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195-037
DECEIVED STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI.1 WELLOMP ETION OR RECOMPLETION REPORT AND LOG SEP 2 2 2015 ` e4 iOG V''1.! la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned Suspended 1b.W 20AAC 25.105 20AAC 25.110__/e Development p Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero 4'"• Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 8/31/2015 195-037 • 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 4/16/1995 50-029-21574-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 4/27/1995 PBU Y-21A ' Surface: 1417'FNL,240'FEL,Sec.33,T11N,R13E,UM • 9 KB(ft above MSL): 82.71' 17. Field/Pool(s): Top of Productive Interval: 122'FNL,2814'FEL,Sec.04,T1ON,R13E,UM GL(ft above MSL): 49.96' , PRUDHOE BAY,PRUDHOE OIL Total Depth: 997'FNL,5278'FEL,Sec.04,T1ON,R13E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 10997'/8979' ADL 028287&047471 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 644577 ' y- 5948834 ' Zone - ASP 4 .13500'/9029' • TPI: x- 642088 y- 5944802 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20. Thickness of Permafrost MD/TVD: Total Depth:x- 639643 y- 5943880 Zone - ASP 4 None 1900'(Approx.) 5. Directional Survey: Yes 0 (attached) No 0 13. Water Death.if Offshore: 21. Re-drill/Lateral Top Wndow MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9000'/7761' 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,LWD,GR.RES 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 40" Conductor 33' 113' 33' 113' 36" 8 cu yds Concrete 13-3/8" 72# L-80 33' 2663' 33' 2663' 17-1/2" 3720 cu ft Permafrost'E' 9-5/8" 47# L-80 31' 9000' 31' 7761' 12-1/4" 897 cu ft Class'G' 7" 29# NT8OS 8823' 11200' 7616' 9023' 8-1/2" 535 cu ft Class'G' 4-1/2" 12.6# L-80 11056' 13485' 8998' 9028' 6" Uncemented Slotted Liner 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#13Cr80/L-80 10644' 10446'/8722' R1tiliStVgt -'`'4 10597/8811' e6. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 1' Was hydraulic fracturing used during completion? Yes 0 No 0 �� Per 20 AAC 25.283(i)(2)attach electronic and printed • information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ..__. 11080' Set Cement Retainer 10997' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ....i.i. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate •'� Form 10-407 Revised 5/2015 CONTINUED'' ON PAGE 2 Submit ORIGINAL only V 7-1.- l a/V 15 A ,o/, /" RBDMS 5EP 2 t 20i4 , (,...z._-7../.0 /6 28. -i,. CORE DATA • Conventional Core(s) Yes 0 No Q • Sidewall Cores Yes ❑ No 0 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 0 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Sag River 10867' 8930' AAC 25.071. Shublik 10912' 8948' Sadlerochit 11220' 9024' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Browning,Zachary H Email: Zachary.Browning@bp.com Printed Name: Joe Lastu Title: Drilling Technologist Signature: k Phone: +1 907 564 4091 Date: 1/2215 J\ INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only i • Y-21A, Well History (Pre-Rig Sidetrack) iia 3/13/2015 CTU-6 1.75" CT. Objective: Mill XN Nipple/ Dummy WS Drift I Caliper. MIRU, BOP Test. CTU-6 1.75" CT. Objective: Mill XN /WS Drift/Caliper. BOP Test, DBIT, MU and RIH w/ Baker LH milling assembly w/3.80"string mill and 3.78" parabolic mill (OAL = 19.15', Max OD = 3.80"). Kill well with 187bbls 1%KCI w/safelube. Tag XN nipple @ 10628'. Mill thru nipple. Dry drift thru nipple, good. Continue RIH until tag at 11215'. Attempt to mill. Stall twice, decide to POOH to changeout BHA. String mill drifted 3.80", parabolic mill drifted 3.77" Make up and RIH with 3.78" Milling BHA. 3/14/2015 Tag at 11,208', mill ahead to 11,210'. CTU-6 1.75" CT. Objective: Mill XN /WS Drift/Caliper. Continue Milling obstruction at 11,208' Mill down to 11,210' CTMD, POOH to inpsect mill. Mill show severe wear across face and outer edge. Possible damaged slotted liner. Make up and RIH with 3.70" Parabolic opti-cut mill with stabilizers. Dry tag at 11218.9'. Stall 14 times. Dry tag at 11219'twice. Decide to POOH to change BHA and inspect mill. Mill shows extreme wear, mill face and sides worn completely smooth and upper end of water courses worn smooth. Perform chain inspection and cut 100'of pipe for chrome management. 3/15/2015 Decision to RDMO and further evaluate well. T/I/O = 730/1650Nac. Temp = SI. T& IA FL (APE request). ALP = 1950 psi. AL SI @ casing valve. TBG FL @ 1368' (20 bbls). IA FL @ 8566' (sta#2, Dome, 150 bbls). SV, WV= C. SSV, MV 3/20/2015 = O. IA, OA= OTG. NOVP. 1000. DRIFTED w/3.80"G-RING, 4-1/2" BLB, 2.68" CENT, UNABLE TO MAKE IT PAST 9,592' SLM. (Suspected Milling Debris). DRIFTED w/3.80"G-RING, 4-1/2" BLB, 3" S-BLR, SID IN X-NIP @ 10,473' MD. UNABLE TO SET 4-1/2"X-CATCHER IN X-NIP @ 10,409' MD. BRUSHED X-NIP @ 10,409' MD. (Difficult to get through nipple). SET 4-1/2"X-CATCHER IN X-NIP @ 10,409' MD. PULLED ST# 1 @ 10,338' MD. PULLED ST#2 @ 8,692' MD. SET RK-DGLV IN ST#2 @ 8,692' 7/10/2015 MD. PULLED ST#3 @ 7,088' MD. T/IIO 1839/570/0 ( Assist S/L with Load and test IA , & brush &flush ) Pumped 5 meth and 547 crude to load IA , MIT-IA to 2500 psi . IA lost 41 psi first 15 and 15 psi the 2nd 15 total loss of( 56 7/11/2015 psi ).Bleed down IA to 500 psi . Pumped 2 meth and 175 180*crude to brush &flush tbg. SET RK-DGLV IN ST#3 @ 7,088' MD. PULLED ST#4 @ 5,085' MD. SET RK-DGLV IN ST#4 @ 5,085' MD. PULLED ST#5 @ 3,003' MD. SET RK-DGLV IN ST#5 @ 3,003' MD. LRS LOADED IA w/547 BBLS CRUDE. SET BK-DGLV IN ST# 1 @ 10,338' MD. LRS PERFORMS 2500 PSI MIT-IA (Pass). PULLED 4-1/2"X-CATCHER @ 10,409' MD. LRS LOADED TBG w/ 180 BBLS CRUDE. 7/11/2015 DRIFTED w/4-1/2" BLB, 3.70" G-RING, UNABLE TO MAKE IT PAST 10,727' SLM. Pumped an additional 5 bbls 180*crude down TBG. Pumped an additional 20 bbls crude while Sline brushed Sline in control of well upon LRS departure. DSO notified of well status. FWHP's = 7/12/2015 90/290/0 caution tags hung and FLUID PACKED ANNULUS sign hung. DRIFTED w/2.80"G-RING, 1.75" S-BLR, UNABLE TO MAKE IT PAST 10,801' SLM. (Bailer Full of Formation Sand). RAN 5' x 3" DRIVE DOWN BAILER, S/D @ 10,796' SLM, WORK TO 10,806' 7/12/2015 SLM. RAN 10'x 2.25" PUMP BAILER, S/D @ 10,804' SLM, WORK TO 10,807' SLM. CTU#6 1.75" CT Job Scope: FCO/ P&A. MIRU CTU. MU Slim 1.75"JSN & RIH. Pump Safelube 7/19/2015 down coil while rih taking returns. CTU#6 1.75" CT Job Scope: FCO/P&A. Continue Rih w/ 1.75"JSN while pumping safelube down coil. Off pump at 10600' (above SL Tag). Dry tag fill at 11,135'. Puh above perfs at 10800'and establish if returns are sufficient for FCO. About—90% returns. Start clean out. Took several attempts to start making hole at 3bpm. Clean out from 11135'to 11185'with gel sweeps. Fill was hard to jet into. Unable to jet any deeper than 11185'. Circulate gel out. Dry tag at 11183'. Puh into tubing & perform injectivity test. Injectivity has improved after clean out. 3bpm at— 750psi. 2bpm at 500psi. 1 bpm at 150psi. Pooh. MU & RIH w/ PDS tools and 3.70"dumbbell drift nozzle. Tag at 11,149' CTM Down. Log up to 10,900', stopping to paint coil flag at 11,020'. POH. Pulled heavy from 10,500' up to 10,000'. Receive good data (+24' correction). MU & Rih w/HES 4-1/2" Cement 7/20/2015 Retainer(3.66"OD/2.0' OAL). • • Y-21A, Well History (Pre-Rig Sidetrack) CTU#6 1.75"CT Job Scope: FCO/ P&A. Correct depth at flag. Set 4-1/2" HES Cement Retainer middle element at 11125'. Top of retainer at 11124'. Pooh. Trim 100' of pipe& re-head. MU & Rih w/ HES Stinger Assy. Prior to stinging into retainer, perform injectivity test pumping down coil into 7" perfs: 1450 psi @ 2.7 bpm/940 psi @ 2.0 bpm/630 psi @ 1.5 bpm. Sting into retainer at 11,110' CTM. Correct depth to 11,125'. Attempt to perform injectivity test into 4-1/2"slotted liner, but appears that retainer or liner top packer is leaking. WHP increasing while pumping down coil. Should be isolated. lnjectivity while stung into retainer: 980 psi @ 2.7 bpm versus 1450 psi @ 2.7 bpm prior to stinging in. Consult with CT Superintendent and Anchorage Intervention Engineer. 7/21/2015 Pooh. MU PDS STP Tools BHA. CTU#6 1.75"CT Job Scope: FCO/ P&A. Continue rih with PDS STP Tools. Perform baseline pass from 10550'to 11105' (—20'above retainer). Come online down backside. Catch fluid after 10 bbls, whp started to stabilize out at-1700psi at 2.8bpm. Then after 40 bbls the well locked up jug tight. Zero injectivity into well now. Pooh. Lost part of PDS centralizer arm (see log for description). Call out Baker for venturi. Run venturi with 3.60" mule shoe bottom. Venturi from tubing tail to liner top. Unable to enter 4.5" liner top. Made several attempts to enter liner top adjusting pump rate, no luck. POOH. Recovered 3 large rocks and formation sand from venturi. Change packoffs, Trim 100' of pipe, chain inspection. Re-run venturi with 3.60" mule shoe oriented in opposite direction. Tag 7/22/2015 TOL at 11047'. Unable to work past, hoover up to tbg tail&back to TOL. Pooh. CTU#6 1.75" CT Job Scope: P&A. Continue pooh. Recover formation sand & large rocks. MU venturi with sealed knuckle joint& re-run. Tag TOL at 11043'. Attempted to get past 11043 multiple times at various speeds, pump rates, and WHP. Could not get deeper. POOH to check venturi, pumping down the backside to maintain 200psi WHP. Venturi partially full of smaller rocks and screen was packed off with sand/clay. Decision from town and CT Superintendent to RIH with a slim reverse FCO BHA and try to remove smaller debris. RIH with 1.75" BDJSN, tagged down at 11048 and made 20'. While PUH WHP increased rapidly, continued up hole. Returns dropped to 50%. Swap to conventional circulation and pump gel sweep from tubing tail. Returns went back to 100%. Circulate bottoms up. Rih &dry tag cement retainer at 11093'. Reverse clean out from 10600' down 7/23/2015 to cement retainer at 11093'. Pump btms up&dry drift clean to cmt retainer. Pooh. CTU#6 1.75"CT Job Scope: P&A. Continue pooh with 1.75 BDJSN. Pump gel pill & 1.25" drift ball thru coil to tanks. MU & Rih with Baker venturi w/3.60" mule shoe bottom. Tagged (down) at 11105CTMD, and ran venturi up and down from tag to LTP. OOH with venturi. Clay and sand fines along with -12 small rocks and one VERY large rock(3.25") stuck in the muleshoe. Decision to re- run the venturi. Tagged with venturi at similar depth 11113, and ran venturi up and down inside liner. Began injectivity test, see log for details. Post injectivity test, cannot get back into liner. Tagging 11055. POOH. Recovered 1 dog dish of sand and gravel. MU BKR milling assembly w/3.72"3- 7/24/2015 bladed junk mill. CTU#6 1.75" CT Job Scope: P&A. MU BKR milling assembly w/3.72" 3-bladed junk mill & RIH. Tag down on the liner top at 11047', spin into liner. Dry drift down to cement retainer at 11110'. PUH and get weight back, paint white flag. Mill through cement retainer and work it down to 11183'. Encounter multiple stalls at 11183'. PUH sticky each time and broke over. Park coil in 7" liner and perform injectivity test-> 2bpm @ 275psi, 3bpm @ 831 psi. Dry drift to 11148' and tag down. Pooh. MU & RIH with PDS carrier& 3.70" Bar-bell nozzle. Bullhead 189 bbls down bs to flush well. Pass 7/25/2015 thru LTP no problem. Stop at 11,140' (did not tag). Log up to 10500'. Flagged pipe at 11,020'. • • Y-21A, Well History (Pre-Rig Sidetrack) CTU#6 1.75" CT Job Scope: P&A. MU BKR 4.5"cement retainer& RIH. RIH and tie-in (PDS Jewelry Log March 30, 1996). Set BKR cement retainer at 11080'. Above cmt retainer perform injectivity test 1 bpm @—500psi, 2bpm @—1450psi. POOH. Cut pipe for chrome management. MU BKR cement stinger and RIH. Park above cmt retainer at 11040' and perform above injectivity test: 2bpm @ 1900psi and climbing, reduce rate. / lbpm @— 815psi. Tag at 11051'. Try pumping down Coil &Whp climbed up to--2000psi, no injectivity now in 7" perfs. Pull up to flag & confirm we are tagging the LTP. Able to bounce past&sting into Cement Retainer at 11066'. Injectivity below retainer: 2bpm @ 1300psi/ 1 bpm @ 500psi ***Zero WHP Response***WHP was actually slowly bleeding down while we were pumping below retainer. When off pump, WHP slowly went to Opsi. Repeated injectivity below retainer&WHP ***Now Communicating***(Opposite of what it just did). Repeat injectivity tests above& below retainer. Not real clear indication of where fluid is going. Constant change on injectivity rates. Discuss with APE, decision to not pump cement. Unsting from retainer, Pooh. MU 3.625"x18.86'dmy WS drift, max OD 3.70". Drift down to 11068' and tag. 7/26/2015 POOH. Left diesel FP in top of well. RDMO. 7/26/2015 SWCP 4516 STANDBY AT WLB UNTIL COIL TUBING IS FINISHED ON WELL. DRIFT TO DEVIATION AT 10,995'SLM (11,029' Elm)W/3.70"x 20' DUMMY WHIPSTOCK. LOCATE TUBING TAIL AT 10,620' SLM/ 10,654' ELM W/3.70"CENT, TEL, 2.50" S-BLR. 7/27/2015 UNABLE TO GET DEEPER THAN 10,858' SLM (Bailer full of cement/pebbles). T/I/O = 260/1160/0. Set 4" H TWC#292 . @125" Through tree. Installed CTD Test Spool#02 . Torqued and PT'd to API specs. (PASSED). Installed tree cap and PT'd (PASSED). RDMO. Final 8/26/2015 WHP's =TWC/1160/0. T/I/O=TWC/1180/0+. Temp= SI. Bleed WHPs to 0 psi. (Pre Rig). No wellhouse, flowline or AL line. Scaffolding on well has no handrails. IA FL @ 110' (7 bbls). OA FL near surface. Bled IAP from 1180 psi to 0+ psi in 45 minutes to slop tank(gas). IA FL rose 70'to 40'? (Difficult shots to determine). Monitored for 30 minutes. No change in WHPs. Final WHPs=TWC/0+/0+. Unable to 8/27/2015 verify SV&WV positions. SSV=C. MV= O. IA&OA= OTG. 23:50. • • r North America-ALASKA BPB-, E Page 1.af.C. Operation Summary Report Common Well Name:Y-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/29/2015 End Date: X3-01753-C:(4,037,963.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:NORDIC 1 Spud Date/Time:4/3/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292157400 Active datum:Y-21A @82.71usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (usft) 8/29/2015 00.00 - 06:00 6.00 RIGD P PRE RELEASED FROM R-35AAT 23:59 HRS ON 08/28/2015 -MOVE SAT OFFICE TOY PAD -MOVE RIG FROM R-35A TO H PAD 06:00 - 14:00 8.00 MOB P PRE STAGE RIG ON H PAD ACCESS ROAD WAIT ON RIG MATS -PERFORM MAINTENANCE ON RIG WHILE WAITING ON RIG MATS -MOVE FROM H PAD TO Y PAD 14.00 - 16:00 2.00 MOB N WAIT PRE RIG STUCK IN ROAD AFTER MOVING OFF FIRST SET OF RIG MATS -WSL NOTIFIED OF RIG STUCK IN ROAD WOS AND NORDIC SUPERINTENDANT NOTIFIED OF RIG STUCK IN ROAD -CALL TOOL SERVICES FOR SUPPORT -WORK TO GET OUT OF HOLE IN ROAD 16.00 - 20;00 4.00 MOB P PRE MOVE RIG TO Y-PAD j-STAGE RIG ON PAD AND CONDUCT CREW I CHANGE -HOLD PJSM WITH NORDIC 'SUPERINTENDANT AND CREW SPOT RIG OVER Y-21 AND SET DOWN ***AOGCC REP JONNIE HILL WAIVED WITNESS OF BOP TEST ON 8/29/2015 AT 1830 HOURS*** ***ACCEPT RIG AT 2000 HOURS*** 20:00 - 21:00 1.00 BOPSUR P j PRE NIPPLE DOWN TREE CAP CONFIRM BARRIERS PER ADW-MOC-11588 I-CYCLE AND RIG UP FUSIBLE CAP ON SWAB VALVE CYCLE AND BLEED MASTER/SWAB AND LEAK TIGHT TEST MASTER/SWAB TO 3500 PSI _-NIPPLE DOWN TREE CAP 21:00 - 23:30 2.50 BOPSUR P PRE NIPPLE UP BOP TO PRODUCTION TREE; TAKE AND POST STACK HEIGHT MEASUREMENTS 23:30 - 00:00 0.50 BOPSUR P PRE PRESSURE TEST BOP PER AOGCC,NORDIC AND BP REQUIREMENTS -HOLD PJSM FOR HIGH PRESSURE TESTING AND DISCUSS PRESSURE CROSSCHECK CARD -FLUID PACK AND SHELL TEST BOP COMPONENTS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES ***AOGCC REP JONNIE HILL WAIVED I WITNESS OF BOP TEST ON 8/29/2015 AT 1830 HOURS*** Printed 9/14/2015 9:49:15AM • North America-ALASKA-BP Page 2 ef-44-' Operation Summary Report Common Well Name:Y-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:8/29/2015 End Date X3-01753-C:(4,037,963.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:NORDIC 1 Spud Date/Time:4/3/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292157400 Active datum:Y-21A c 82.71usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/30/2015 00:00 - 08:30 8.50 BOPSUR P PRE PRESSURE TEST BOP PER AOGCC,NORDIC AND BP REQUIREMENTS -TEST BOP COMPONENTS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES -HOLD RIG EVACUATION DRILL AND AAR -FLUID PACK COILAND PREP FOR INNER REEL VALVE/PACK-OFF TEST ***AOGCC REP JONNIE HILL WAIVED WITNESS OF BOP TEST ON 8/29/2015 AT 1830 HOURS*** 08:30 - 09:00 0.50 BOPSUR P PRE PERFORM SLACK MANAGEMENT -PUMP SLACK BACK WITH 1%KCL -UNABLE TO MOVE SLACK IN REEL WITH KCL 09:00 - 13:00 4.00 BOPSUR N WAIT I PRE WALT ON FRESHWATER (WATER ORDERED PRIOR TO SHIFT CHANGE) ***PERFORM"RIG EVAC DRILL*** 13:00 17:30 4.50 I BOPSUR P PRE PERFORM SLACK MANAGEMENT -PUMP SLACK BACK WITH FRESH WATER I-RIG UP COIL CUTTER AND CUT 262'COIL l-INSTALL SLB COIL CONNECTOR -PULL TEST 40K GET ONTO WELL WITH INJECTOR MU BHI UQC/LQC -PRESSURE TEST SLB CONNECTOR/BHI CHECKS 17:30 - 20:00 2.50 BOPSUR P PRE PULL TWC -LOAD VALVE SHOP LUBRICATOR ONTO RIG FLOOR -RU LUBRICATOR AND PRESSURE TEST SAME -PULL TWC/CLOSE MASTER AND SWAB VALVE;100 PSI WHP -RD LUBRICATOR/UNLOAD FROM RIG FLOOR -TORQUE TREE BOLTS/GREESE TREE 20.00 - 20:45 0.75 BOPSUR P PRE MAKE UP NOZZLE/DRIFT BAR ASSEMBLY 1-MAKE UP 13'NOZZLE ASSEMBLY IN 'ANTICIPATION OF FAILED BULLHEAD KILL (ELIMINATES TESTING NIGHT CAP AND QTS) -STAB ON INJECTOR,PRESSURE TEST QTS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES -PUMP ELINE SLACK FORWARD WITH 60 BBLS,50°FRESH WATER -OPEN TREE VALVES TO A CLOSED CHOKE; 100 PSI WHP 20:45 - 21:30 0.75 BOPSUR P PRE BULLHEAD KILL WELL -ONLINE DOWN KILL LINE WITH 5 BBLS McOH SPEAR 1-BRING PUMPS UP TO 4.7 BPM;PUMPS TRIP AT 3500 PSI AFTER 10 BBLS PUMPED -SHUT DOWN,SWAP COIL FROM 50°FRESH WATER TO McOH SPEAR AND 120°KCL 21:30 - 23:30 2.00 BOPSUR P PRE RIH WITH NOZZLE ASSEMBLY FOR BOTTOM KILL -RIH AT 100 FPM,CIRCULATING 1 BPM, HOLDING CONSTANT WHP -GAS RETURNS FROM 6400'TO 7000' Printed 9/14/2015 9:49:15AM • North America-ALASKA-BFB f a� Page 3 v Operation Summary Report Common Well Name:Y-21 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:8/29/2015 End Date: X3-01753-C:(4,037,963.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:NORDIC 1 Spud Date/Time:4/3/1986 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292157400 Active datum:Y-21A(x)82.71 usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 BOPSUR P PRE BOTTOM KILL WELL -GET ON BOTTOM,MAINTAIN CASING PRESSURE,BRING PUMPS UP TO 170 SPM AND HOLD 2200 PSI DRILL PIPE PRESSURE (2050 FINAL+150 SAFETY) -CIRCULATE RETURNS TO FLOWBACK TANK 8/31/2015 00:00 - 01:00 1.00 BOPSUR P PRE CONTINUE BOTTOM KILL SWAP TO 8.5 PPG MUD 60 BBLS INTO FIRST I BOTTOMS UP WITH 8.4 PPG KCL -MAINTAIN CASING PRESSURE,GET 8.5 PPG MUD TO NOZZLE AND HOLD 3200 PSI DRILL PIPE PRESSURE (3050 FINAL+150 SAFETY) -CIRCULATE SECOND BOTTOMS UP WITH 8.4 KCL,TAKING RETURNS TO FLOWBACKTANK; DUMP ADDITIONAL 10 BBLS INTERFACE AND GET CLEAN 8.5 PPG MUD TO SURFACE;SHUT DOWN PUMPS 01.00 - 01:15 0.25 BOPSUR P PRE FLOW CHECK WELL;STATIC 01:15 - 03:30 2.25 BOPSUR P PRE POH WITH NOZZLE/DRIFT ASSEMBLY POH AT 120 FPM IN/OUT RATE=1.18/0.53 BPM IN/OUT DENSITY=8.53/8.43 PPG HOLD PJSM,FLOW CHECK,TAG UP,POP OFF INJECTOR AND LAY DOWN NOZZLE ASSEMBLY 03:30 - 04:30 1.00 STWHIP P WEXIT I MAKE UP BAKER 4-1/2"X 7"DELTA WHIPSTOCK I-MOBILIZE BTT TOOLS TO RIG FLOOR, ASSEMBLE AND HIGH-SIDE WHIPSTOCK I ASSEMBLY -MAKE UP WHIPSTOCK BHA 04.30 - 07:30 3.00 STWHIP p WEXIT RIH WITH WHIPSTOCK ASSEMBLY -STAB ON INJECTOR,PRESSURE TEST QTS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES AND RIH -IN/OUT RATE=0.80/1.24 BPM -IN/OUT DENSITY=8.51/8.56 PPG -MAINTAIN TRIPS-150 PSI ABOVE CIRCULATING PRESSURE 07:30 - 09:30 2.00 STWHIP P WEXIT LOG TIE IN(0')CORRECTION -LOG CCL LOG FOR SETTING WHIPSTOCK 09:30 - 10:00 0.50 STWHIP P WEXIT RIH TO WHIPSTOCK SETTING DEPTH -RECORD PU/SO WEIGHTS:38K/24K -PRESSURE UP SHEAR OFF:3400 PSI -SET DOWN 5K ON WHIPSTOCK 10:00 - 12:00 2.00 STWHIP P WEXIT POOH F/10,995'-200'MD -MM IN/OUT:1.24/0.81 CIRC PSI:740 -MW IN/OUT:8.54 PPG/8.52 PPG I-FLOW CHECK AT SURFACE I-HELD PJSM FOR LD WHIPSTOCK BHA 12:00 - 13:30 1.50 STMILL P WEXIT CHANGE BHA -STAND INJECTOR BACK -LD WHIPSTOCK RUNNING TOOLS -MU MILLING ASSEMBLY -GET ON WELL WITH INJECTOR -PRESSURE TEST QTS -INITIALIZE MWD TOOLS Printed 9/14/2015 9:4915AM - 4- • • North America-ALASKA-BP Page 4 d2L Operation Summary Report Common Well Name:Y-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/29/2015 End Date: X3-01753-C:(4,037,963.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:NORDIC 1 I Spud Date/Time:4/3/1986 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292157400 Active datum:Y-21A©82.71usft(above Mean Sea Level) Date From-To Hrs Task Code NPT j NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 16:45 3.25 STMILL P WEXIT RIH WITH MILLING ASSEMBLY F/120'-10,945' MD -MM IN/OUT:1.24/0.81 CIRC PSI:740 -MW IN/OUT:8.54 PPG/8.52 PPG LOG TIE IN(-1)CORRECTION -RIH DRY TAG PINCH POINT AT-11,001.9'MD 16:45 - 00:00 7.25 STMILL P WEXIT MILL 3.8"WINDOW F/11,001.3'-11,006.7'MD 004 MM IN/OUT:2.65/2.64 CIRC PSI:2150 MW IN/OUT:8.54 PPG/8.51 PPG 13'Pi -WOB/MTR WORK:2-3K/150 PSI MILL TO 11,006.7 AND LOSS RATE INCREASES TO-12 BPH 9/1/2015 00:00 - 01:00 1.00 STWHIP P WEXIT CONTINUE MILLING 3.80"'WINDOW F/11,006.7 I T/11,007.7' -MM IN/OUT:2.65/7:48 FREESPIN:2150 AT 2.7 BPM -MW IN/OUT:8.54 PPG/8.51 PPG -IA/OA/PVT:77/13/214 WOB/MTR WORK:2-3K/150 PSI 01 00 - 02:00 1.00 STWHIP P WEXIT CONTINUE MILLING 3.80"WINDOW F/11,007.7' T/11,008.7' MM IN/OUT:2.65/2.50 FREESPIN:2150 AT 2.7 BPM I I j-MW IN/OUT:8.54 PPG/8.51 PPG -IA/OA/PVT:83/15/203 -WOB/MTR WORK:1-2K/150 PSI 02:00 - 03:45 1.75 STWHIP P WEXIT I CONTINUE MILLING 3.80"WINDOW F/11,008.7' T/11,010.3' -MM IN/OUT:2.65/2.48 FREESPIN:2150 AT 2.7 BPM -MW IN/OUT:8.54 PPG/8.51 PPG -IA/OA/PVT:83/15/190 -WOB/MTR WORK:1-2K/150 PSI MILL TO BOTTOM OF WINDOW AT 11,009.3' AND CONTINUE CONTROL MILLING TO 11,010.3 FOR REAMER TO EXIT 03:45 - 05:45 2.00 STWHIP P WEXIT DRILL 10'RATHOLE -INCREASE WOB AND DRILL 10'NEW FORMATION WITH SLOW ROP UNDER 4 FPH -TAKE BOTTOMS UP SAMPLE AND CONFIRM WELLBORE EXIT 05:45 - 07:30 1.75 STWHIP P WEXIT MAKE 3X REAMING PASSES AT 1 FPM -MOTOR WORK ON 1ST PASS DOWN-100 PSI MOTOR WORK ON 2ND PASS DOWN-40 PSI 1-MOTOR WORK ON 3RD PASS DOWN-25 PSI DRY DRIFT(NO ISSUES NOTED) 07:30 - 10:00 2.50 STMILL P WEXIT POOH F/11,000'-250'MD -MM IN/OUT:4.19/3.41 CIRC PSI:3281 -MW IN/OUT:8.58 PPG/8.52 PPG -FLOW CHECK Printed 9/14/2015 9:49:15AM • • 4cal- Operation �1 North America-ALASKA-BP Page 5 4 Operation Summary Report Common Well Name:Y-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/29/2015 End Date: X3-01753-C:(4,037,963.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:NORDIC 1 Spud Date/Time:4/3/1986 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292157400 Active datum:Y-21 A t 82.71 usft(above Mean Sea Level) Date j From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) _ (usft) 10:00 - 11:30 1.50 DRILL P WEXIT CHANGE BHA GET INJECTOR OFF WELL LD MILLING ASSEMBLY I-GRADE MILLS:3.80 GO/3.79 NOGO -MU BUILD/LATERAL ASSEMBLY -GET ON WELL WITH INJECTOR -INITIALIZE MWD TOOL PRESSURE TEST QTS 11:30 - 15:00 3.50 DRILL P WEXIT RIH F/120'-10,880'MD MM IN/OUT:2.45/2.92 CIRC PSI:1798 -MWIN/OUT:8.56 PPG/8.53 PPG -LOG TIE IN(-1)DEPTH CORRECTION 15:00 - 22:15 7.25 DRILL P PROD1 I DRILL 4-1/4"LATERAL SECTION F/11,020'- 11,165'MD MM IN/OUT:2.82/2.48. CIRC PSI:2878 j-MW IN/OUT:8.59 PPG/8.57 PPG -IA/OA/PVT:43/13/224 -WOB/MTR WORK:1-3K/350-400 PSI LASS RATE=-18-20 BPH 22:15 - 22:45 0.50 DRILL P PROD1 LOSS RATE INCREASED-WIPER TRIP TO WINDOW AT 10,997' LOSS RATE INCREASE TO-65-90 BPH I-REDUCE PUMP RATE TO-2.6 BPM AND ;WIPER TRIP TO WINDOW AT 10,997' CONTINUE DRILLING AND SLOWLY I INCREASE PUMP RATE TO: -MM IN/OUT:2.72/2.43 CIRC PSI:2512 -MW IN/OUT:8.61 PPG/8.57 PPG -WOB/MTR WORK:1-3K/200-300 PSI -LOSS RATE=-18-20 ***CORRECTED WINDOW DEPTHS OF TIE-IN TOW:10,997'MD I-BOW:11,006'MD -RA TAG:11,005.5'MD 22:45 - 00:00 1.25 DRILL P PROD1 DRILL4-1/4"LATERAL SECTION F/11,165'- 11,290'MD -MM IN/OUT:2.74/2.53 CIRC PSI:2787 -MW IN/OUT:8.62 PPG/8.63 PPG -IA/OA/PVT:56/16/297 -WOB/MTR WORK:1-3K/350-400 PSI LOSS RATE=-10-13 BPH 9/2/2015 00:00 - 02:00 2.00 DRILL P PROD1 DRILL 4-1/4"LATERAL SECTION F/11,290'- 11,450'MD -MM IN/OUT:2.74/2.53 CIRC PSI:2787 -MW IN/OUT:8.62 PPG/8.63 PPG -IA/OA/PVT:56/16/297 -WOB/MTR WORK:1-3K/300-350 PSI -LOSS RATE=-10-13 BPH 02:00 - 03:00 1.00 DRILL P PROD1 MAKE LONG WIPER TRIP -WIPER TRIP TO THE WINDOW 11,006'AT -2.90 BPM -NO OVER PULL OR TIGHT HOLE -OPEN EDC I-CONTINUE WIPER TRIP TO 10,640'AT 3.5 BPM RIH TO 10,880' TIE-IN LOG AND MAKE+2'CORRECTION RIH TO WINDOWAND CLOSE EDC CONTINUE RIH TO 11,450'TD -HOLE SLICK-NO TIGHT SPOTS Printed 9/14/2015 9:49:15AM TREE 4"CNV • y-21 A 4-1/2'CHROME.TBG WELL ANGLE>70"@ 11045''•" WFa 1 ' •D= MCEVOY 7 ACTUATOR= BAKER OKB.ELEV= 87.6' 0 BF HEV= 51.35' 2025' _14-1/2"HES XMP,D=3.813 KOP= 3100' Max Angle= 92°@ 11435 _"CONDUCTOR, — ? Datum MD= 10748 _#, GAS MANDRELS Datum TVD= 8800'SS ID= ST MD ND DEV TYPE VLV LATCH PORT DATE a. 5 3003 3002 8 MMG DAY RK 0 07/11/15 13-3/8"CSG,72#,L-80,D=12.347' —1 2668' till 4 5085 4765 39 MMG DMY RK 0 07/11/15 9-518"X T BKR TIEBACK SLV,D=7.50' H8823• 3 7088 6258 42 MMG DMY RK 0 07/11/15 2 8692 7509 36 IMG DMfY RK 0 07!11115 9-5/8"X 7' BKR TACK SLV,D=7.50" —i $$30'--•� 1 10338 8656 52 KBG2 DON BK 0 07/11/15 9-5/8"CSG,47#,L-80,ID=8.681" —I ^-9000' H MLLOUT WNDOW(Y-21A) 9000'-9050' Minimum ID = 3.80" a@ 10631' , I 10409• _14-1/2"FES X NP,D=3.813 MILLED 4-1/2" XN NIPPLE S A_ I 10442' _17"X 4-112"BKR S-3 FKR,D=3.870" 1 I 10473' _44-1/2"FES X NP,D=3.813 41/2"TBG,12.6#,13-CR JFE BEAR, H 10545' j-- .0152 bpf,D=3.958" 10554' _19-5/8"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TBG STUB(TAGGED 10/17/06) H 10550' ' 10585" _44-1/2'OTiS X NP,D=3.813' 10597' ___I 7"X 4-1/2"BKR SAB-3 PKR,ID=3.875" ' 10621' —I4-112"OTIS X NP,D=3.813" ' 10631' __I 4-1/2"OTIS XN NP,NULLED TO 3.80'(3/13/15) 4-1/2"TBG,12.6#,L-80 NSCT, H 10642' ‘ 10644' _44-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" 10654' —I ELME)TT LOGGED ON XX/XX/XX 0 ----I 10997' ]—Jr X 4-1/2'DELTA WHPSTOCK(08/31/15) 7"LNR,29#,NT-80S NSCC,.0371 bpf,D=6.184" H 11200' 11056' HT"X 4-1/2"TNV SS HORZ PKR,ID=3.91' PERFORATION SUMMARY 11028' —I4"RADKVICTNEMARKER JT W/RA TAG ' ' t REF LOG: PRODUCTION LOG OF 05/08/95 � � ANGLE AT TOP PERE: 67'@ 10890' 11056' H 7"X 4-1/2"TIN SS HORZ PKR,D=3.91" Note:Defer to Production OB for historical pert data 11 11080' {4 112"BKR CMT RETAINER(07/26/15) SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 3-318" 6 10890-10920 0 03106!96 , ilk , ? H FISH:LOGGING CENT ARM LEFT DH(07/22/15) 3-3/8" 6 10972 11002 0 03/06/96 ' 4br—' 11183' HFISH:CMT RETAINER MLLED/PUSH33(07/25!15) 3-3/8" 6 11012-11032 O 03/06/96 4-1/2' SLTD 11189-12567 C 05/03/95 11219' H COLLAPSED LNR(03/15/15) (81) \I 4-1/2" SLTD 12603-13461 C 05/03/95 0 12576' —I4-112"PAY ZONE CSG PKR PBTD 13461' 4-1/2"SLID LNR,12.6#,L-80 NSCT, 13485' 1 ' .0152 bpf,D=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY MT 04/01/86 ORIGINAL COMPLETION 09/16/15 TBDIJMD GLV C!O(07/11/15) WELL: Y-21A 05/03/95 LINDER SIDETRACK CMPLETION 09/16/15 TTRIJMD SET CMT RET/FISH/COLLAPSED LNR PERMIT No: 1950370 10/22/06 D16 RWO 09/16/15 TR/JMD ADDED WHIPSTOCK(08/31/15) API No: 50-029-21574-01 03/13/15 I I W PJC ILL XN NIPPLE 09/22/15 JNUJMD UPDATED TOP OF MLLOUT DEPTH Sec.33,T11N,R13E, 1417 FNL&240'FEL 05/20/15 PJC TBG/LW UPDATES _ 05/20/15 PJC REFORMAT/ LLOUT PRE RIG BP Exploration(Alaska) -o Ze1 \qs. of) 1110 2c044 1 mJ WELL LOG RECEIVED TRANSMITTAL AUG 2 0 21i6 AOGCCDATA LOGGED PROACTIVE DIAC{NOSTIC SERVICES, INC. 2.q/2015 K BENDER To: AOGCC Makana Bender 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 attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage, AK 99508 gancpdc(a bp.com SCANNED SEP d 32015 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 20-Jul-15 07-12 BL/CD 50-029-20337-00 2) Leak Detection - STP 21-Jul-15 Y-21A BL/ CD 50-029-21574-01 </7) Signed : (i) Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(WMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Di stribution\Transmittal S heets\BP_Transmit.docx of ThiAlaska Oil and Gas hw\ I�js THE STATE �,' of j Conservation Commission I ASKA. mitt 2 l = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1433 OA, AL q Fox' 907 276 7542 JUL 1t 1 www.aogcc alaska.gov NE® 0 L N John McMullen SLp► Engineering Team Leader CI5 0 3 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-21A Sundry Number: 315-368 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, Daniel T. Seamount, Jr. �,d Commissioner DATED this 72dayof June, 2015 Encl. STATE OF ALASKA RECEIVED ' ALASKA OIL AND GAS CONSERVATION COMMISSION ; u`��``.6 APPLICATION FOR SUNDRY APPROVAL .il_IN 1. 5 201 20 AAC 25.280 A0GVC 1. Type of Request: V ❑Abandon ®Plug for Redrill • El Perforate New Pool ❑ Repair Well ['Change Approved Program ❑Suspend 0 Plug Perforations El Perforate 0 Pull Tubing ['Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well ['Stimulate ❑Alter Casing ['Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ['Exploratory ❑Stratigraphic 195-037 • - 3. Address. 6. API Number: e,Alaska 99519-6612 ®Development ❑Service P.O. Box 196612,Anchorage, 50.029-21574-01-00 • 7 If perforating 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU Y-21A • Will planned perforations require a Spacing Exception? 0YesNo 9. Property Designatior 10.Field/Pool(s): ADL 028287&047471 Prudhoe Bay/Prudhoe Bay- 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) 13500' - 9029' - 13461' 9027' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 33'- 113' 33'- 113' Surface 2630' 13-3/8" 33'-2663' 33'-2663' 4930 2670 Intermediate 8969' 9-5/8" 31'-9000' 31'-7761' 6870 4760 Production Liner 2377' 7" 8823'- 11200' 7616'-9023' 8160 7020 Liner 2429' 4-1/2" 11056'- 13485' 8998'-9028' 8430 7500 Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft): 10890'-11032',Slotted Liner 11189'-13461' 8939'-8991',Slotted Liner 9022'-9027' 4-1/2", 12.6# 13C r80/L-80 10644' Packers and SSSV Type: 7"x 4-1/2"Baker S-3 Production Packer; Packers and SSSV 10446'/8722'; 7"x 4-1/2" Baker SABL-3 Packer MD(ft)and ND(ft): 10597'/8811' 12. Attachments: 13.Well Class after proposed work. ®Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work. Commencing Operation June 25,2015 ❑Oil ❑WINJ ❑WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG ®Suspended • 17. I hereby certify that th- oregoing is rue and correct to the best of my knowledge Contact: Zach Browning,564-5220 Printed Name. J2' ; n a I. ' Title: Engineering Team Leader 011.5*----Email: Zach Browning@bp.com Signature: ,,W / Phone. 564-4711 Date: ea.Commission Use Only Conditio of approval Notify Commission so that a representative may witness Sundry Number: 315- -3(Qy 11 ❑ Plug Integrity L tsOP Test ❑Mechanical Integrity Test ❑Location Clearance Other C'OP tei f to 3S-OU 5 l4 psis .3 262/ps., 5 ) 4/3"1-/arpr�v�.?tcr frit tc zSGe, p_5-i' f1/fer7--)c//c ph,3p14 •cii-rev-i f a-ppr-i cdp-rr 2c.--,-tC25-. /!Z Li ). Spacing Exception Required? ❑Yes E]`No Subsequent Form Required: /0 — 4 O 7 APPROVED BY /2_ ' Approved By: COMMISSIONER THE COMMISSION Date: Form 10-403 Rev ed 10/2012 AoRi G1ADMSj i i for 12 months from the date of approval Submit In Duplicate l/ &//7//c U pIV JUN 2 4 2015 Cl ' it,./s To: Alaska Oil & Gas Conservation Commission = From: Zach Browning biD CTD Engineer Date: June 11, 2015 Re: Y-21A Sundry Approval Request Sundry approval is requested to plug the Y-21A slotted liner and perforations as part of the preparation, drilling and completing the proposed Y-21B coiled tubing sidetrack. History of Y-21A: Y-21 was drilled in 1986 and abandoned in 1995 after CUM production of 1MM BO. Y-21A was completed in 1995 and has CUM production of 1.84 MM BO. This well is currently producing -50- 80 BOPD at 94% WC.,, This well has no remaining well work options, and the best utility for this U'fi wellboreis to sidetrack to a more prospective location. Proposed plan for Y-21B and BL1: Drill a through tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig on or around August 25th, 2015. The Y-21 B sidetrack will be a single string exit from the existing 7" liner. The kick-off is in the Shublik and will land in Zone 4 targeting reserves in Zone 4B. The proposed sidetrack is a —3025' horizontal Ivishak Zone 4 producer to be completed with a 3-1/2" x 2-7/8" 13Cr solid liner, cemented in place. From the Y-21B leg a slimhole BL1 lateral will be drilled. This will also be a zone 4 sidetrack targeting reserves in 4B north of the parent and completed with a 2-3/8" slotted liner left outside the window. This Sundry covers the plugging the existing Y-21A perforations via the Y-21 B liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. /i ld o(�ct. ye ver-,' �� 02 —(/' 5Wio,--h Co" C w% 7-44 1„4?// ®� iP dr // �S�i 6 ti/c.? q f�(7,,.wr /00/. recover -fro" �y'1 Porti a, pf %Gly Pre-Rig Work(scheduled to begin June 25th, 2015) 1. S Dummy GLVs. Drift for Whipstock. 2. F A/SL: Load IA and MIT-IA. 3. C Set Cement retainer. Liner Cement Squeeze. 4. S Drift for Whipstock 5. E Set 4-1/2" x 7" Delta Whipstock at 11,000' MD 6. V Set TWC. Pre CTD Treework. 7"h i5 Rig Work(scheduled to begin August 25th, 2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP = 2621psi) 2. Bullhead kill well. 3. Mill 3.80" window at 11,000' and 10' of rathole. (4-1/2" x 7" Delta WS set pre-rig on E-line) 4. Drill Production hole section: 4.25" OH, 3025' (12° deg/100 planned). 5. Run 3-1/2" x 2-7/8" 13Cr solid liner leaving TOL at—10,495' MD. 6. Pump primary cement (TOC=TOL), 47.2 bbls of 15.8 ppg liner cmt planned (20% OH excess). 7. Perform GR/CCL cleanout/logging run. Ale 8. Test liner lap to 2400 psi. Set LTP on slickline post-rig if test fails.* T,o 9. Perforate well based on log interpretation. 10. Swap to 2" CT reel. 11. Set 3-1/2" Monobore WS with top set at 11,120' MD 12. Mill 2.80" window at 11,120' MD and 10' of rathole. 13. Drill Production hole section: 3.25" OH, 2490' (12° deg/100 planned). 14. Run 2-3/8" L-80 slotted liner. TOL left outside window at—11,140' MD 15. Freeze protect well to 2500' MD 16. Set TWC, RDMO * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. Re-install wellhouse, flowline and pull TWC. 2. Install GLVs. 3. Set liner top packer with slickline if liner lap test fails.* 4. ASRC flowback. SIT. Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 TREE= - 4"CM/ S Y NOTES: OLD WELLBORE NOT SHOWN ON WEFLHEAD= MCEVOY ACTUATOR -2 BELOW BAKER Y-21 A 0TRK WINDOW.EXCEEDS 70 DEG @ 11045'8 GOES HORIZONTAL @ OKB.ELEV= 87.6' BF.EFEV= 51.35' 11341'7'4-112"CHROME TBG"' KOP= 3100' Max Angle= 92"@ 11435' I I 2025' _44-1/2"HES X NP,D=3.813 Datum MD= 10746 GAS LFT MANDRELS Datum TVD= 8800'SS ST ND ND DEV TYPE VLV LATCH FORT DATE 5 3003 3002 7 MM3 DONE RK 16 05/24/07 13-3/8"CSG,72#,L-80,D=12.347" H2668' Iii4 5085 4766 39 G DOME RK 16 05/24/07 , 3 7088 6259 42 MM3 DOME RK 16 05/24/07 y 2 8692 7510 36 Ii/MG DOME RK 16 05/24/07 1 10338 8657 52 KBG2 SO BK 24 05/24/07 TOP OF 7"LNR —I 8823' —i L 8823' TOP OF BKR TIEBACK SLV,D=7.50" 8830' _9-5/8"X 7"BKR LNR TOP PKR, Minimum ID = 3.80" @ 10631' w/HYDSETHGR,D=6.184" MILLED 4-1/2" XN NIPPLE I Ir----------1 10409' _14-1/2"HES X NP,D=3.813 S $ 10442' _47"X 4-1/2"BKR S-3 PKR,D=3.870" I I —I 10473' _14-1/2"HES X NP,0=3.813 4-1l2"TBG,12.6#,13-CR VAM TOP, H 10545' —/ .0152 bpf,ID=3.958" I 10550' _I TUBNG STUB(TAGGED 10/17/06) 10554' _17"X 4-1/2"UNIQUE OVERSHOT I I 10585' _14-1/2"OTIS X NP,D=3.813" S N 10597' _17"X 4-1/2"BKR SAB-63 PKR,D=3.875" I I 10621' _14-1/2"OTIS X NP,D=3.813" I I 10631' _J4-1/2"OTIS XN NIP,MLLEDTO 3.80"(3/13/15) 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" —{ 10642' / \ 10644' _14-1/2"WLEG,D=3.958" 10654' --) ELMD 5-JIO IV11LLt.J I VVIVWWV I I-LIN/ nnnn' nncn' PERFORATION SUMMARY 1 11027' -4'MARKER JT W!RA TAG] REF LOG: PRODUCTION LOG OF 05/08/95 ANGLE AT TOP PERF: 67'@ 10890' 11056' 7")---I—(4- 2"TNV SS HORZ PKR D=3.91" 1 Note:Refer to Rod uction 06 for historical perf data 11200' 7"LNR,29#,NT80-S, SIZE SP= INTERVAL Opn/Sgz SHOT SQZ .0371 bpf,D=6.184" 3-3/8" 6 10890-10920 0 03/06/96 �1t1`1 11111. 3-3/8" 6 10972-11002 0 03/06/96 111111 v 12576' —CTC EXT 11111111. 3-3/8" 6 11012- 11032 0 03/06/96 .1.1.4.1.11.4.1....:.. CSG PKR '1'1'1D9'1'D MOW 4-1/2" SLID 11189- 12567 O 05/03/95 .111111111/11111/11114 4-1/2" SLID 12603-13461 0 05/03195 111111111111111111111, �j11111111/11111111114 �® 411111111111.4.11 -, 111111111111111111114 , 1111111111111111/1114 :i 9-5/8"CSG,47#,L-80,D=8.681" H 11367' 1.1.. PBTD H 13461' 4-1/2"SLID LNR,12.6#,L-80,.0152 bpf,D=3.958" 13485' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UM' 04/01/86 ORIGINAL COMPLETION 11/14/06 DCR/PJC DRLG DRAFT CORRECTIONS WELL: Y-21A 05/03/95 LINDER SIDETRACK CM PLETION 06/01/07 JLJ/PAG GLV GO(05/24/07) PERMT No:'1950370 10/22/06 D16 RWO 12/03/13 TJWJMD SET 4-1/7'PX RUG(11/27/13) AR No: 50-029-21574-01 09/25/05 WTS/TLH XXN PLUG SET(05/23/04) 02/06/14 JTMWJMD PULLED PX PLUG(02/05/14) Sec.33,T11 N,R13E,1417'FNL 8 240'FEL 11/09/06 JLJ/TLH XXN PLUG PJLLECYGLV GO 03/13/15 TTR/PJC MLL XN NIPPLE 11/12/06 DRS✓TLH FKRDESCR CORRECTION 1 BP Exploration(Alaska) TREE= " 4"OW WELLHEAD= MCEVOY , Y NOTES: OLD WELLBORE NOT SHOWN ON ACTUATOR= BAKERY-21B BL1 SDTRK EXCEEDS 70 DEG @ 11045'8 GOES HORIZONTAL BF.E3EV= 51.35' 11341'.**4-1/2"CHROME TBG"' KOP= 3100' Max Angie= 9?@ 11435' I 2025' 4-1/2"HES X NP,D=3.813 Datum MD= 10746 GAS LFT MANDRELS Datum TVD= 8800'SS ST WD TVD DEV TYPE VLV LATCH PORT DATE 5 3003 3002 7 WiMG DOME RK 16 05/24/07 13-3/8'CSG,72#,L-80,0=12.347" —I 2668' 4 5085 4766 39 MND DOME FE 16 05/24/07 3 7088 6259 42 WAG DOME RK 16 05/24/07 2 8692 7510 36 MND DOW RK 16 05/24/07 1 10338 8657 52 KBG2 SO BK 24 05/24/07 TOP OF 7'LIR —I 8823' 8823' _I TOP OF BKR TACK SLV,D=7.50" Minimum ID = 3.80" © 10631' I! 8830' 1_19-5/8-X 7"BKR LNR TOP PKR, MILLED 4-1/2" XN NIPPLE I w/HYDSET HGR,D=6.184" 1 ' 10409' _14-1/2"HES X NP,D=3.813 4-1/2"TBG,12.6#,13-CR VAM TOP, —{ 10545' E ►:/ 10442' _47'X 4-1/2"BKR S-3 PKR D=3.870" .0152 bpf,D=3.958" , ' 10473' .44-1/2"HES X NP,D=3.813 1 r I 10550' .4�I`IG STUB(TAGGED 10/17/06) B-Leg - 10554' _7"X 4-1/2"UNIQUE OVERSHOT 3-1/2"H511 x2-7/$"STL L-80 SB.Lher TOW S set@ 11,000' TD at14,025'MD I L 10585' _J4-1/2"OTIS X NP,D=3.813" X-overat-11,180'M D $ ►:/ 10597' _17"X4-1/2"BKR SAB-63PKR,D=3.875" TOL@ 10,495'M D I 10621' _14-1/2"OTIS X NP,D=3.813" BL1 - ' 10631' _14-1/2"OTIS XN MP,MLLED TO 3.80"(3/13/15) 2-3/8"H511 Sbt ed ]her TOW S set@ 11,120'MD ,TD @ 13,630' // 10644' .44-1/2"WLEG,D=3.958' 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958' -f 10642' I , _ //41, / / / / / / / / 69° INC / // / / / PERFORATION SUMMARY ,�i.4' REF LOG: PRODUCTION LOG OF 05/08/95 ( •1'''' ANGLE AT TOP FERE: 67"@ 10890' O f Note:Refer to Production DB for historical pert data •4 r SIZE SR= INTERVAL Opn/Sgz SHOT SQZ 3-3/8" 6 10890-10920 0 03/06/96 11027' —14'MARKER JT W!RA TAG 3-3/8" 6 10972-11002 0 03/06/96 •••+ t' 3-3/8" 6 11012-11032 0 03/06/96 .".'. , 4-1/2" SLID 11189-12567 0 05/03/95 +�•f# 11056' -17"X 4-12"TNV SS HORZ PKR D=3.91" 4-1/2" SLID 12603-13461 0 05/03/95 >•p•• .##### Set CIBP and Cement Squeeze A" of Y 21A slotted liner .+#.. DATE REV BY COMMENTS DATE REV BY COMVETTTS PRUDHOE BAY UNIT 04/01/86 ORIGINAL COMPLETION 11/14/06 DCR/PJC DRLG DRAFT CORRECTIONS WELL: Y-21A 05/03/95 UNDER SIDETRACK CMPLETION 06/01/07 JLJ/PAG GLV CIO(05/24/07) PERAK No:'1950370 10/22/06 D16 RWO 12/03/13 TJWJW ) SET 4-1/2"PX PLUG(11/27/13) AR No: 50-029-21574-01 09/25/05 WTS/TLH XXN PLUG SET(05/23/04) 02/06/14 JTWYJWD PULL®PX PLUG(02/05/14) Sec.33,T11 M R13E, 1417'R'L&240'FEL 11/09/06 JLJ/ILH XXN PLUG PULLED/GLV C/O 03/13/15 TTR/PJC MILL XN MPPLE 11/12/06 DRS/TLH FKR DESCR CORRECTION BP Exploration(Alaska) 0 11-' e•I ."m 4 a 111 v g m S2 A• III 1111 15 V•� f _ ,i — II I I II 110 I' A 2 11 R" m f ,f.. .^a a_^ i o 111 .1 I Nil n 7 . . 7 g O m ry A g9. u t '�o a L.ii r 7. U m U 7 2 t m o i� a - v O a a m m Q ■ I Q cal g `-a... I 1 m 9 I L a i1 0 Ju. o�� I I 1 r O > , m 1 m c i m // n� ° I g a ry z U S me N m CQ f I v go C ' I €I III OM O ‘.° igg Z I U U j ' 1 1 Q I Y E1 111 0 e A Stl Eo (� II& ic I W1. ? s &, & • ,4J 1 • I . 2, o E i WN 1 ~ 9 U W m 0 w I! 0U O t ®l4 = N Ii N 11 14 41. LL a - mot Vm / ]j _1 „ Q 1 d U 1 U I LI Ce I 6' 1 ■ mI iii m N 1 a [ 0 II ] IAI1 0 'J ow '� I M I. ��� " i_ 1 " I i■ ,I rvjn. \ l ii - I m• 1 $ M Ir 1 iii 1 " O I I 111=1111i 11 Z 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 V 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 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. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. iq5 - 0~-~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy ~incent TO RE-SCAN Nathan Lowell Date: ~1 ~1 ~si Notes: Re-Scanned by: Bevedy Deanna Vincent Nathan Lowell Date: Is~ • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 AMC JA 2 December 20, 2010 Mr. Tom Maunder t �, `. Alaska Oil and Gas Conservation Commission �, ._Slon 333 West 7 Avenue ^ . *AlitS• Anchorage, Alaska 99501 r ''' <" >: Subject: Corrosion Inhibitor Treatments of GPB Y Pad 19 5,0 3 7 Dear Mr. Maunder, . rj Enclosed please find multiple copies of a spreadsheet with a list of wells from Y Pad 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, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator 0 i BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12/20/1,0 , Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # cement pumped _ cement date inhibitor sealant date ft bbls ft na gal Y -01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y - 02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y - 03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y - 04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y -058 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y -06A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y - 07A 2071050 50029205600100 14.5 2.0 0.3 NA 1.70 8/4/2010 Y -08A 1880560 500292057201 00 NA 4 NA 15.30 8/5/2010 Y -09A 1970830 50029205790100 19 1.5 3.6 NA 17.00 8/4/2010 Y -10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y -11C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y -13 1811120 50029206340000 NA 0.4 NA 3.40 4/15/2010 Y -148 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y -16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y - 18 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y -19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y -20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 r> Y -21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y - 22A 1881150 50029215580100 NA 0.5 NA 3.40 8/4/2010 Y -236 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 • Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y -25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y - 26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y -27 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y - 28 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y - 29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 Y -30 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y - 31 1910560 50029221610000 NA 0.5 NA 3.40 4/12/2010 Y - 32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y -33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y - 34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y - 35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y -36 1931310 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y -37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 RE: UNDER EVALUATION: Y~A (PTD #1950370) Sustained IA Casin~ressure - P... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~, 3'~' io Sent: Thursday, February 25, 2010 9:49 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); NSU, ADW Well Integrity Engineer; GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Schmoyer, AI Subject: RE: UNDER EVALUATION: Y-21A (PTD #1950370) Sustained IA Casing Pressure -Possible TxIA Comm All, Well Y-21 B (PTD #1950370) passed a TIFL on 02/24/10 proving tubing integrity. The well has been reclassified as Operable and may be placed on production when convenient for operations. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~t~.~~~ ~Vtt-tft' . e ~U From: NSU, ADW Well Integrity Engineer Sent: Sunday, February 21, 2010 11:03 PM To: NSU, ADW Well Integrity Engineer; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GCl Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Schmoyer, AI Subject: UNDER EVALUATION: Y-21A (PTD #1950370) Sustained IA Casing Pressure -Possible TxIA Comm AI I, Well Y-21 B (PTD #1950370) has been report with sustained casing pressure on the IA due to possible TxIA communication. The wellhead pressure were tubing/IA/OA equal to 150/2340/20 on 2/19/10. The well was reported with high IA pressure in January but passed a TIFL on 1/24/10. The well has been reclassified as Under Evaluation. Once normal operations return following the inclement weather, a TIFL will be conducted to evaluate the well for possible TxIA communication. A TIO plot and wellbore schematic have been included for reference. Please let us know if there are any questions. Thank you, 3/1/2010 RE: UNDER EVALUATION: Y~A (PTD #1950370) Sustained IA Casin~ressure - P... Page 2 of 2 Anna Dude, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: 1907) 658-5102 Pager: (907} 659-5100 x1154 3/1/2010 FW: UNDER EVALUATION: Y- lA (PTD #1950370) Sustained IA Cas~Pressure - P... Fage 1 0 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: .Sunday, February 21, 2010 11:05 PM ~~~~ Z-~Z-3~~o To: Regg, James 6 (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: FW: UNDER EVALUATION: Y-21A (PTD #1950370) Sustained IA Casing Pressure -Possible TxIA Comm Attachments: Y-21A TIO Plot.doc; Y-21A.pdf Jim, Tom, and Guy - I apologize I missed adding your names to the original distribution. _,,.,,, ,,, m~..,.,,. Thank you, Anna ~u6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 859-5102 Pager: {907) 859-5100 x1154 ~tiA~~t~~~~ ~~~ ~ l~ ~d~~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, February 21, 2010 11:03 PM To: NSU, ADW Well Integrity Engineer; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GCl Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Schmoyer, AI Subject: UNDER EVALUATION: Y-21A (PTD #1950370) Sustained IA Casing Pressure -Possible TxIA Comm All, Well Y-21 B (PTD #1950370) has been report with sustained casing pressure on the IA due to possible TxIA communication. The wellhead pressure were tubing/IAlOA equal to 150/23~~2/19/10. The well was reported with hig I1LA pressure in Januarv but passed a TIFL on 1/24/10. The well has been reclassified as Under Evaluation. Once normal operations return following the inclement weather, a TIFL will be conducted to evaluate the well for possible TxIA communication. A TIO plot and wellbore schematic have been included for reference. «Y-21A TIO Plot.doc» «Y-21A.pdf» (~ Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 859-5102 Pager: {907) 859-5100 x1154 2/23/2010 PBU Y-21A PTD #1950370 2/21 /2010 TIO Pressures Plot a,DDo 3,aoa 2.OD0 1.000 • -#~- Tbg -F IA -~- OA OOA -~ OOOA On J • 11J21JD9 11!28!09 12/05!09 12!12!09 12!19!09 12!26!09 D1J02J10 01!09!10 01!16!10 01!23!10 01J3DJ1D 02!06!10 02!13!10 02I2DJ10 TREE= 4" CNV WELLHEAD= MCEVOY ACTUATOR= BAKER KB. ELEV = 87.56' BF. ELEV = 51.35' KOP = 3100' Max An le = 92 11435' Datum MD= 10746 Datum ND = 8800' SS PERFORATION SUMMARY REF LOG: PRODUCTION LOG OF 05/08/95 ANGLEATTOP PERF: 67 @ 10890' Note: Refer to FYoduction DB for historical erf data SIZE SPF NTERVAL n/S z DATE 3-3/8" 6 10890 - 10920 O 03/06/96 3-3/8" 6 10972 - 11002 O 03/06/96 3-3/8" 6 11012 - 11032 O 03/06/96 4-112" SLTD 11189 - 12567 O 05/03/95 4-1/2" SLID 12603 - 13461 O 05/03/95 Y-21 A 9-5/8" MLLOUT WINDOW (Y-21A) 9000' - 9050' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/01/86 ORIGINAL COMPLETION 11/14/06 DCR/PJC DRLG DRAFT CORRECTIONS 05/03/95 LINDB~ SIDEfRACKCMPLETION 06/01/07 JLJ/PAG GLV GO(OS/24/07) 10/22/06 D16 RWO 09/25/05 WTS/TLH XXN PLUG SET (05/23/04) 11 /09/06 JLJITLH XXN PLUG PULL®/GLV C/0 11/12/06 DRS/TLH PKRDESCR CORRECTION PRUDHOE BAY UNIT WELL: Y-21A PERMIT No: 1950370 API No: 50-029-21574-01 1714' SNL & 240' WEL, Sec. 33, T11N, R13E BP Exploration (Alaska) SAFETY NOTES: OLDW~LBORENOT SHOWN ON DIAGRAM BELOW 9-5/8" SDTRK WINpOW. WELL EXCEEDS 70 DBG @ 11045' & GOES HORIZONTAL 11341'.*'"'4-1/2" C HROM E TBG'*' ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3003 3002 7 MMG DOME RK 16 05C24i07 4 5085 4766 39 MMG DOME RK 16 05/24/07 3 7088 6259 42 MMG DOME RK 16 05/24N7 2 8692 7510 36 MMG DOME RK 16 05C24ro7 1 10338 8657 52 KBG2 SO BK 24 05x24/07 4-1/2" SLTD LNR 12.6#, L-80, .0152 bpf, ID= 3.958" 73485' . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED NO\! 0 2 2006 REPORT OF SUNDRY WELL OPERA '[!ºN~ " ~.' .' f··~. ;". f'~ ,'" "rid " ", ,. ""H' r 1. Operations Performed: t rwi';;; QtfI 0 AbandonD Repair Weill!! Plu : PerforationsD Stimulate 0 . !"""',A- ..... er Alter CasingD Pull TubingŒ Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD it 1 Q"-ß370 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-21574-01-00 7. KB Elevation (ft): 9. Well Name and Number: 82.71 Y-21 A 8. Property Designation: 10. Field/Pool(s): ADL-047471 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 13500 feet true vertical 9030.0 feet Plugs (measured) None Effective Depth measured 13461 feet Junk (measured) None true vertical 9028.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 20" 91.5# H-40 26 - 110 26.0 - 110.0 1490 470 SURFACE 2643 13-3/8" 72# L-80 25 - 2668 25.0 - 2668.0 5380 2670 PRODUCTION 5094 9-5/8" 47# L-80 NSCC 24 - 5118 24.0 - 4791.0 6870 4760 PRODUCTON 3882 9-5/8" 47# L-80 Butt 5118 - 9000 4791.0 - 7762.0 6870 4760 LINER 2377 7" 26# NT -80S 8823 - 11200 7617.0 - 9024.0 7240 5410 LINER 2429 4-1/2" 12.6# L-80 11056 - 13485 8999.0 - 9029.0 8430 7500 ._......,'~- Perforation depth: Measured depth: 10890-10920,10972-11002,11012-11032, SLTD ---11189-12567, SLTD ---12603-13461 True vertical depth: 8940-8951,8971-8982,8986-8992, SL TD --- 9023-9020, SL TD --- 9020-9028 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 21 - 10545 (\ L'( 2.n f1H 7"x4-1/2" Unique Overshot @ 10545 1~1#\~~~,~;¡:';R; ¿) Ü . ''WiY'.,. , '"..,y -t;\"_'\Jt~',- 4-1/2" 12.6# L-80 @ 10550 - 10~i4'" ." Packers & SSSV (type & measured depth): 9-5/8" Baker LNR Top PKR @ 8830 7" Baker S-3 Packer @ 10442 7" Baker SAB-63 PKR @ 10597 7" TIW SS HORZ Packer @ 11056 ~1'¡¡-::?t~J!\.Jfr;: 8Ft CTC EXT CSG Packer @ 12576 Ç¡ t~2UDÕ 4-1/2" HES X Nipple @ 2025 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RWO work completed --- replaced tubing with 4·1/2" Chrome tubing. 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubing Pressure Prior to well operation: SI 0 0 --- 0 Subsequent to operation: SI 0 0 --- 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentOO ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasO WAG 0 GINJO WINJO WDSPLO Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TSUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWaYl1e R. Schnorr ~ A Title Petroleum Engineer Signature ~~. L77 Æ // ./ Phone 564-5174 Date 10/31/06 lj . ,~. . Form 10-404 Revised 4/2004 TREE = WELLHEAO= ACTUATOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MO = Datum lVO = 4" CrN MCEVOY BAKER 87.56' 51,35' 3100' 92 @ 11435' 10746 8800' SS PJC DRAFT 113-318" CSG, 72#, L-80, 10 = 12.347" I 2668' Minimum ID = 3.725" @ 10631' 4-1/2" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, 13-CR VAM TOP, .0152 bpf, 10 = 3.958" 10545' 14-1/2" TBG, 12.6#, L-80, .0152 bpt, 10 = 3.958" , 10642' PERFORA TION SUMMARY REF LOG: PRODUCTION LOG OF 05108195 ANGLE AT TOP PERF: 67 @ 10890' Note: Refer to Production DB tor historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 6 10890 - 10920 C 03/06196 3-3/8" 6 10972 - 11002 C 03/06196 3-3/8" 6 11012-11032 C 03106/96 4-1/2" SLTO 11189 -12567 C 05/03/95 4-1/2" SLTD 12603 - 13461 C 05/03195 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 11367' OA TE REV BY 04/01/86 05103195 LINDER 10/22106 D16 09/25/05 WTS/TL 10124/06 ? / PJC COMMENTS ORIGINAL COM PLETION SIDETRACK CMPLETION RWO XXN PLUG SET (05/23/04) ORLG DRAFT CORRECTIONS DATE Y-21A SAF OTES: OLD WB..LBORE NOT SHOWN ON DIAGRAM BELOW 9-518" SDTRKWINDOW. WELL EXCEEDS 70 DEG @ 11045' & GOES HORIZONTAL @ 11341', 2025' -14-112" HES X NIP, 10 - 3.8131 GAS LIFT MANDRELS ST MO lVO OEV TYPE VLV LATCH 5 3003 3002 7 MMG OCR RKP 4 5085 4766 39 MMG OMY RK 3 7088 6259 42 MMG OMY RK 2 8692 7510 36 MMG OMY RK 1 10338 8657 52 KBG2 OMY BK PORT DATE o 10/21/06 o 10/21/06 o 10/21/06 o 10/21/06 o 10/21/06 ~ TOP OF BKR TIEBACK SL V, 10 = 7.50" 9-5/8" X 7" BKR LNR TOP PKR, w/HYDSET HGR, 10=6.184" ...14-1/2" HES X NIP, 10 - 3.8131 ';1" ~~" x 4-112" BKR S-3 PKR, 10 = 3.870" ...14-112" HES X NIP, 10- 3.8131 ...1 TUBING STUB (TAGGED 10/17/06) I ...17" x 4-1/2" UNIQUE OVERSHOT I ...14-1/2" OTIS X NIP, 10 = 3.813" I 10597' ...17" X 4-112" BKR SAB-63 PKR, 10 = 3.875" ...14-1/2" OTIS X NIP, 10 = 3.813" I ~ 4-1/2" OTIS XN NIP, 10 = 3.725" , ...14-112" XXN PLUG (05123/04) I -14-1/2" WLEG, ID = 3.958" I H ELMO I 9-518" MILLOUT WINDOW (Y-21A) 9000' - 9050' --17" X 4-1/2" TrN SS HORZ PKR, 10 = 3.91" 7" LNR, 29#, NT80-S, .0371 bpf, 10 = 6.184" , : ' , ,I ~r IÎ~~~I " " " I PBTD I " ~ 13461' 14-1/2" SLTDLNR, 12,6#, L-80, .0152 bpf, 10=3.958" REV BY COMMENTS PRUDHOE BA Y UNfT WELL: Y-21A PERMfT No: '1950370 API No: 50-029-21574-01 1714' SNL & 240' WEL, Sec. 33, T11 N, R13E BP Exploration (Alaska) . . Y-21A DESCRIPTION OF WORK COMPLETED EVENT SUMMARY AWGRS 09/05/2006 T/I/O=41 0/190/5. Temp=SI. AL line blinded @ IA casing valve. Bleed WHP's to 0 psi. (Pre-PPPOT, Pre-RWO). Bled TBG from 490 psi to 120 psi in 45 minutes. lAP decreased 110 psi to 80 psi during TP bleed. Switch bleed to IA. Bled lAP from 80 psi to o psi in 1 hour. TP increased 10 psi to 130 psi during lAP bleed. Bled TBG from 130 psi to 0 psi in 3 hours. lAP increased to 10 psi during TP bleed. Bled lAP from 10 psi to 0 psi in 20 minutes. Bled OAP from 10 psi to 0 psi in 1 minute. Monitor for 15 minutes during rig down. No change in WHP's during rig down. Final WHP's=OIOIO. AWGRS 09/06/2006 T/lA/OA = SI/OIO (Pre-Rig Inspection) PPPOT-IC - Failed PPPOT-T - Passed Bled inner casing hanger void to 0 psi. Torqued lockdown screws to 500 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up void to 3,800 psi. for 30 mins. - Failed Bled tubing hanger void to 0 psi. Torqued lockdown screws to 500 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up void to 5,000 psi. for 30 mins. - Passed AWGRS 09/07/2006 *** WELL SHUT IN ON ARRIVAL *** (drift for chem cut, dump bail sluggits) DRIFT TO TOP OF 41/2" XXN PLUG @ 10609' SLM WI 3.75" CENT., & 3.50" LIB DUMPED (1) 50# BAG SLUGGITS ON XXN TTP @ 10603' SLM SD @ 9160' WI 3.50" x 10' D. BAILER, UNABLE TO WORK PAST. INADVERTANTL Y DUMPED BAILER ATTEMPT TO WORK OBSTRUCTION @ 9160' SLM. AWGRS 09/08/2006 TIIA/OA = SI/OIO (Attempt to energize "Y" seals on Packoff) PPPOT-IC = Passed Bled casing hanger void to 0 psi. Rigged up injection gun and pumped (3) sticks of Cameron packing. Tested packoff secondary "Y" seals. Clean fluid returns achieved. Pressured up to 3,800 psi. for 30 mins. -Passed AWGRS 09/08/2006 WORKED SLUGGITS FROM 9160' SLM DOWN TO TOP OF PLUG WI 4.5" BL BRUSH & 2.50" GAUGE RING DRIFTED TUBING WI 3.750" GAUGE RING, TAGGED SLUGGITS @ 10597' SLM (12' SLUGGITS ON PLUG) "''''''' LEFT WELL SHUT IN "''''''' AWGRS 09/18/2006 RIG UP FOR TUBING PUNCH. AWGRS 09/19/2006 TIIIO 5015010. RUN 1: SMALL TUBING PUNCH OVER INTERVAL 10,530-10,532 FT RUN 2: 2X12' STRING SHOT OVER INTERVAL 10,546-10,558 FT RUN 3: 3-5/8" CHEMICAL CUT OF 4-1/2" TUBING AT 10,556 FT TOOL "DISCONNECTED" BELOW BOTTOM CHEM TUBE. SEVERING HEAD AND BOTTOM CENTRALIZER LEFT DOWNHOLE. TOTAL LENGTH 2.6'. MAX OD = 3-5/8". HOLES IN BOTTOM CHEM TUBE, SOME SPLASHBACK OF CATALYST NOTICED ON LOWER CENTRALIZER. PICTURES TAKEN AND SENT TO PE. TAGGED SLUGGITS AT 10,612 FT ELM "'*'" JOB COMPLETE*"'''' AWGRS 09/20/2006 "'''''''WELL SHUT IN ON ARRIVAL"'*'" (PRE RWO) RUN 3.5" LIB TO 10537' SLM CURRENTLY PULLING SEVERING HEAD W/3.25 OVERSHOT. AWGRS 09/21/2006 (PRE RWO) RAN IN HOLE W/KJ, XO, 4- DOG OVERSHOT (3.7 OD) TO 10589'SLM RAN 3.00" DRIVE DOWN BAILER W/3.5" WIRE BRADED WIRE TRAP BOTTOM TO 10589'SLM RAN 10' 3.00" PUMP BAILER WI FLAPPER BOTTOM TO 10589'SLM RAN OBANNON OVERSHOT TO 10589'SLM RAN 3.5" LIB TO 10589'SLM RAN 3.6 CENT, .85" SPEAR TO 10589'SLM RAN 2.75 OD - 2.21 ID OVERSHOT TO 10589'SLM. Page 1 . . Y-21A DESCRIPTION OF WORK COMPLETED AWGRS 09/22/2006 (FISS CHEM. CUTTER PARTS) RAN MULTIPLE ASSORT. OF TOOL (SEE LOG) TO TRY AND FISH OUT CHEM. CUTTER / BOWSPRING CENT FROM 10589' SLM W/ NO SUCCESS. AWGRS 09/23/2006 (FISH OUT CHEM CUTTER HEAD RAN ASSORTMENT OF TOOLS TO TRY TO FISH OUT CHEM. CUTTER HEAD WITH NO SUCCESS. AWGRS 09/24/2006 (FISHING CHEM CUTTER TOOL) BAILED W/3.00 PUMP BAILER & 2 5/8" HYDROSTATIC BAILER BEFORE MAKING SEVERAL ATTEMPTS W/OVERSHOTS TO PULL CHEM. CUTTER. AWGRS 09/25/2006 (FISHING CHEM. CUTTER) RECOVERED E-LlNE SEVERING HEAD & CENTRILZER FROM 10,589' SLM ***WELL SHUT IN ON DEPARTURE*** AWGRS 09/25/2006 Y-21 well head ID for town engineer. MeCvoy SSH 4" Cameron tree with a 5 seal adapter. 4-1/2 TDS lift thread. Well head has Alemite external test fittings AWGRS 10/04/2006 T/I/O=200/200/0 Temp=SI MIT-OA 2000 psi ***PASSED*** (Pre-RWO) - Pressured up OA w/1. 7 bbls 60/40. OA lost 110 psi 1st 15 min. OA lost 50 psi 2nd 15 min. Pass, bled OAP. Circ-Out (Pre-RWO) - Pumped 10 bbl neat methanol spear, 1131 bbls seawater down tubing, taking returns up IA through cosasco loop to production. Freeze protected TxlA to 2500' by over displacing IA w/172 bbls 60/40 taking returns up tubing to production. Pumped down tubing w/38 bbls 60/40 taking returns up IA to production. Freeze Protected flow line w/30 bbls 60/40. CMIT TxlA 3500 psi *** PASSED*** Pressured up TxlA to 3500 psi w/ 8 bbls 60/40. T/IA lost 20/20 psi in 1st 15 min. T/IA lost 40/40 psi in 2nd 15 min. Bled all WHP's. Final WHP's= 0/0/0 DIMS 10/14/2006 RDMO C-07, MIRU to Y-21A DIMS 10/15/2006 MIRU on Y-21A, Pull BPV, Circ Freeze Protect & Displaced Well to Clean SW. N/D Adapter & Tree, N/U BOP. BOPE Test. DIMS 10/16/2006 Test BOPE, Pull Hanger, CBU, Pull 4.5" Tubing, M/U BHA, RIH DIMS 10/17/2006 Continue to P/U 4" DP f/Pipe Shed, Dress Off Tubing Stub at 10543', Pump Sweep, POOH, Attempt to Pull Pack Off Through BOPs, Run and Test RTTS, N/D BOPE, Repair LDS. DIMS 10/18/2006 DIMS 10/19/2006 DIMS 1 0/20/2006 DIMS 10/21/2006 Continued work on Well Head, N/U BOPE,Test Pack Off, Pull RTTS, M/U 3.625" Reverse Basket, RIH, Wash and Ream to XXN Plug at 10,613', Pump Sweep, POOH. LID Reverse Circ Basket, M/U GS Spear, RIH, Attempt to Latch and Pull XXN Plug, POOH, M/U Mule Shoe, RIH, POOH LID Drill Pipe. Continue to LID 4" Drill Pipe, R/U Tubing Handling Equipment, Run 4.5", 12.6#, 13Cr80, JFE Bear Completion. Continue Running 4.5", 12.6#, 13Cr80 JFE Bear Completion, Landed Tubing, Circulated in Corrosion Inhibited Sea Water, Set and Test Packer, Set TWC, N/D BOPE, N/U Production Tree and Tested Same Freeze Protect Well. Page 2 . . Y -21 A DESCRIPTION OF WORK COMPLETED DIMS 10/22/2006 U-Tube Well, Set and Test SPY, RID Circulating Equipment, Secure Well. Page 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-21 Y-21 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: Spud Date: 4/3/1986 End: 10/22/2006 10/15/2006 1 0/22/2006 10/14/2006 10:00 - 12:00 2.00 MOB P PRE 12:00 - 13:30 1.50 MOB P PRE 13:30 - 14:00 0.50 MOB P PRE 14:00 - 15:00 1.00 MOB P PRE 15:00 - 00:00 9.00 MOB P PRE 00:00 - 01 :00 1.00 MOB P PRE 01 :00 - 03:30 2.50 MOB P PRE 03:30 - 04:30 1.00 MOB P PRE 04:30 - 06:00 1.50 MOB P PRE 06:00 - 09:00 3.00 MOB P PRE 09:00 - 10:30 1.50 WHSUR P DECOMP 10:30 - 12:30 2.00 WHSUR P DECOMP 12:30 - 15:00 2.50 WHSUR P DECOMP 10/15/2006 15:00 - 17:00 2.00 WHSUR P DECOMP 17:00 - 19:00 2.00 WHSUR P DECOMP 19:00 - 21:00 2.00 WHSUR P DECOMP 21 :00 - 21 :30 0.50 BOPSU DECOMP 21 :30 - 00:00 2.50 BOPSU P DECOMP 10/16/2006 00:00 - 02:30 02:30 - 03:00 03:00 - 03:30 2.50 BOPSU P RID Rig Floor Bridle Up to UD Derrick Move Rig to Middle of Pad, Removed BOPs from Cellar. Prepare Derrick to UD. RlU Booster Tires, Front and Rear. Move Rig to Y-Pad. Move Rig Down Y-Pad Access Road. Lay Herculite, Set Rig Mats, Remove Booster Wheels Front and Rear, Install BOPs On Cellar Stand. PJSM RlU to and Raise Derrick. Move and Spot Rig on Y-21A RlU Number Two Pump and Motor Skid. Ready Floor and Cellar. P/U DSM Lubricator and Pull BPV. No Pressure on Tubing Side. Rig Down DSM Lubricator. Take on Seawater to Pits 3 & 4. Rig Accepted at 0900 hrs. Wait on bleed tank to arrive for OA. PJSM. Circulate well with 40 bbl high visc sweep and 650 bbls of 140 deg Seawater. Pump at 7 bpm and 550 psi. Noticed sweep come back early at - 325 bbls. Holes in tubing at - 4500'. Monitor Well and Confirm Dead. Set TWC and Test to 1000 psi below and 3500 psi above for 10 mins each. B/D and RID Circulating Hoses and Equipment. Bleed off control lines, Nipple Down Production Tree and Adapter Flange, Check Thread in Hanger --- 4-1/2" TDS. N/U BOPE. RlU to Test BOPE Test BOPE to 250 psi Low and 3,500 psi High. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by John Crisp. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1-Annular, HCR Choke, HCR Kill, 4" TIW Valve. Test #2- Manual Choke, Manual Kill, Dart Valve 4 ". Test #3- Choke Valves 1,12, 13, 14 Test #4- Choke Valves 9, 11, Blind Rams, Upper IBOP. Test #5-Choke Valves 5,8,10, Lower IBOP Test #6- Choke Valves, 4,6,7. Test #7- Choke Valves 2. DECOMP Continue to test BOPE Test #8- Choke Valve #3. Test #9- Lower Rams (VBR's) with 4". Test #10- Lower Rams (VBR's) with 4.5" tbg. Accumulater Test- 3000 psi Starting Pressure, 1900 psi After Actuation, First 200 psi in 15 seconds, Full Pressure in 1 Minute 14 Seconds. 5 Nitrogen Bottles at 2,200 psi. DECOMP RlU Tbg Handling Equipment and Control Line Spooling Unit, RlU Lubricator Extension. DECOMP Service Top Drive and Draworks wait on DSM. 0.50 PULL P 0.50 PULL P Printed: 10/25/2006 10:01 :04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-21 Y-21 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 1 0/15/2006 1 0/22/2006 Spud Date: 4/3/1986 End: 10/22/2006 10/16/2006 03:30 - 04:30 1.00 PULL P DECOMP P/U DSM Lubricator and Pull TWC. UD DSM Lubricator. 04:30 - 05:00 0.50 PULL P DECOMP M/U 4-1/2" TDS XO to Joint of DP. Run in and engage hanger. 05:00 - 06:00 1.00 PULL P DECOMP Check for pressure, BOLDS, pull hanger to the floor. 130K to get hanger off seat, P/U wt = 150K. 06:00 - 07:00 1.00 PULL P OECOMP Circ Btms Up at 10 bpm and 470 psi. 07:00 - 18:00 11.00 PULL P DECOMP PJSM, BIO and BID Top Drive. POOH and UD 4-1/2" L-80 NSCT Tbg. Recovered 249 jts + Cut Jt 23.44", 6 GLMs and 1 SSSV, and 56 Control Line Bands. 18:00 - 19:00 1.00 PULL P OECOMP RID Tubing Handling Equipment, Clear and Clean Rig Floor. 19:00 - 19:30 0.50 PULL P DECOMP Set Wear Ring. 19:30 - 00:00 4.50 PULL P DECOMP P/U M/U BHA #1. BHA consists of 6"x4.5" Shoe, XO, 2-Extendsions, Triple Connect, XO, 3 - 4 3/4" Boot Baskets, 7" csg Scraper, XO, Bowen Bumper Jar, Bowen Oil Jar, 9 - 4 3/4" Drill Collars, XO, 47 jts Drill Pipe, XO, XO, 95/8" csg Scraper, XO, XO. BHA Length = 1843.22' 10/17/2006 00:00 - 07:30 7.50 CLEAN P DECOMP P/U 4" HT-38 Drill Pipe from Pipe Shed. 07:30 - 09:00 1.50 CLEAN P DECOMP Obtain Initial Drilling Parameters. P/U Wt = 180K, SIO Wt = 160K, Rot Wt = 172K Pump Rate 4 bpm at 550 psi. Tag Tubing Stub at 10543' and No Go with Overshot at 10553', All Drill Pipe Measure, Dress Off Stub as per Baker Fishing wI up to 10K Wt on Mill to confirm all the way down. Confirm Slide over stub 2 times wI no pumps or rotation. 09:00 - 10:00 1.00 CLEAN P DECOMP Pump 40 bbl High Visc Sweep and Circulate around at 10 bbl per min and 2600 psi. 10:00 - 15:00 5.00 CLEAN P DECOMP Monitor Well,B/O and BID Top Drive. POOH and Stand Back DP. 15:00 - 16:00 1.00 CLEAN P DECOMP UD 7" Scraper and Dress Off Assembly. 16:00 - 16:30 0.50 CLEAN P DECOMP Drain Stack and Pull Wear Ring. 16:30 - 18:00 1.50 WHSUR P DECOMP M/U Running Tool and Latch Pack Off and BOLDs. One Lock Down Broke wlBacking Out. Release Running Tool and UD Same. 18:00 - 18:30 0.50 WHSUR P DECOMP P/U and Install Wear Ring. Clear and Clean Rig Floor. 18:30 - 19:30 1.00 WHSUR P DECOMP RIH wlMule Shoe tJ1 ,442'. M/U RTTS and Storm Valve RIH to 36' Took Weight. 19:30 - 20:00 0.50 WHSUR P OECOMP POOH w/RTTS Rubber Elements Rolled up on Mandrel. Repositioned Rubber Elements on Rig Floor. 20:00 - 21 :30 1.50 WHSUR P DECOMP RIH to 60' and Set RTTS. Tested to 1,000 psi from Below and 3,500 psi f/Above. UD Running Tool. 21 :30 - 22:30 1.00 WHSUR P DECOMP N/D BOPE. 22:30 - 00:00 1.50 WHSUR P DECOMP Grind and Repair Lock Down Screw 10/18/2006 00:00 - 04:00 4.00 WHSUR P DECOMP Continue to Work on LDS, Install 2 Blanks,and One New LDS Assembly. Install New 9 5/8" Pack off. 04:00 - 05:00 1.00 WHSUR P DECOMP N/U BOP Stack. 05:00 - 06:30 1.50 WHSUR P OECOMP RlU and Test Pack Off to 5,000 psi for 30 minutes. 06:30 - 07:00 0.50 WHSUR P DECOMP RlU and Test Casing Spool Connection to 3,500 psi for 10 minutes on Chart Recorder. 07:00 - 07:30 0.50 WHSUR P DECOMP P/U RTTS Running Tool and RIH to 60', Release RTTS and POOH, U D RTTS. 07:30 - 08:30 1.00 WHSUR P DECOMP POOH w/16 std Drill Pipe and UD Mule Shoe. 08:30 - 09:00 0.50 CLEAN P DECOMP RlU 2 7/8" Handling Equipment, Prepare BHA. 09:00 - 11 :00 2.00 CLEAN P DECOMP M/U 3 5/8" Reverse Basket BHA. BHA Consist of 3 5/8" Reverse Basket, XO, 4 jts 2 7/8" Pac DP, XO, XO, 3-43/4" Printed: 1 0/25/2006 10:01 :04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-21 Y-21 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 1 0/15/2006 10/22/2006 Spud Date: 4/3/1986 End: 10/22/2006 10/18/2006 09:00 - 11 :00 2.00 CLEAN P OECOMP Boot Baskets, XO, Bowen Bumper Jar, Bowen Jar, 9-4 3/4" Drill Collars, XO. BHA Lenght = 443.34' 11 :00 - 12:30 1.50 CLEAN P OECOMP RIH t/ 3,350', 12:30 - 13:00 0.50 CLEAN P DECOMP Kick While Tripping Drill, and Safety Discussion. 13:00 - 14:00 1.00 CLEAN P OECOMP Continue t/RIH to 8,100'. 14:00 - 14:30 0.50 CLEAN P DECOMP Service Top Drive, Iron Roughneck, and Draworks. 14:30 - 15:30 1.00 CLEAN P DECOMP Continue to RIH t/10,509' 15:30 - 17:00 1.50 CLEAN P DECOMP Obtain Parameters, Up Weight=180,000#, Down Weight=157,OOO#, Rotating Weight=172,OOO#, 40 rpm, 4,500 ft-Ibs Torque, 3.5 bpm w/610 psi. Tag Tubing Stub at 10,550' Tagged Slugets at 10,594', Washed and Reamed to 10,613' Drill Pipe Measurement 17:00 - 17:30 0.50 CLEAN P DECOMP Drop Ball and Open Reverse Circulating Tool and Circulated Down to 10,613'. 17:30 - 20:00 2.50 CLEAN P DECOMP Pumped 20 bbl Sweep at 5 bpm w/1800 psi, Monitor Well Pump Dry Job 20:00 - 23:00 3.00 CLEAN P DECOMP POOH 23:00 - 00:00 1.00 CLEAN P DECOMP Handle BHA 10/19/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Clean and Lay Down Reverse Circ Basket and Boot Baskets. Reverse Basket Had One Piece of Metal Shaving. Boot Basket had Some Slugets and Some Pipe Scale. 01 :00 - 02:30 1.50 CLEAN P DECOMP Clear and Clean Rig Floor, Make Up GS Spear Assembly. 02:30 - 05:00 2.50 CLEAN P DECOMP RIH to 8,000' 05:00 - 06:00 1.00 CLEAN P DECOMP Cut and Slip Drilling Line 06:00 - 06:30 0.50 DHB P DECOMP Obtain Parameters and SPA. Up Weight-182,OOO#, Down Weight=152,OOO#. 06:30 - 07:30 1.00 DHB P DECOMP Washed Down to Top of Plug at 10,613', At 3.5 bpm w/1300 psi. Pump Pressure Increase to 1,650 psi, Shut Down Pumps, Stacked 5,000# Down Weight. P/U and Slack off to 10,000# Down Weight and Repeat 2X With 2,000# Additional Up Weight. 07:30 - 09:00 1.50 DHB P DECOMP Monitor Well Researched Plug History, No Clear Indication of Latch on Plug. 09:00 - 09:30 0.50 DHB P DECOMP RIH Pumps Off To 10,613', Stacked 10,000# Down Weight and Held In Place for 5 Minutes, POOH to Top of 4.5" Tubing Stub at10,550', Monitor Well For 5 minutes. 09:30 - 13:30 4.00 OHB P DECOMP POOH Stand Back 4" Drill Pipe. 13:30 - 15:00 1.50 DHB P OECOMP UD BHA 15:00 - 15:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor 15:30 - 19:00 3.50 CLEAN P DECOMP M/U Mule Shoe and RIH to 10,261' 19:00 - 19:30 0.50 CLEAN P DECOMP POOH f/10,261 to 9,969'. UD Drill Pipe. 19:30 - 20:30 1.00 CLEAN P DECOMP Rig Service, Iron Roughneck, Pipe Skate, Top Drive. 20:30 - 22:00 1.50 CLEAN P DECOMP Repair Iron Roughneck 22:00 - 00:00 2.00 CLEAN P DECOMP Continue to UD Drill Pipe f/9,969'. 10/20/2006 00:00 - 06:00 6.00 CLEAN P DECOMP POOH UD Drill Pipe f/8'500'. 06:00 - 06:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor, Pull Wear Ring. 06:30 - 07:30 1.00 RUNCO RUNCMP R/U Tubing Handling Equipment. 07:30 - 09:30 2.00 RUNCO RREP RUNCMP Repairing Stabing Board Winch. 09:30 - 00:00 14.50 RUNCO RUNCMP Run 4.5" 12.6#, 13CR-80, JFE Bear Tubing. Use Jet Lube Seal Guard Pipe Dope. Average MIU Torque 4,500 ftllbs. 208 jts of 4.5",12.6#, 13Cr80, JFE Bear Tbg, 1 Unique 9.625" x 4.5" Overshot,1-jt 4.5",12.6# 13Cr80, Vam Top Tbg, 1- 4.5" X Nipple wI RHC, Baker 9.625" x 4.5" S-3 9Cr Pkr, X Nipple, 5 Printed: 10/25/2006 10:01 :04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-21 V-21 WORKOVER DOVON DRILLING INC. DOVON16 Start: Rig Rel~ase: Rig Number: I 10/15/2006 1 0/22/2006 Spud Date: 4/3/1986 End: 10/22/2006 GL~'S , DCR Shear Valve in top Station, and 1 X Nipple at 20a1'. 10/21/2006 00:00 - 02:30 2.50 RUNCMP Ru~ 4.5" 12.6#, 13CR-80, JFE Bear Tubing. Use Jet Lube Seal I Guard Pipe Dope. Average M/U Torque 4,500 ft/lbs. 256 jts of 4.5'1, 12.6#, 13Cr80, JFE Bear Tbg, 1 Unique 9.625" x 4.5" Ov~rshot, 1-jt 4.5",12.6# 13Cr80, Vam Top Tbg, 1- 4.5" X Nipple wI RHC, Baker 9.625" x 4.5" S-3 9Cr Pkr, X Nipple, 5 GÜ~'s , DCR Shear Valve in top Station, and 1 X Nipple at 202~'. 02:30 - 03:30 1.00 RUNCO RUNCMP M/~ K-Bear to Vam Top XO, M/U 3 jts Vam Top Tubing to englige Unique Overshot. Parameters: Up Weight 148,000#, Do~n Weight 128,000#, Indications of Overshot going Over TUbing Stub at 10,550'. Slacked Off to 10,553' Increasing Weiþht in 5,000# Increments to 20,000# No Indication of Shl' P"'''' Up sod Repeated 3X Wüh No "dioati", of She r. 03:30 - 04:30 1.00 RUNCO RUNCMP RlU Circulating Equipment, Began Pumping at 2 bpm w/80 psi. Sla~ked Off to 10,550 Pump Pressure Increase as Overshot was Engaged. Slacked off To 10,553' Pump Pressure Increase to 1 $0 psi. Continued to Slack Off with No Indication of Shear to 1Ø,558' Pump Pressure Increased to 500 psi. Reconfirmed Spa~e Out 3X With Same Results. 04:30 - 05:30 1.00 RUNCO RUNCMP UD $ jts Vam Top Tubing, RID Circulating Equipment. 05:30 - 07:30 2.00 RUNCO RUNCMP M/U !Space Out Pups = 39.38' in Length. And One jt Vam Top TUbihg, Land Tubing in Tubing Spool. 07:30 - 08:00 0.50 WHSUR P RUNCMP Run Iln Lock Down Screws in Tubing Hanger 08:00 - 13:00 5.00 WHSUR P RUNCMP R1"'" in 250 bbl, 140 deg Clean Sea Wete" Followed By 515 bls140 deg Sea Water with Corrosion Inhibitor. Pumped at 3 pm w/360 psi. UD Tubing Handling Equipment and Tubi~g Tongs. 13:00 - 14:30 1.50 WHSUR P RUNCMP Set ljIacker, Increase Pressure to 3,500 psi and Test Tubing f/30 ~inutes, Bled Pressure to 1,750 on Tubing. Pumped Down Ann Ius to 3,500 psi and Held Pressure f/30 Minutes Good Test$. Bled Off Tubing Pressure to 0 psi and Opened DCR Valv¡j¡ and Pumped Down Tubing and Annulus wlGood Flow. UD 4anding jt. 14:30 - 15:30 1.00 WHSUR P RUNCMP Set ~nd Tested TWC to 1,000 psi f/Below and 3,500 psi f/Abdve and Charted. 15:30 - 16:30 1.00 WHSUR P RUNCMP NID $OPE 16:30 - 18:00 1.50 WHSUR P RUNCMP prepte Well Head, Nipple Up Tree and Adapter Flange 18:00 - 19:00 1.00 WHSUR P RUNCMP Test I dapter Flange to 5,000 psi. 19:00 - 21 :00 2.00 WHSUR P RUNCMP Test Production Tree, Flange Leaked on Swab Valve, Torqued Flange Bolt and Retest Tree to 5,000 psi. Difficulty Working Air Out qf Tree for Good Pressure Test. 21 :00 - 21 :30 0.50 WHSUR P RUNCMP RlU IDSM and Pull Two Way Check, RID DSM. 21 :30 - 23:30 2.00 WHSUR P RUNCMP RlU Uittle Red Services, Test Lines to 2,500 psi. Pump 140 bbl of Ditel Freeze Protect at 2 bpm w/615 psi 23:30 - 00:00 0.50 WHSUR P RUNCMP U-tub. Well. 10/22/2006 00:00 - 01 :00 1.00 WHSUR P RUNCMP Contitue To U-Tube Well. 01 :00 - 02:00 1.00 WHSUR P RUNCMP Set ~V, Test to 1,000 psi Good Test. 02:00 - 03:00 1.00 WHSUR P RUNCMP BID D Surface Lines, RID Secondary Annulus Valve, Secure Well. Rig Release at 03:00 on 10/22/06 'I ! Printed: 10/25/2006 10:01 :04 AM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001, M PL ATE IA L U N D W E R TH IS M ARK ER DATA 95'-~03'? PL8 STATIC ,- L' 10..55,5 .... 110'i9 95--037 PL.S/TEHP ,..."E 8680 ...../ 1083 95'-037 NGP .:.L-7766---90~0 'FVI.}, 9,5-037 ROP/NGP/DGR/EWF:a. '..L 9000 13.500 GR/(2CL '-L' SEPIA 674. i -' T 10'~',!~07 .:. R COVIF'LETION DAI'E z. DAIL. Y WEI..I.. OPS .'i4 ,:,/ , , / /' Ar"e dr'y d'i't, ch sampies r'equ'i,'eq' '~. y e s ( n o A iq d r' e c e 'i: v e: ~..l ,, y e s i"~ o .- ~ ~,,!as the we-ii cor"ed~ C C, H h'1 E N 'r'g n O R e c e i' v e d "? y e s ri o LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ~NCHORAGE AK, 99501. Date: 11 March 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please =ind the data as described below: WELL # DESCRIPTION ! PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF Run # 1 Run # 1 ECC No. 6189.02 6425.01 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 r AnChorage, AK 99518 FAX to (907) 563-7803 ~ Date: AnchoF~e, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 95-37 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 $o-029-21574-01 4. Location of well at surface ~.~,~,~ ........ 9. Unit or Lease Name 1417'SNL, 24O' WEL, SEC. 33, T11N, R13E 254' SNL, 3115' WEL, SEC. 4, TION, R13E ..... ~ )' Y-21A At Total Depth ~. ,4¢.,~_.~L_ .... ~ Prudhoe Bay Field/Prudhoe Bay Pool 993' SNL, 5266' WEL, SEC. 4, TION, R13E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 82. 71 I ADL 047471 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 04/16/95 04/27/95 05/03/95I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13500'MD/9030' TVD 13500'MD/9030' TVD YES [] NO []I 2196feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, L WD, GR, RES 23. CASING, UNER AND CEMENTING RECORD SETTING DEFTH MD CASING SIZE WT. PER Ft. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Cond. Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2668' 17-1/2" 3720 cu ft Permafrost 'E' 9-5/8" 4 7# L-80 Surface 5118' 12-1/4" 9-5/8" 4 7# L-80 5118' 9000' 12-1/4" 897 cu ft Class 'G' 7" 29# NT-80S 8823' 11200' 8-1/2" 535 cuft Class 'G' 4-1/2" 12.6# L-80 11056' 13485' 6" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2" 10644' 10597' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11189'- 12567' 9022'- 9020' Freeze Protect with 155 Bbls Dry Crude 12603'- 13461' 9020'- 9028' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) May2, 1995 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. FE8 1 6 l~gG Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate -'9. 30. GEOLOGIC MARKERS ~-ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 10867' 8931' Shublik 10912' 8949' Sadlerochit 11220' 9025' 31. LIST OF A'FI'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title $~nior Drilling Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 FEB 1 1°J96 :?;,~ Cons. Cerr~mi,'-::-~ion , · . . _ .£ BP/AAI SHARED SERVICE DAILY OPERATIONb PAGE: 1 WELL: Y-21A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/11/95 05:00 SPUD: RELEASE: 05/03/95 10:00 OPERATION: DRLG RIG: NABORS 28E WO/C RIG: 04/11/95 ( 1) TD: 0' ( 0) 04/12/95 ( 2) TD:11035' (11035) 04/13/95 ( 3) TD: 9765' ( 0) 04/14/95 ( 4) TD: 9250' ( 0) MOVING RIG MW: 0.0 VIS: 0 RIG DOWN, BLOW DOWN STEAM LINES, LOWER DERRICK, BREAK COMPLEXES. MOVE RIG OFF WELL. PREPARE FOR MOVE TO Y-PAD. RIGGED UP KELLY MW: 0.0 VIS: 0 MOVE RIG P-PAD TO N-PAD. LAY DOWN A-LEGS, WAIT ON SECURITY. CONTINUE MOVE RIG N-PAD TO Y-PAD. ON LOCATION @ 1700 HRS 04/11/95. SPOT SUBSTRUCTURE OVER WELL Y-21, SPOT MOTOR COMPLEX. RAISE DERRICK, RAISE WINDWALLS. SPOT PIT COMPLEX. HOOK UP SERVICE LINES. TAKE ON SEAWATER AND FUEL. RIG UP DRILL FLOOR, P/U KELLY. POH L/D TBG MW: 0.0 VIS: 0 MOVE RIG. RIGGED UP DRILLFLOOR/DERRICK. RIG ACCEPTED @ 0600 HRS ON 04/12/95. R/U CELLAR AND FLOOR, CONNECTED CHOKE LINE. INSTALLED ACCESSORIES. EQPT WORK COMPLETED, RUNNING TOOL RETRIEVED. TESTED 9 5/8" PACKOFF. FAILED TO TEST. WILL NEED TO BE REPLACED LATER. CIRCULATED CSG W. SEA WATER UNTIL RETURNS CLEANED UP. REVERSE THE LAST CIRC. R/D LINES. INSTALLED TWO WAY CHECK VALVE. TWO WAY CHECK IN PLACE. RIGGED UP BOP STACK. TESTED BOP EXCEPT BTM PIPE RAM, CHOKE MANIFOLD. WILL TEST BTM RAM AND KELLY AFTER PULLING TBG. PULLED HGR TO FLOOR W/ 105K#. SPOOLED CONTROL LINE. POH L/D TBG. CHANGING 9 5/8" PACKOFF MW: 0.0 VIS: 0 LAID DOWN TUBING TO 9765'. TIGHT CONNECTIONS. NO EVIDENT CORROSION. MOTICABLE PARAFFIN. L/D TONGS AND CLEARED FLOOR. 300 JTS LAID OUT. 7 GLM'S, 1 SSSV, 32 CLAMPS, 4 BANDS. CUT JT IMMEDIATELY BELOW 7TH GLM. JT # WILL BE VERIFIED ON LOAD OUT. TESTED BTM RAMS, KELLY, IBOP, TIW. TESTED BOP STACK. RAN EZSV ON 5" DP IN 9 5/8" 47# CSG. SET PACKER @ 9250' P/U WT + 200K, S/O WT + 175K. TESTED CASING. CIRCULATED.' DISPLACED W/ 9.9 PPG MUD, AND SPOTTED 12 BBL 18 PPG PILL ON TOP OF EZSV. PULLED DRILLPIPE IN STANDS TO 9250' INSTALLED CASING HANGER AND SEAL ASSEMBLY RUNNING TOOL. ~HANGING 9 5/8" PACKOFF. WELL ' Y-21A OPERATION: RIG : NABORS 28E PAGE: 2 04/15/95 ( 5) TD: 9250' ( 0) 04/16/95 (6) TD: 9250' ( 0) 04/17/95 ( 7) TD:10026' ( 776) 04/18/95 ( 8) TD:10464' ( 438) CHANGE 9-5/8" PACKOFF MW: 0.0 VIS: 0 LD TBG T/9765. TIGHT CONNECTIONS. NO EVIDENT CORROSION. NOTICABLE PARAFFIN. LD TONGS & CLEARED FLOOR. LD 7 GLM'S; 1 SSSV; 32 CLAMPS; 4 BANDS; CUT JT BELOW THE 7TH GLM. TESTED BTTM RAMS, KELLY, IBOP & TIW. WITNESS WAIVED BY AOGCC. PRESS TEST OK @5000PSI. RAN EZSV ON 5" DP IN 9-5/8" 47# CASG. SET PACKER @9250. SET EZSV IN 10K INCREMENTS. 60K T/SHEAR OFF. WT TESTED 15K. TESTED CASG VIA STRING. PRESS TEST OK @3500PSI. CIRC @9250. DISPLACED W/9.9 PPG MUD & SPOTTED 12 BBLS 18PPG PILL ON TOP OF EZSV. OBTAINED 100% HOLE VOL. PULLED DP IN STANDS T/9250. INSTALLED CASING HANGER & SEAL ASSY RUNNING TOOL. CHANGE THE 9-5/8" PACKOFF. DRILL T/9010 MW: 0.0 VIS: 0 FINISH CHANGING THE 9-5/8" PACKOFF. TEST T/5000. RAN WEAR RING. MU BHA #1. SERVCO 8.5" 6 BLADED SECTION MILL. RIH T/9000. STOP @ WINDOW DEPTH & MILL. CUT WINDOW F/9000 T/9050. HAD CMT F/9025 T/9050. CIRC. OBTAINED 300% HLE VOL. CIRC UNTIL NO METAL WAS OBSERVED. POOH T/834. PULL BHA. LD SECTION MILL. PU 5" DP MULE SHOE. & RIH T/9150, PLUG SETTING DEPTH. BROKE CIRC 3X DURING TIH. CIRC WHILE BJ MIXED CMT. OBTAINED 100% ANNUL. VOL ON BU. BJ PUMPED 5 BBLS H20, TESTED LINES T/3000, FOLLOWED BY 15 BBLS H20. BJ PUMPED 36.22 BBLS OF 17P?G CMT FOLLOWED BY 7 BBLS H20. CIRC 2 9150. RIG PUMPED 141 BBLS OF 9.7 PPG MUD T/BALANCE PLUG. HOLE DISPLACED W/WATER, 100%. POOH 14 STDS. CIRC @7848. 1 DP VOL. HESITATE SQUEEZED T/2000 PSI. NO INDICATION OF WINDOW TAKING CMT. HELD F/1 HR. STOP T/CONDUCT PRESS TEST. PULLED BHA. CIRC @ 0'. FLUSHED BOPE W/STINGER. OBTAINED 100% CLEAN RETURNS F/HOLE. MU BHA #2. CUT & SLIP LINE. TIH T/8600. BROKE CIRC EVER 1500'. WASHED 8600 T/8765. TAGGED GREEN CMT @8765. DRILLED SOFT CMT F/8765 T/8910. WOC. WASHED F/8910 T/9002. FIRM CMT. STARTED T/SLIDE @9010. DRILLING MW: 0.0 VIS: 0 DRILLED T/9996. SLID 5.75 HRS & ROTATED 10.75 HRS. PUMPED SEVERAL SWEEPS. STOPPED DRILLING F/SHORT TRIP HALF-WAY THROUGH THE KINGAK FORMATION. POOH T/8960. SHORT TRIP INTO THE WINDOW. HOLE IN GOOD SHAPE. RIH T/9996. DRILLED T/10026. RIH TO 10465' MW: 0.0 VIS: 0 DRILLED TO 10464' STOPPED DRILLING W/ BHA #2 DUE TO HIGH BIT HOURS AND SLECTION TO START #2 K/O. CIRCULATE @ 10464' OBTAINED CLEAN RETURNS. PULLED BHA. OPEN HOLE IN GOOD SHAPE. WINDOW WAS SMOOTH. MADE UP BHA #3. SERVICED WEAR RING. M/U BHA #3. RIH TO 10465' FEB ] 6 ]996 ~":~ '?'-~ Cons. Commi~sion WELL : Y-21A OPERATION: RIG : NABORS 28E PAGE: 3 04/19/95 ( 9) TD:10965' ( 501) 04/20/95 (10) TD:l1200' ( 235) 04/21/95 (11) TD:ll200' ( 0) 04/22/95 (12) TD:ll200' ( 0) 04/23/95 (13) TD:l1890' ( 690) DRILLING MW: 0.0 VIS: 0 RIH T/10217. THE HOLE IS TIGHT & PACKING OFF. REAMED F/10217 T/10464. CLEAN HOLE. ABLE TO KEEP HOLE OPEN. DIRECTIONAL DRILLING T/2ND K/O POINT W/SS MOTOR. K/O & MAINTAINED PLANNED ANGLE & DIRECTION. GEO MARKERS APPEARED T/BE 40-HIGH, BUT LATER CONFIRMED THAT THE WEREN'T. ~9042 HORIZONTAL TARGET. CROSSED FAULT ~120' SOUTH OF PREDICTION. ICLINATION TOOL IS NOT WORKING. RIH TO 9000' MW: 0.0 VIS: 0 DRILLED TO 11077'. POH TO 10464'. RIH TO 11077'. DRILLED TO 11200'_ CIRCULATE. OBTAINED BOTTOMS UP__PUMP PILL -- POH TO 1390'. PULLED BHA. BHA LAID OUT. MADE UP BHA #4. RIH TO 9000'. REVERSE CIRC MW: 0.0 VIS: 0 RIH TO 10593'. REAMED FROM 10593 - 10748', AND 11000 - 11200'. CIRCULATED. OBTAINED BOTTOMS UP. LAY DOWN 34 JTS DP. POH TO 1390'. PULLED BHA. BHA LAID OUT. RIGGED UP TOP RAM. CHANGE TO 7" TEST DOORS. RIGGED UP CASING HANDLING EQUIPMENT. RAN CASING TO 2360'. CIRCULATED. OBTAINED BOTTOMS UP. RAN DRILLPIPE IN STANDS TO 11200' LAST 4-' TOOK WEIGHT. CIRCUALTED @ 11200'_ SLURRY WAS BATCH MIXED WHILE WE WERE CIRC. PUMPED spACERS. PUMPED 5 BBL WATER TEST LINES, OK. PUMPED 15 BBL WATER FOLLOWED BY 70 BBL SPACER. MIXED AND PUMPED SLURRY. RELEASED DART. DISPLACED SLURRY. PLUG BUMPED. TESTED CASING. SET PACKER, SET HANGER. REVERSE CIRCULATED @ 8842'. DRILLING CEMENT MW: 0.0 VIS: 0 REVERSE CIRCULATE @ 8842' TOTAL OF 2 BOTTOMS UPS HAD 1-1 1/2 BBLS OF CEMENT RETURNS. LAID DOWN DRILLPIPE IN STAND. RIGGED UP TOP RAMS. CHANGE TO 3 X 6 VERABLES. TESTED ALL RAMS. TESTED ANNULAR PREVENTOR. TESTED CHOKE MANIFOLD. TESTED KELLY COCKS. INSTALLED BORE PROTECTOR. CLEAN UP RIG FLOOR. MADE UP BHA #4. SINGLED IN DRILL PIPE TO 1000' MAKE UP 13 JTS NEW HYDRILL DRILL PIPE. TESTED EMSS. SINGLED IN DRILL PIPE TO 4938' 63 JOINTS PICKED UP. RIH TO 11000'. TESTED CASING. DRILLED CEMENT TO 11073' DRILL & SLIDE MW: 0.0 VIS: 0 DRILLED CEMENT TO 11203' PLUS 3' OF NEW HOLE. CIRCUALTE @ 11203'. CHANGE MUD OVER TO FLO-PRO, MADE LOGGING PASS FOR BASELINE WITH NEW MUD. OBTAINED BOTTOMS UP.DRILLED TO 11890'. i Oh_.:ivED WELL : Y-21A OPERATION: RIG . : NABORS 28E PAGE: 4 04/24/95 (14) TD:12222'( 332) 04/25/95 (15) TD:12530'( 308) 04/26/95 (16) TD:12806' ( 276) 04/27/95 (17) TD:13438' ( 632) 04/28/95 (18) TD:13500' ( 62) 04/29/95 (19) TD:13500' ( 0) RIH TO 11330' MW: 0.0 VIS: 0 DRILLED TO 12222'. CIRCULATE. OBTAINED BOTTOMS UP. FLOW CHECK. OBSERVED WELL STATIC. POH TO 91' DOWNLOADED MWD TOOL. PULLED BHA. BHA LAID OUT. MADE UP BHA #5. MAKE UP MEDIUM SPEED MOTOR. SERVICE WEAR BUSHING. RIH TO 6500'. CUT 104' DRILLING LINE. LINE SLIPPED AND CUT. RIH TO 11330' DRILLING MW: 0.0 VIS: 0 CIRCULATE @ 11276'. DRILLED TO 12366'. EMSS FAILED. END BHA RUN. CIRCUALTE @ 12366'. OBTAINED BOTTOMS UP. FLOW CHECK. OBSERVED WELL STATIC. POH TO 92' DOWNLOADED MWD TOOL. MADE UP BHA #6. CHANGE OUT MWD CHANGE MEDIUM SPEED MOTOR PICK UP ROLLER CONE BIT. FUNCTIONED DOWNHOLE TOOLS @ 2100'. RIH TO 12360'. LOGGED HOLE WITH LWD. FORMATION EVALUATION FROM 12360 - 12366'.. DRILLED TO 12530'. INSTALL BORE PROTECTOR MW: 0.0 VIS: 0 DRILLED TO 12806'. CIRCULATE @ 12806' OBTAINED BOTTOMS UP. FLOW CHECK. OBSERVED WELL STATICl POH TO 90'. PULLED BHA. BHA LAID OUT. CHANGE OUT MOTOR STATOR RUBBER FOUND IN BIT. DOWNLOADED MWD TOOL. MADE UP BHA #7. MAKE UP NEW MOTOR AND ORIENT SAME. INSTALLED BORE PROTECTOR. DRILLING MW: 0.0 VIS: 0 REPAIRED SPINNER. RIH TO 6500'. REPAIRED DRAW WORKS. RIH TO 11200'. RIH TO 12806'. BENCHMARK SURVEY @ 11659', OK. DRILLED TO 13438'. REAMED TO 12200' MW: 0.0 VIS: 0 DRILLED TO 13500'. CIRCULATED AT 13500'. OBTAINED BOTTOMS UP. FLOW CHECK. OBSERVED WELL STATIC. POH TO 8800' STOPPED TO PICK UP LAY OUT TUBULARS. LAID DOWN DRILL PIPE TO 2400' 66 JOINTS LAID OUT. POH TO 90' DOWNLOADED MWD TOOL. PULLED BHA. BHA LAID OUT. MADE UP BHA #8. CUT 104' DRILLING LINE. LINE SLIPPED AND CUT. RIH TO 11200'. REAMED TO 12200' TRIP MW: 0.0 VIS: 0 REAMED TO 13500'. CIRCUALTED. OBTAINED CLEAN RETURNS. CIRCUALTED. LCM PILL SPOTTED DOWNHOLE, LCM CONTENET 3.0 LD/BBL. POH TO 11200'. CIRCULATED. HEAVY SLUG SPOTTED DOWNHOLE. POH TO 250'. PULLED BHA. BHA LAID OUT. RIGGED UP TUBING HANDLING EQUIPMENT. RAN CASING TO 2400'. 2 1/16" TUBING INSIDE 4.5 CASING, INSTALL TIW PACKER. RAN DRILLPIPE IN STANDS TO 3500'. TRIP IN 4 1/2" LINER. WELL : Y-21A OPERATION: RIG : NABORS 28E PAGE: 5 04/30/95 (20) TD:13500' ( 0) 05/01/95 (21) TD:13500' ( 0) 05/02/95 (22) TD:13500' ( 0) MAKE UP BHA #9 MW: 0.0 VIS: 0 RAN DRILLPIPE IN STANDS TO 11200' CIRCULATED @ 11200' OBTAINED BOTTOMS UP. RAN CASING IN STANDS TO 13465'. CIRCULATED @ 13485'. WASH LINER TO BOTTOM @ 13500'_ SPACE LINER OUT AT 13485'. DROPPED BALL. CIRCULATED @ 13485'. PACKER SET @ 13485'. BALL LANDED PRESSURE UP IN STAGES. BALL SEAT SHEARED PRESSURE DROPPED. BACK SIDE TO 3500' _ OK RELEASE FROM LINER WITH 24 TURNS. CIRCULATED @ 13475'. DISPLACE WITH SEA WATER. PULLED DRILLPIPE IN STANDS TO 11056'. CIRCULATED. HOLE DISPLACED WITH SEAWATER. PULLED DRILLPIPE IN STANDS TO 2400'. LAY DOWN 2 1/16" INNER STRING AND TIW SETTING TOOLS. RETRIEVED BORE PROTECTOR. INSTALLED BOP TEST PLUG ASSEMBLY. TESTED ALL RAMS. TESTED ANNULAR PREVENTOR. TESTED CHOKE MANIFOLD. INSTALLED BORE PROTECTOR. RIGGED UP TUBING HANDLING EQUIPMENT. MADE UP BHA #9. MADE UP BHA #10 MW: 0.0 VIS: 0 MADE UP BHA #9. RIH TO 12600'. SET INFLATABLE PACKER @ 12575'. LOCATE PROFILE SUB, FUNCTION TOOLS, TEST LINES. PUMP 3 BBLS RETARDED WATER LOAD DART PUMP 3 BBLS CLEAN CEMENT LOAD SPONGE, PUMP 4 BBLS RETARDED WATER DISPLACE TO TOOL WITH RIG PUMP. LOCATE AND INFLATE PACKER WITH BJ. PACKER SET @ 12575'. POH TO 11145' REVERSE CIRCULATED. SETTING TOOLS FAILED. CIRCULATED. OBTAINED CLEAN RETURNS. CIRC CEMENT OUT THE LONG WAY WHEN WE TRIED TO REVERSE THE DOWN HOLE TOOL WOULD CLOSE. POH TO 50'. PULLED BHA. BHA LAID OUT. LAY DOWN CTC PACKER SETTING TOOLS. MADE UP BHA #10. CLEAN OUT ASSEMBLE. RUN TUBING TO 5704.90' MW: 0.0 VIS: 0 MADE UP BHA #10. RIH TO 13424' CIRCULATED. ACID SPOTTED DOWN HOLE. CAN'T FIND BLEACH ON PICK LIST. LAID DOWN DRILL PIPE TO 11056'. CIRCULATED @ 11020.9' OBTAINED CLEAN RETURNS. HAD CLEAN SEAWATER RETURNS. LAID DOWN DRILLPIPE TO 2490'. PULLED BHA. BHA LAID OUT. REMOVED BORE PROTECTOR. RUN SINGLE COMPLETION, 4 1/2". RAN TUBING TO 5704.9'. 1 6 1996 Cons. Commission /.~',,:h o:'a:.'.i8 WELL · Y-21A OPERATION: RIG : NABORS 28E PAGE: 6 05/03/95 (23) TD:13500' ( 0) 05/04/95 (24) TD:13500' ( 0) CIRCULATE MW: 0.0 VIS: 0 RAN TUBING TO 8464.90'. STOPPED TO PICK UP/LAY OUT TUBULARS. TO PICK UP SSSV. TESTED DUAL CONTROL LINE. RAN TUBING TO 10607.90' INSTALLED TBG HANGER. LAND TUBING AT 10643'. RUN IN LOCK DOWN SCREWS. CIRCULATE. REVERSED IN COREXIT. HOLE DISPLACED WITH SEAWATER. SET PACKER AT 10596.97'. TESTED PACKER ON THE INSIDE, OK. TESTED BACKSIDE. INSTALLED HANGER PLUG. BACK PRESSURE VALVE. HANGER PLUG IN POSITION. RIGGED DOWN BOP STACK. INSTALLED WELLHEAD HOUSING. INSTALL PRODUCTION TREE. CIRCULATED @ 10643.90'. RIG UP TO U-TUBE DIESEL INTO THE WELL WAIT ON DRILL SITE MAINTENANCE TO PULL BACK PRESSURE. RIG UP TREE TO U-TUBE. RUG UP LUBRICATOR PULL BACK PRESSURE VALVE INSTALL TREE TEST PLUG AND TEST TREE. CIRCULATED @ 5964.90'. PUMP 155 BBLS OF FREEZE PROTECTION DOWN ANNULUS. RELEASE RIG MW: 0.0 VIS: 0 COMPLETED OPERATIONS. RELEASED RIG @ 2200 HRS ON 05/03/95. SIGNATURE: (drilling superintendent) DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/Y-21A 500292157401 NORTH SLOPE COMPUTATION DATE: 5/10/9 DATE OF SURVEY: 042795 MWD SURVEY JOB NUMBER: AK-MW-50031 KELLY BUSHING ELEV. = 82.71 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDI NORTH/SOUTH EAST/ NATES VERT. WEST SECT. 8998 7760.28 7677.57 9005 7765.64 7682.93 9133 7868.62 7785.91 9167 7895.02 7812.31 9261 7967.60 7884.89 35 40 S 28.58 W .00 35 42 S 28.63 W .60 38 12 S 42.90 W 6.93 38 12 S 46.20 W 6.07 41 0 S 57.30 W 8.08 3364.36S 1289 3367.74S 1291 3429.94S 1336 3444.74S 1351 3481.60S 1398 .58W 3273.72 .42W 3277.40 .57W 3353.16 .14W 3373.93 .18W 3433.33 9356 8039.34 7956.63 9452 8110.39 8027.68 9548 8177.78 8095.07 9642 8240.04 8157.33 9737 8299.62 8216.91 41 30 S 61.70 W 3.09 43 12 S 60.90 W 1.85 46 54 S 61.00 W 3.88 50 35 S 62.30 W 4.05 51 42 S 64.20 W 1.94 3513.50S 1452 3544,61S 1509 3577.39S 1568 3611,08S 1630 3644.36S 1696 .35W 3494.37 .16W 3556.74 .17W 3621.85 .66W 3690.09 .71W 3760.59 9829 8355.09 8272.38 9924 -8410.57 8327.86 10015 8464.05 8381.34 10110 8520.19 8437.48 10202 8574.90 8492.19 53 47 S 66.80 W 3.22 54 42 S 67.20 W 1.01 53 47 S 66.30 W 1.27 53 30 S 70.50 W 3.59 53 24 S 67.30 W 2.80 3674.58S 1763 3704.69S 1834 3734.01S 1902 3762.08S 1973 3788.64S 2041 .07W 3829.18 .01W 3900.96 .27W 3970.27 .15W 4040.58 .98W 4108.37 10297 8632.03 8549.32 52 54 S 71.40 W 3.48 10391 8689.09 8606.38 51 47 S 71.70 W 1.20 10512 8762.83 8680.12 53 30 S 68.70 W 2.41 10573 8798.62 8715.91 54 24 S 68.80 W 1.49 10603 8815.97 8733.26 55 35 S 69.00 W 4.00 3815.51S 2113 - 3838.92S 2183 3871.66S 2274 3889.49S 2320 3898.41S 2343 .26W 4178.13 .42W 4244.67 .28W 4332.54 .llW 4377.77 .24W 4400.55 10636 8833.67 8750.96 10670 8850.58 .8767.87 10700 8863.91 8781.20 10733 8877.35 8794.64 10764 8890.25 8807.54 58 35 S 69.40 W 9.27 62 42 S 69.60 W 11.89 65 0 S 69.70 W 7.61 65 35 S 69.30 W 2.18 65 54 S 69.80 W 1.74 3908.12S 2368 3918.65S 2396 3928.09S 2422 3938.32S 2449 3948.33S 2476 .81W 4425.63 .99W 4453.14 .44W 4477.94 .80W 4504.66 .65W 4530.86 10795 8902.98 8820.27 10826 8915.36 8832.65 10859 8928.04 8845.33 10890 8940.27 8857.56 10921 8952.16 8869.45 66 11 S 70.10 W 1.30 66 41 S 69.50 W 2.40 67 5 S 67.90 W 4.72 67 18 S 67.20 W 2.14 67 54 S 67.30 W 1.95 3958.15S 2503 3967.97S 2530 3978.77S 2557 3989.87S 2584 4001.03S 2611 .55W 4556.97 .22W 4582.90 .92W 4610.25 .80W 4637.24 .41W 4664.07 10952 8963.56 8880.85 68 5 10981 8974.58 8891.87 68 0 11014 8986.25 ~ 8903.54 69 35 11045 8996.24 8913.53 72 41 11076 9004.72 8922.01 76 18 S 67.30W .66 S 67.00 W 1.00 S 66.60 W 5.09 S 66.60 W 10.03 S 66,10 W 11.45 4011.92S 4022.53S 4034.39S 4046.01S 4058.28S 2637.44W 2662.62W 2690.29W 2717.14W 2745.15W 4690.30 4715.73 4743.81 4771.13 4799.73 SPERRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU/Y-21A 500292157401 NORTH SLOPE COMPUTATION DATE: 5/10/95 DATE OF SURVEY: 042795 MWD SURVEY JOB NUMBER: AK-MW-50031 KELLY BUSHING ELEV. = 82.71 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11108 9011.53 8928.82 11141 9016.99 8934.28 11181 9021.74 8939.03 11212 9024.64 8941.93 11245 9027.08 8944.37 78 48 S 65.80 W 7.97 4070.855 2773.32W 82 0 S 65.80 W 9.77 4084.085 2802.76W 84 24 S 65.33 W 6.09 4100.565 2839.04W 85 5 S 64.97 W 2.48 4113.815 2867.65W 86 24 S 64.60 W 4.11 4127.795 2897.34W 4828.67 4858.97 4896.44 4926.16 4957.17 11276 9028.25 8945.54 11308 9028.53 8945.82 11340 9028.53 8945.82 11373 9028.25 8945.54 11403 9027.64 8944.93 89 11 S 65.30 W 9.44 4140.735 2925.01W 89 48 S 65.80 W 2.40 4154.175 2954.57W 90 11 S 64.40 W 4.59 -~ 4167.535 2983.36W 90 48 S 64.20 W 1.94 4181.635 3012.66W 91 30 S 64.90 W 3.26 4194.695 3040.10W 4985.99 5016.53 5046.46 5077.28 5106.02 11435 9026.69 8943.98 11467 9025.76 8943.05 11499 9025.40 8942.69 11531 9025.71 8943.00 11562 9026.36 8943.65 91 54 S 65.60 W 2.52 4208.065 3069.10W 91 24 S 66.60 W 3.46 4221.135 3098.60W 89 54 S 67.00 W 4.89 4233.635 3127.76W 89 0 S 68.70 W 5.99 4245.735 3157.48W 88 35 S 69.60 W 3.18 4256.755 3186.42W 5136.11 5166.34 5195.93 5225.65 5254.06 11594 9027.08 8944.37 11626 9027.73 8945.02 11658 9028.31 8945.60 11690 9028.93 8946.22 11721 9029.44 8946.73 88 48 S 70.10 W 1.69 4267.735 3216.34W 88 54 S 70.00 W .44 4278.785 3246.77W 89 0 S 69.90 W .44 4289.725 3276.76W 88 48 S 69.70 W .88 4300.825 3306.92W 89 18 S 69.00 W 2.80 4311.635 3335.62W 5283.12 5312.60 5341.70 5371.04 5399.12 11754 9029.27 8946.56 11786 9027.67 8944.96 11816 9025.08 8942.37 11848 9022.22 8939.51 11880 9019.87 8937.16 91 18 S 69.00 W 6.17 4323.265 3365.90W 94 24 S 70.00 W 10.15 4334.485 3395.91W 95 24 S 69.90 W 3.31 4344.845 3424.30W 95 0 S 69.80 W 1.30 4355.705 3453.88W 93 24 S 70.00 W 5.04 4366.665 3483.85W 5428.90 5458.21 5485.75 5514.49 5543.59 11911 9018.30 8935.59 11943 9017.43 8934.72 11976 9016.95 8934.24 12009 9016.49 8933.78 12039 9016.02 8933.31 92 18 S 70.30 W 3.60 4377.395 3513.57W 90 48 S 71.00 W 5.17 4388.005 3543.79W 90 54 S 70.40 W 1.87 4398.745 3574.44W 90 41 S 69.50 W 2.77 4410.135 3605.65W 91 5 S 70.20 W 2.69 4420.445 3633.75W 5572.35 5601.37 5630.80 5661.08 5688.39 12071 9015.74 8933.03 12103 9015.71 8933.00 12136 9015.93 8933.22 12168 9016.82 8934.11 12191 9017.56 8934.85 89 54 S 71.00 W 4.47 4431.175 3664.22W 90 11 S 71.40 W 1.56 4441.505 3694.57W 89 0 S 71.40 W 3.69 4451.875 3725.38W 87 54 S 71.40 W 3.37 4462.265 3756.26W 88 18 S 70.90 W 2.85 4469.515 3777.50W 5717.67 5746.61 5775.89 5805.24 5825.50 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING DBU/Y-21A 500292157401 NORTH SLOPE COMPUTATION DATE: 5/10/9 DATE OF SURVEY: 042795 MWD SURVEY JOB NUMBER: AK-MW-50031 KELLY BUSHING ELEV. = 82.71 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12222 9018.29 8935.58 12254 9018.86 8936.15 12286 9019.53 8936.82 12318 9020.28 8937.57 12349 9021.02 8938.31 89 0 S 71.00 W 2.27 4479.68S 3806.96W 89 0 S 71.30 W .93 4490.06S 3837.36W 88 35 S 70.70 W 2.25 4500.48S 3867.62W 88 41 S 71.20 W 1.58 4510.99S 3898.05W 88 35 S 71.40 W .72 4520.96S 3927.51W 5853.67 5882.67 5911.59 5940.70 5968.74 12381 9021.72 8939.01 12413 9021.86 8939.15 12446 9021.24 8938.53 12461 9020.78 8938.07 12477 9020.32 8937.61 88 54 S 71.30 W .99 4531.19S 3957.82W 90 35 S 72.10 W 5.87 4541.24S 3988.19W 91 35 S 71.80 W 3.25 4551.18S 4018.71W 91 48 S 72.70 W 5.96 4555.90S 4033.43W 91 35 S 71.00 W 11.02 4560.73S 4048.17W 5997.57 6026.31 6055.09 6068.91 6082.83 12492 9019.90 8937.19 12509 9019.58 8936.87 12522 9019.48 8936.77 12542 9019.45 8936.74 12556 9019.49 8936.78 91 30 S 71.10 W .90 4565.78S 4062.89W 90 41 S 70.30 W 6.88 4571.22S 4078.42W 90 11 S 70.70 W 4.84 4575.63S 4090.89W 90 0 S 70.40 W 1.82 4582.22S 4109.55W 89 35 S 71.00 W 5.11 4586.89S 4122.86W 6096.90 6111.79 6123.80 6141.75 6154.54 12573 9019.59 8936.88 12586 9019.59 8936.88 12605 9019.57 8936.86 12623 9019.85 8937.14 12638 9020.50 8937.79 89 48 S 70.30 W 4.11 4592.76S 4139.59W 90 11 S 70.00 W 4.05 4596.95S 4151.21W 89 54 S 70.20 W 1.90 4603.42S 4169.05W 88 18 S 70.40 W 9.02 4609.44S 4185.88W -86 41 S 70.00 W 11.02 4614.50S 4199.94W 6170.61 6181.84 6199.12 6215.36 6228.97 12655 9021.72 8939.01 12667 9022.67 8939.96 12687 9024.33 8941.62 12701 9025.37 8942.66 12719 9026.58 8943.87 85 24 S 70.40 W 7.69 4620.48S 4216.54W 85 11 S 70.60 W 2.44 4624.34S 4227.44W 85 24 S 72.80 W 10.87 4630.67S 4246.59W 85 48 S 71.60 W 9.30 4634.81S 4259.48W 86 35 S 73.40 W 10.77 4640.29S 4276.85W 6245.01 6255.50 6273.63 6285.73 6301.99 12733 9027.40 8944.69 12750 9028.25 8945.54 12764 9028.94 8946.23 12782 9029.75 8947.04 12797 9030.20 8947.49 86 54 S 72.00 W 9.87 4644.58S 4290.65W 87 11 S 70.90 W 6.94 4649.80S 4306.19W 87 11 S 73.30 W 16.95 4654.14S 4319.62W 87 41 S 71.80 W 8.72 4659.57S 4336.89W 88 48 S 72.10 W 7.72 4664.14S 4350.93W 6314.86 6329.62 6342.26 6358.41 6371.64 12814 9030.40 8947.69 12829 9030.39 8947.68 12845 9030.27 8947.56 12862 9030.10 8947.39 12876 9029.91 8947.20 89 48 S 70.80 W 9.86 4669.43S 4366.69W 90 18 S 71.20 W 4.28 4674.30S 4380.84W 90 30 S 72.20 W 6.26 4679.41S 4396.30W 90 41 S 72.00 W 1.68 4684.59S 4412.32W 90 48 S 74.30 W 16.27 4688.69S 4425.86W 6386.61 6400.14 6414.77 6429.85 6442.40 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SFIARED SERVICES DRILLING PBU/Y-21A 500292157401 NORTH SLOPE COMPUTATION DATE: 5/10/9 DATE OF SURVEY: 042795 MWD SURVEY JOB NUMBER: AK-MW-50031 KELLY BUSHING ELEV. = 82.71 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DC/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12892 9029.67 8946.96 90 54 S 74.20 W .89 4693.02S 4441.21W 12909 9029.40 8946.69 90 54 S 72.10 W 12.03 4698.08S 4457.92W 12924 9029.16 8946.45 91 0 S 73.30 W 8.31 4702.38S 4471.74W 12940 9028.87 8946.16 91 0 S 71.80 W 9.03 4707.36S 4487.57W 12955 9028.61 8945.90 91 0 S 71.80 W .00 4712.06S 4501.87W 6456.40 6471.88 6484.78 6499.58 6513.09 12973 9028.29 8945.58 91 5 S 74.30 W 14.23 4717.18S 4518.68W 12987 9028.10 8945.39 90 24 S 73.40 W 8.07 4721.11S 4532.24W 13006 9028.00 8945.29 90 11 S 74.10 W 3.77 4726.51S 4550.78W 13017 9027.99 8945.28 89 54 S 72.30 W 17.70 4729.49S 4560.64W 13033 9028.02 8945.31 89 54 S 72.90 W 3.78 4734.24S 4575.80W 6528.69 6541.13 6558.17 6567.31 6581.46 13048 9028.06 8945.35 89 48 S 72.40 W 3.40 4738.72S 4590.11W 13066 9028.12 8945.41 89 48 S 74.20 W 9.94 4743.92S 4607.46W 13079 9028.12 8945.41 90 11 S 74.40 W 3.34 4747.54S 4620.34W 13096 9027.88 8945.17 91 24 S 73.00 W 10.64 4752.40S 4636.97W 13110 9027.49 8944.78 91 54 S 74.20 W 9.71 4756.18S 4649.81W 6594.83 6610.87 6622.62 6637.91 6649.73 13126 9026.93 8944.22 92 0 S 75.50 W 7.86 4760.51S 4665.80W 13142 9026.36 8943.65 92 5 S 75.90 W 2.58 4764.45S 4681.25W 13160 9025.85 8943.14 91 11 S 75.20 W 6.46 4768.85S 4698.32W 13174 9025.60 8942.89 90 54 S 76.10 W 6.84 4772.28S 4711.75W 13186 9025.41 8942.70 90 54 S 75.40 W 5.92 4775.19S 4723.21W 6664.20 6678.00 6693.28 6705.28 6715.52 13206 9025.11 8942.40 90 48 S 77.20 W 8.99 4779.94S 4742.69W 13229 9024.80 8942.09 90 41 S 74.90 W 9.68 4785.67S 4765.75W 13238 9024.74 8942.03 90 5 S 74.60 W 8.08 4787.85S 4773.76W 13254 9024.73 8942.02 90 0 S 74.00 W 3.75 4792.24S 4789.36W 13270 9024.83 8942.12 89 18 S 75.20 W 8.73 4796.47S 4804.71W 6732.76 6753.26 6760.52 6774.74 6788.67 13288 9025.09 8942.38 89 0 S 75.60 W 2.79 4800.99S 4822.06W 13302 9025.33 8942.62 89 0 S 73.30 W 16.75 4804.67S 4835.28W 13333 9025.78 8943.07 89 24 S 74.40 W 3.66 4813.55S 4865.95W 13366 9026.06 8943.35 89 35 S 74.60 W .88 4822.12S 4896.88W 13398 9026.28 8943.57 89 35 S 74.40 W .62 4830.75S 4927.97W 6804.24 6816.27 6844.42 6872.52 6900.79 13428 9026.86 8944.15 88 11 S 74.90 W 4.94 4838.71S 4956.99W 13442 9027.36 8944.65 87 48 S 76.10 W 8.89 4842.27S 4970.75W 13500 9029.56 8946.85 87 48 S 76.10 W .00 4856.05S 5026.41W 6927.11 6939.44 6988.87 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6988.99 FEET AT SOUTH 45 DEG. 59 MIN. WEST AT MD = 13500 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 225.66 DEG. TIE IN POINT 8998.4' WINDOW POINT 9005' INTERPOLATED DEPTH 13500' 1 6 1995 ,,:,;~,:,~.<.~-; C~i~ &. i:-.',~s Cons. ComMi~,~iOl~ Anchor~.ge SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING PBU/Y-21A 500292157401 NORTH SLOPE COMPUTATION DATE: 5/10/95 DATE OF SURVEY: 042795 JOB NUMBER: AK-MW-50031 KELLY BUSHING ELEV. = 82.71 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8998 7760.28 7677.57 9998 8453.76 8371.05 10998 8980.76 8898.05 11998 9016.62 8933.91 12998 9028.03 8945.32 3364.36 S 1289.58 W 3728.36 S 1889.40 W 4028.52 S 2676.73 W '4406.24 S 3595.25 W 4724.21 S 4542.67 W 1238.12 1544.64 306.52 2017.64 473.00 2981.78 964.13 3970.37 988.59 13500 9029.56 8946.85 4856.05 S 5026.41 W 4470.44 500.07 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 SHARED SERVICES DRILLING PBU/Y-21A 500292157401 NORTH SLOPE COMPUTATION DATE: 5/10/95 DATE OF SURVEY: 042795 JOB NUMBER: AK-MW-50031 KELLY BUSHING ELEV. = 82.71 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8998 7760.28 7677.57 3364.36 S 1289.58 W 1238~12 9026 7782.71 7700.00 3378.42 S 1297.62 W 1243.36 5.24 9151 7882.71 7800.00 3437.93 S 1344.25 W 1268.85 25.49 9281 7982.71 7900.00 3488.61 S 1409.31 W 1298.64 29.79 9414 8082.71 8000.00 3532.00 S 1486.48 W 1332.21 33.57 9555 8182.71 8100.00 3579.96 S 1572.83 W 1372.80 40.60 9710 8282.71 8200.00 3635.04 S 1677.43 W 1427.70 54.89 9876 8382.71 8300.00 3689.45 S 1797.80 W 1493.41 65.72 10047 8482.71 8400.00 3743.92 S 1925.70 W 1564.66 71.25 10215 8582.71 8500.00 3792.63 S 2051.69 W 1632.74 68.08 10380 8682.71 8600~00 3836.37 S 2175.72 W 1698.00 65.25 10546 8782.71 8700.00 3881.47 S 2299.47 W 1763.39 65.40 10746 8882.71 8800.00 3942.49 S 2460.91 W 1863.45 100.05 11004 8982.71 8900.00 4030.61 S 2681.56 W 2021.31 157.86 13500 9029.56 8946.85 4856.05 S 5026.41 W 4470.44 2449.13 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITf~ To: State of Alaska July 14, 1995 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - Y-21A AK-MW-50031, AK-RB-950419 RE: The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way,//G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-21574-01 1 Blueline 1 Rev Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-21574-01 1 Blueline 1 Rev Folded Sepia LDWG Formatted LIS Tapei _ t /r~~~\ ,/ 1 Magnetic Tape 50-029-21574-01 ~ j~ 1 LDWG Verification Listing 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION · 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 11 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS/STATIC FNL BL+RF 1 PLS/TEMP/FINAL BL+RF ECC No. Run # 1 4967.01 Run # 1 5041.03 Run # 1 6425.00 Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please stg~ and r:eturn Petrotechntoal Data Cente~ BI' Exploration (Alaska) Ino 900~s~st Benson Boulevard Anehor~e- ALASKA OIL GAS CONSERVATION COMMISSION ! / I TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 31, 1995 Terry Jordan Drilling Engineer Supervisor BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit Y-21A BP Exploration (Alaska) Inc, Permit No. 95-37 Sur. Loc. 1714'SNL, 240'WEL, Sec. 33, TllN, R13E, UM Btmnhole Loc. 1003'SNL, 5231'WEL, Sec. 4, TiON, R13E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to redrJ, ll the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ \ BY ORDER OF THE~OMI{~SSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll;'lllb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenF']I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) BP Exploration KBE = 89' fe et 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1714'SNL, 240' WEL, SEC. 33, T11N, R13E At top of productive interval 246' SNL, 3069' WEL, SEC. 4, TION, R13E At total depth 1003' SNL, 5231' WEL, SEC. 4, TION, R13E 2. Distance to nearest property line ADL 28289-49' fee t 13. Distance to nearest well No close approach feet 16. To be completed for deviated wells :Kickoff depth 9000 feet Maximum hole angle 90.4 o 18. Casing program s~ze Specifications 6. Property Designation ADL 47471 7. Unit or property Name Prudhoe Bay Unit 8. Well number Y-21A (11-4-10-13) 0. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool 11. Type Bond(see 20 AAC 25.025) Number 2S 100302630-277 9. Approximate spud date Amount 4/10/95 $200,000. O0 4. Number of acres in property!15. Proposed depth (MD and'rvD) 2560 13492' MD/9029' TVD f e e t 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum suHace 3330 psig At total depth (TVD) ~800'/4390 psig Setting Depth Top Bottom Quantity of cement Hole Casing Weight I GradeI 6" 4-1/2" NSCT 19. To be completed for Redrill, Re-entry, and Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Coupling Casing Length Structural Conductor 110' Length i2350' 2442' MD, 8850 11050' TVD M D TVD 7642' 11200' 9044' 430 sx Class "G" 9030' 13492' 9029' Uncemented slotted liner (include stage data) Deepen Operations. 11630 feet 9088 fe et 11585 feet 9080 feet Size Plugs (measured) MAR 23 1995 Aiaska Oil & Gas Cons. Commission Anchora c- Junk (measured) Cemented Measured depth True Vertical depth 20" 8 cu yds concrete 146' 146' Surface Intermediate Production Liner Perforation depth: 2632' 13-3/8" 3720 cu ft PF 'E" 2668' 2668' 11331' 9-5/8" 897 cuft "G" 11367' 8924' 572' 7" 316 cuft "G" measured 11050'-11108', 11380'.11520' true vertical 8943'-8962', 9037'-9068' (Subsea) 11058'-11630' 8945~9088' i 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] iDrilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed reportl-I 20 AAC 25.050 requirementsi--I 21. I hereby ced!fy that, tll, e foregoing is true and correct to the best of my knowledge Signed /'~/_/~(//~ ~ Title Dr/fling Engineer Supervisor Date ~ '~'l-~ Commission Use Only Permit Number IAPI number IAppLoval dste See cover letter , ~',J<"-,~'~ 150'°''~-~'-'~'E'//'''<-~/-'¢'/ I ~' ""~-/~"-~ for other requrements Conditions of approval Samples required [] Yes ~ No Mud Icg required [] Yes ;~ No Hydrogen sulfide measures F'J Yes [] No Directional survey required J~ Yes [] NO Required working pressure for BO['I~ [] 2M; r-']3M; J~5M; Fll0M; I-Il SM; Other: Unginal Signed ~y by order of ,.,/ / Approved by David W. Johnston Commissioner me comm,ssion Form 10-401 Rev. 12-1-85 Submit in triplicate [Well Type of Well (producer or injector): ..me: [Y-21a Well Plan Summary [Producer [ Surface Location: 1,714' FNL 240' FEL Sec 33 T11N R13E Target Location: 246' FNL 3,069' FEL Sec 4 T10N R13E (start of horizontal) Bottom Hole Location: 1,003' FNL 5,23 i'FEL Sec 4 T10N R13E (end of horizontal) ] AFENumber: 14P0654 ] Estimated Start Date: 1 4-10-95 [MD: i 13,492' I I Rig: [Nabors 28-E I Operating days to complete: ] 26 I TVD: [ 9,029' [ [ KBE-MSL 35.1' 89.0' Well Design (conventional,slimhole,etc.) I Horizontal Sidetrack I I Formation Markers: Formation Tops MD TVD(RKB) HRZ 8603' 7439' LCU 8865' 7652' Kickoff Point 9000' 7763' Kingak 9379' 8059' TJB 10576' 8807' Sag River 10787' 8932' Top Shublik 10837' 8957' Top Sadlerochit 11074' 9034' 7-5/8" Casing Point 11200' 9044' At Horizontal (90.4°) Total Depth 13492' 9029' End Slotted Liner Casing/Tubinl Prol,~ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 8-1/2" 7" 264/ L-80 NSCC 2350' 8850'/7642' 11200'/9044' 6" 4-1/2" 12.6# ', L-80 NSCT 2442' 11050'/9030' 13492'/9029' (slotted) Tubing 4-1/2" 12.6# L-80 NSCT 10705' 32'/32' 10737'/8900' Logging Program: [Open Hole Logs: 8-1/2" Hole W/L: None MWD' GR from 2nd KOP to Horizontal 6" Hole MWD' Resistivity/GR in horizontal section Cased Hole Logs: 9-5/8" Casing None ~si0n Mud Program: Intermediate Mud Properties: [ 8-1/2" hole section to horizontal: LSND Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9,000' 9.6-9.7 40-50 12-15 4-8 8-12 9-10 <6 HTHP-15.0 10,700' 9.6-9.8 50-60 20-30 10-12 12-16 9-10 <6 Start Build HTHP- 15.0 11,200' 9.6-9.8 50-60 20-30 10-12 12-16 9-10 <6 HTHP-15.0 Hazards/Concerns Utilize hi vis sweeps to assist hole cleaning Treat with 2 ppb each of Boreplate, Barotrol, & Baranex before entering Kingak. Monitor LSYP and increase if problems occur trying to clean the hole. Potential high torque could need lubricant use. Reduce API fluid loss to <6 cc before drilling Kingak Section. Production Mud Properties: I 6" hole section: Xanvis KCL Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 11,200' 8.8-9.0 50-60 30-40 15-20 18-24 9.5-10.5 <6 13,492' 8.8-9.0 50-60 30-40 15-20 18-24 9.5-10.5 <6 Hazards/Concerns Lost Circulation still a possibility due to severe overbalance in Sadlerochit. Differential sticking possible with overbalance situation. Perform/report daily checks on KC1 concentrations in Xanvis KC1 system. High torque may be experienced and should be countered with Lubtex treatments. Directional: [KOP: 19,000' md I Maximum Hole Angle: 90.4° Tangent Angle 53.5© Close Approach Well: None The above listed wells will be secured during the close approach. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. E ¢ E IV E D Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal: Cuttings Handling: CC2A Fluid Handling: Annular injection. Annular Injection: Verify the list below against Karen Thomas' Report of Approved Wells prior to injection. DO NOT EXCEED 35,000 BBLS IN THE ANNULUS. MAR 2 3 199,5 A~aska 0il & Gas Cons. Commission Anchora .n AREA WELL PREV VOL PERMH-I'ED PERMITTED DATES INJECTED VOL (BBLS) (BBLS) V~A Y-36 235 35,000 1/1/95-12/31/95 VV:::)A Y-37 0 35,000 1/1/95-12/31/95 Sidetrack Y-21a Operational Summary 1. P&A well with coil tubing unit. Tag cement at least 100' above the top perf @ 11,050' md. Cut 3-1/2" tubing at one joint above the sliding sleeve @ 9,805'. 2. Pull 3-1/2" tubing. Set bridge plug @ +9,250' md. 3. Mill out window at + 9,000' md and set a cement kick off plug. 4. Drill 8-1/2" hole to horizontal in Zone 4 using gamma ray/directional MWD to + 11,200' md. 5. Set 7" L-80 liner @ + 11,200' md. 6. Drill 6" hole reaching TD at + 13,489' md using xanvis mud. 7. Set 4-1/2" slotted liner @ TD. External casing packers may be used along slotted liner. 8. Run new completion of 4-1/2" L-80 tubing. Drilling Hazards · Sadlerochit interval has a pore pressure of 8.0 ppg EMW. occur due to overbalance. Lost circulation may RECEIVED MAR 23 1995 Air~ska Oil & 6as Con~. Commission Anchora ,~, VHH February 28, 1995 BJ SERVICES PRUDHOE BAY DRILLING Y PAD, WELL 21A NABORS RIG 28E DRILLING LINER WELL DATA DEPTH 11200'MD 9044'TVD HOLE SIZE 8 1/2" PIPE SIZE 7" OD, 29# MUD WEIGHT 10.0 PPG BHST 210° F BHCT 140° F VOLUME EXCESS VOLUME REQUIRED TOP OF CEMENT PREFLUSH 358 CF 30% OH 498 cf 8700'MD Preflush/Spacer CEMENT RECOMMENDATION Preflush: 20 Bbls WATER containing 70 Bbls MCS-4 Spacer Slurry: 430 Sks (503 cf) Class G + 150 ghs BA-86L + 0.3% FL-33 + 0.6% CD-32 + 0.2% A-2 + 0.5% Gel + 1 ghs FP-12L CEMENT PROPERTIES i, PREFLUSH LEAD SLURRY DENSITY- PPG 8.4 / 10.5 15.7 YIELD - CF/SK 1.17 MIX WATER - GALS/SK 3.58 THICKENING TIME - HRS:MINS FLUID LOSS - CC's / 30 MINS 2:30-3:00 + 0:45 SURFACE < 5O FREE WATER - ML's COMPRESSIVE STRENGTH - PSI 12 HOURS @ OF 24 HOURS @ °F 0.0 @ 45° angle UCA 2350 UCA 2800 REMARKS Volume includes 80' float joint. TOL @ 8850'MD inside 9 5/8" csg at 9000' MD. Slight additive adjustment should be expected to achieve desired properties. RECEIVED ~ q~l ,& 6~s 6on~. Commission BPX-$hared Services Drilling Alaska State Plane: Zone4 PBU : %'OA: Y-Pad Y-21A Y-2 lA Wp5 WELL PLaN PROFILE SUUMAR¥ JS?.n Wl~End WD!Plonned Activity ~ooo i : 1 IHoo i ¢JOOO~SII)[TRACK Y-~'I J KD~. DRILL OUT VI3H 8 1/~' ~IT. D8~START ~ CURVE AT 4 D~EES / 100' ~UILDI~ FRON 35.6 DE.ElS INCLINAT[~ TO 53,5 DE.lES ~D ~TURNI~ AZI~IH rR~ 205.6 DEGRE[~ TO 249.5 1 ~5~JNTAIN TA~NT. : Ji200i~TART ~ CUEV[ AT R DEGaEES / 100' TO INCLINATION DF 90.37 DE~EES ~D AZIHUIN ~- 250.06 ~[ACN 7 ' CASING P~JNT. 1349HiDRILL OUT WITH 6' BlT. H*INTAIN ~ANOENT TO TD . 5~44390 I 5~.44110 J 59'44675 J 5~-43g 75 J J \ .~..,n, ! 0731 ,¢ ~oo 2to~ 3c~c ~o~3~00 3~0~ ~oo 4000 ~20G a4'oo ~oc dJO0 5DOt ~ 1~ /~. ~,4..-.~ ....... ~:~l:,? :~ ~.~F~~ ..... · ...... ........... ~ .......... ~~,,,, ,,23 .................... ~2¢~~ .... .... , ..... CRITICAL POINT DATA kCg :)$.14' 2J,~5.4C' 7439 ~I~G ~ JiB3 G~G5 35.12' 207,9d' 7A52 ~9& S 1252 V JK~ / TIE IN / 9000 35.~5' EOI.Si' 77{3 33G~~ )299 V / INIER~ATED J~JNT / :~T J ~ C~vE e ~d~ 1~0*~ 53 5C' 749.5~' 6491 376Z~ 1691 V I~T*~T ~ IO~L5 53.50' ~,e.5C' 6a,0 ~3~ ~ 23~ v fo.,o'/iD, ;~ v Dr Cg~ : 250.&~' 9029 4g~& S 4980 V s CASI~.~ PDIN1 DAT~, ] 1170090.38' k~O.6~' 9044 41C7 ~)'O I 7 V 13492 9G.37' ~0,66' 9~9 48~ 4980 V RECEIVED MAR 2:5 1995 Alaska 0il & 6as 0OHS. Commission Anchora J SURFACE LOCATION J ~,.. ~3-1-95 J ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator BP EXPloration Abandon X Suspend __ Operation Shutdown __ Re-enler suspended well ~ Alter casing __ Repair well ~ Plugging X Time extension ~ Stimulate __ Change approved program ~ Pull tubing __ Variance__ Perorate __ Other X Plugback for redrill 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 4. Location of well at surface 1417'SNL, 240' WEL, SEC. 33, T11N, R13E At top of productive interval 791' SNL, 2460' WEL, SEC. 4, TION, R13E At effective depth 1206' SNL, 2801' WEL, SEC. 4, TION, R13E At total depth 1241' SNL, 2829' WEL, SEC. 4, TION, R13E Measured depth 6. Datum elevation (DF or KB) KBE = 87.56 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well numbe~-- Y-21 (?~-0'4-10-13) . 9. Peril{it number .~J86-70 10. APl number 50- 029-21574 11. Field/Pool Prudhoe Bay Field/Oil Pool True vertical depth 146' 146' 2668' 2668' 11367' 8924' 11058;11630' 8945'-9088' 12. Present well condition summary ~'/ Total depth: measured 11630 feet P~s(measured) true vertical 9088 feet ~ Effective depth: measured 11585 f~t Junk (measured) true vertical 9080~ feet Casing Length ~,S'~ze Cemented Structural ,,~. 20 8 cu yds Concrete Conductor 110' ~ ',', Surface 263~ 13-3/8 3720 cuft PF "E" Intermediate 1,,1,331' 9-5/8" 897 cuft Class "G" Production ~ 572' ----~, 7" 316 cuft Class "G" Liner /¢~e ~.,'1105~./~,108',11380;11520' Perforation depth: asure true vertical 8943;8962', 9037;9068' (Subsea) RECEIVED Tubing (size, grade, and measured depth) 3-1/2" EUE 8rd to 9871' with 3-1/2" tailpipe to 11278' MD - 6 1995 ~s~a u~j & Gas Cons. Cornmiss Packers and SSSV (type and measured depth) 9-5/8" TIW packer @ 9871'MD; 3-1/2" Otis SSSV @ 2039' ~cho~ 13. Attachments Description summary of proposal × Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 3/10/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. ! hereby certify/that the foregoing is true and correct to the best of my knowledge. ;' "'~ " FOR COMMISSION USE ONLY , (- Title Drilling Engineer Supervisor Conditions of approvkal! Notify_Commission so representative may witness Plug integrity v'" BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- N. O 7' Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST der [] redrll~g~ serv ON/O~ s~o~ ~ ADMINISTRATION ENGINEERING 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N APPR 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................ Y N~ Surface casing protects all known USDWs ......... Y N CMT vol adequate to circulate on conductor & surf csg.. Y N CMT vol adequate to tie-in long string to surf csg . . . Y N CMT will cover all known productive horizons ....... Y ~ Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............ ~ N If a re-drill, has a 10-403 for abndnmnt been approved.~ N--~/ Adequate wellbore separation proposed ......... ~ N If diverter required, is it adequate ........... ¥ Drilling fluid program schematic & equip list adequate ~_ BOPEs adequate ..................... BOPE press rating adequate; test to ~L~ psig.~ N Choke manifold complies w/API RP-53 (May 84) ...... Work will occur without operation shutdown ....... ~-~ N Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y y ~ j /~ 32. Seismic analysis 9f shallow gas zones .......... Y/ N / ~/../--/-· 33. Seabed condition survey (if off-shore) ......... / N 34. Contact name/phone for weekly progress reports .... / Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMISSION: DWJ Comments/Instructions: HOW/jo - A:~ORMS~cheldist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ape Subfile 2 is ~ype:' ~ _S TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 6458.00 R. JACKSON G. COOPER 500292157401 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 14-JUL-95 MWD RUN 3 R. JACKSON KIRK WHITE MWD RUN 4 R. JACKSON KIRK WHITE MWD RUN 5 JOB NUMBER: LOGGING ENGINEER: R. JACKSON OPERATOR WITNESS: KIRK WHITE SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE MWD RUN 6 r'. r<. m ! ? E D KIRK WHITE .... dUL ? I99 AI~ ~_ --.s~ Oil & Gas O~s. 4 10N ~Chorago U°mmissioa 13E 1714 2400 82.71 81.21 48.31 CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 7.000 11200.0 6.000 4.500 13500.0 MWD - DGR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUN 1 WAS DIRECTIONAL ONLY. PRE/POST MUD DISPLACEMENT TO FLOPRO WAS TAKEN AT 11143' MD: PRE DISPLACEMENT SAMPLES = 187.5 AAPI POST DISPLACEMENT SAMPLES = 181.5 A3kPI APPARENT SHIFT OF 6.0 AAPI. DGWD GAMMA RAY DATA IS PROVIDED FROM 10400' TO 10917' MD. SLIMHOLE RLL GAMMA RAY DATA IS PROVIDED FROM 10917' TO 13408' MD. SLIMHOLE DGWD GAMPLA RAY DATA IS PROVIDED FROM 13408' TO 13436' MD. SLIMHOLE PHASE 4 RLL WAS PROVIDED FROM 11200' TO 13415' MD. THE SHALLOW PHASE 4 RESISTIVITY CURVE (RPS) WAS NOT FUNCTIO5 .. THIS WAS KNOWN & UNDER'~f~)OD BY ALL PARTIES PRIOR TO RUNNUING THIS TOOL. 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 RP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 10401.0 11200.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: STOP DEPTH 13436.0 13415.0 -- EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 10464.0 11200.0 3 11200.0 12222.0 4 12222.0 12366.0 5 12366.0 12807.0 6 12807.0 13500.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : Y - 2lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRA24E Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPM MWD 68 1 OHMM RPD MWD 68 1 OHMM ROP MWD 68 1 FPHR FET MWD 68 1 HR 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 24 * DATA RECORD (Ti ~# 0) 1014 BYTES * Total Data Records: 173 Tape File Start Depth = 13500.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 43408 datums Tape Subfile: 2 272 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10401.0 $ 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: STOP DEPTH 11136.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) ' REMARKS: ~D RUN 2. 20-APR-95 MSC DGWD VERSION 1.32 DEP VERSION 2.041 MEMORY 11200.0 10464.0 11200.0 0 53.5 82.0 TOOL NUMBER NGP 69 8.500 .0 LSND 9.70 57.0 9.9 9OO 16.1 .000 .000 .000 .000 .0 150.8 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : Y - 2lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 20 Tape File Start Depth = 11205.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4834 datums Tape Subfile: 3 83 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER:· 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10916.0 EWR4 10922.0 $ 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: STOP DEPTH 12131.0 12139.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 23-APR-95 MSC DGWD VERSION 1.32 DEP VERSION 2.041 MEMORY 12222.0 11200.0 12222.0 0 85.0 95.4 TOOL NUMBER P001SP4 P001SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 11200.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLOPRO 8.90 60.0 9.7 40000 6.6 .140 .150 .110 .220 100.0 93.4 100.0 100.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 3. $ : BP EXPLORATION (ALASKA) : Y - 2lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHM~ 4 3 RPM MWD 68 1 OHMM 4 4 RPD MWD 68 1 OHMM 4 5 ROP MWD 68 1 FPHR 4 6 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 74 Tape File Start Depth = 12225.000000 Tape File End Depth = 10900.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 61966 datums Tape Subfile: 4 139 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12130.0 EWR4 12137.0 $ 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: STOP DEPTH 12275.0 12282.0 24-APR-95 MSC DGWD VERSION 1.32 DEP VERSION 2.041 MEMORY 12366.0 12222.0 12366.0 0 88.6 89.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P001SP4 P001SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 11200.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLOPRO 9.00 58.0 9.6 36000 4.6 .150 .150 .110 .230 98.0 96.4 98.0 98.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 4. $ : BP EXPLORATION (ALASKA) : Y - 2lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHM~ 4 3 RPM MWD 68 1 OHMM 4 4 RPD MWD 68 1 OHMS4 4 5 ROP MWD 68 1 FPHR 4 6 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 16 Tape File Start Depth = 12375.000000 Tape File End Depth = 12100.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8692 datums Tape Subfile: 5 81 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12272.0 EWR4 12279.0 $ 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: STOP DEPTH 12718.0 12725.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN)' TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 26-APR-95 MSC DGWD VERSION 1.32 DEP VERSION 2.041 MEMORY 12807.0 12366.0 12807.0 0 85.2 91.8 TOOL NUMBER P001SP4 P001SP4 6.000 11200.0 FLOPRO 8.90 56.0 8.9 35000 5.4 .O9O . 100 .070 .140 103.0 95.8 103.0 103.0 ,00 ,000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 5. $ : BP EXPLORATION (ALASKA) : Y - 2lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMS4 4 3 RPM MWD 68 1 OHMM 4 4 RPD MWD 68 1 OHFfM 4 5 ROP MWD 68 1 FPHR 4 6 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 24 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 34 Tape File Start Depth = 12850.000000 Tape File End Depth = 12250.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70374 datums Tape Subfile: 6 99 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12717.0 EWR4 12724.0 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RE SIS. 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): STOP DEPTH 13436.0 13415.0 27-APR-95 MSC DGWD VERSION 1.32 DEP VERSION 2.041 MEMORY 13500.0 12807.0 13500.0 0 87.8 91.8 TOOL NUMBER P001SP4 P001SP4 6.000 11200.0 FLOPRO 9.00 52.0 8.8 33000 5.6 .000 .000 .000 .000 .0 .0 .0 .0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 6. $ : BP EXPLORATION (ALASKA) : Y - 2lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FR3~ME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHM/~ 4 3 RPM MWD 68 1 OHMM 4 4 RPD MWD 68 1 OHMM 4 5 ROP MWD 68 1 FPHR 4 6 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 45 Tape File Start Depth = 13500.000000 Tape File End Depth = 12700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19900 datums Tape Subfile: 7 110 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 8 is type: LIS 95/ 7/14 01 **** REEL TRAILER **** 95/ 7/14 01 Tape Subfile: 8 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes End of execution: Fri 14 JLY 95 2:20p Elapsed execution time = 7.58 seconds. SYSTEM RETURN CODE = 0
