2000 152.207 763 9235.5 9616.5 FET MWD010 HOUR 1. 37 5.65 2.85992 763 9235.5 9616.5 NPHI MWD010 PU-S 10.29 53.06 23.1415 773 9187.5 9573.5 FCNT MWD010 CNTS 144.6 1820.9 722.747 775 9186.5 9573.5 NCNT MWD010 CNTS 16261.8 43718.8 28740.5 773 9187.5 9573.5 RHOB MWD010 G/CM 1. 975 2.811 2.26954 663 9257 9588 . . DRHO MWD010 G/CM -0.323 0.289 0.0539532 663 9257 PEF MWD010 BARN 1. 43 19.17 4.14032 775 9201 9588 9588 First Reading For Entire Fi1e..........9168 Last Reading For Entire Fi1e...........9661.5 File Trailer Service name.... .........STSLIB.002 Service Sub Level Name... Version Number.... . . . . . . .1.0.0 Date of Generation.......03/10/03 Maximum Physical Record..65535 File Type..... ... ....... .LO Next File Name...........STSLIB.003 Physical EOF File Header Service name............. STSLIB. 003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/10/03 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: jf FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI RHOB DRHO PEF GR RPX RPS RPM RPD FET ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9574.0 9574.0 9574.0 9588.5 9588.5 9588.5 9610.0 9617.0 9617.0 9617.0 9617.0 9617.0 9662.0 jf LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: jf TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 ~ STOP DEPTH 10283.5 10283.5 10283.5 10298.0 10298.0 10298.0 10319.5 10326.5 10326.5 10326.5 10326.5 10326.5 10371.5 03-SEP-03 Insite 66.37 Memory 10371.0 9661. 0 10371.0 53.7 90.7 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 TOOL NUMBER 62456 110059 100547 73634 . . # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 9260.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.50 46.0 9.2 3600 7.3 1. 200 .640 .980 .950 70.0 138.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ........ ....0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .lIN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9574 10371. 5 9972.75 1596 9574 10371. 5 ROP MWD020 FT/H 1.6 209.64 36.0721 1420 9662 10371.5 GR MWD020 API 14.22 144.53 57.5232 1420 9610 10319.5 RPX MWD020 OHMM 7 37.9 15.8799 1420 9617 10326.5 RPS MWD020 OHMM 6.82 59.89 18.1032 1420 9617 10326.5 RPM MWD020 OHMM 6.87 68.05 20.7343 1420 9617 10326.5 RPD MWD020 OHMM 8.36 64.62 22.5378 1420 9617 10326.5 FET MWD020 HOUR 1. 02 21.17 3.41132 1420 9617 10326.5 NPHI MWD020 PU-S 15.59 35.25 23.6745 1420 9574 10283.5 FCNT MWD020 CNTS 323.1 1291. 2 683.334 1420 9574 10283.5 NCNT MWD020 CNTS 22282.9 41128.1 31148.6 1420 9574 10283.5 RHOB MWD020 G/CM 2.044 3.402 2.36953 1420 9588.5 10298 DRHO MWD020 G/CM -0.273 0.937 0.0353465 1420 9588.5 10298 PEF MWD020 BARN 1. 45 6.15 2.35269 1420 9588.5 10298 . . First Reading For Entire File..........9574 Last Reading For Entire File.......... .10371.5 File Trailer Service name............. STSLIB. 003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation... ....03/10/03 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/10/03 Maximum Physical Record..65535 File Type... ...... .......LO Previous File Name.......STSLIB.003 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 10320.0 10327.0 10327.0 10327.0 10327.0 10327.0 10372.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA Electromag # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): STOP DEPTH 11827.0 11834.5 11834.5 11834.5 11834.5 11834.5 11880.0 05-SEP-03 Insite 66.37 Memory 11880.0 10371.0 11880.0 89.3 96.8 RAY Resis. 4 TOOL NUMBER 62456 73634 6.125 9260.0 FLO-PRO 8.50 43.0 9.6 3150 . . FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 7.5 1. 200 .550 1.000 1. 300 68.0 155.0 68.0 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.............. ...Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 . UN Max frames per record......... ....Undefined Absent value...................... -999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10320 11880 11100 3121 10320 11880 ROP MWD030 FT/H 2.86 300.1 121. 603 3017 10372 11880 GR MWD030 API 20.31 199.72 55.2474 3015 10320 11827 RPX MWD030 OHMM 8.18 42.97 17.9812 3016 10327 11834.5 RPS MWD030 OHMM 8.32 41.97 19.2352 3016 10327 11834.5 RPM MWD030 OHMM 8.58 38.85 19.9971 3016 10327 11834.5 RPD MWD030 OHMM 9.2 38.43 21.0495 3016 10327 11834.5 FET MWD030 HOUR 0.22 17.79 1.34815 3016 10327 11834.5 First Reading For Entire File..........10320 Last Reading For Entire File...........11880 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN · . Continuation Number..... .01 Next Tape Name...........UNKNOWN Comments.......... .......STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
