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David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 10/18/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Directional Survey Report (PDF) and Data File (XLSX) For each of the well bores listed in the table below: Well Name PTD # API # PBU 05-16 177-143 50029202620000 PBU 05-16A 194-129 50029202620100 PBU 05-16B 199-100 50029202620200 PBU 05-16C 213-056 50029202620400 PBU 18-30 195-091 50029225680000 PBU 18-30A 209-087 50029225680100 PBU 18-30APB1 209-087 50029225687000 SFTP Transfer - Data Folders: Please include current contact information if different from above. T38085 T38086 T38087 T38088 T38089 T38090 T38091 10/20/2023 PBU 05-16B 199-100 50029202620200 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 16:29:04 -08'00' { • STATE OF ALASKA « : E V c Al"KA OIL AND GAS CONSERVATION CCSISSION SFR 1 7 2013 REPORT OF SUNDRY WELL OPERATIONS .A+. CO 1. Operations Performed: ❑Abandon ®Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended Well 0 Alter Casing ®Pull Tubing ❑Stimulate-Frac ❑Waiver ❑Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑Exploratory ❑Stratigraphic 199-100 • 3. Address: 0 Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-20262-02-00 • 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 028326 • PBU 05-16B 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): USIT Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11. Present well condition summary: Total depth: measured 14135' feet Plugs:(measured) 11160' feet true vertical 8808' feet Junk:(measured) 14043' feet Effective depth: measured 14050' feet Packer: (measured) 10272' feet true vertical 8808' feet Packer: (true vertical) 7984' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 116' 20" 116' 116' 1530 520 Surface 2723' 13-3/8" 2723' 2723' 4930 2670 Intermediate 10039' 9-5/8" 10039' 7824' 6870 4760 Production Liner 1946' 7" 8669'- 10615' 6951'-8256' 7240 5410 Liner 3685' 4-1/2" 10450'- 14135' 8123'-8808' 8430 750 Scab Liner 5200' 7" 3492'-8692' 3479'-6966' 7240 5410 Perforation Depth: Measured Depth: 11700'-13998' feet True Vertical Depth: 8782'-8809' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# 13Cr85/L-80 10458' 8130' Packers and SSSV(type,measured and true vertical depth): 7"x 4-1/2"HES TNT Packer 10272' 7984' o!!�� 12.Stimulation or cement squeeze summary: S A�1N N.UV L v w i ` Intervals treated(measured): � Treatment description including volumes used and final pressure: Set CIBP at 11160',Cut and Pull 4-1-2", 12.6#, L-80 Tubing at 10383', Run 7",26#, L-80 Scab Liner from 3492'-8692',Cement Scab Liner w/156 Bbls,Yield 1.17(749 sx)Class'G',Cut&Pull 9-5/8"Casing from 2480', Run 9-5/8",47#, L-80 Tie-Back to 2484', Cement 9-5/8"Tie-Back w/171 Bbls,Yeild 1.18(814 sx)Class'G', Run 4-1/2", 12.6#, 13Cr85 Tubing to 10383'. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 620 0 Subsequent to operation: 0 0 0 20 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic' 0 Development ❑Service 0 Daily Report of Well Operations 16. Well Status after work: '0 Oil ❑Gas ❑WDSPL 0 Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG ❑GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Abby Warren,564-5720 Email:Abigail.Warren @bp.com 313-199 Printed N me' Joe Xst fk Title: Drilling Technologist i{{�/ Signature: Phone: 564-4091 Date: /� ,gf '3 Form 10-404 Re d 10/2012 L / / ,5-/j 3 RBDMS OCI 1 j) OriinalOnly • • 05-16B, Well History (Pre Rig Workover) Date Summary 05/26/13 PULL 4-1/2"WRP FROM 10407'SLM/10441' ELMD. DRIFT W/4-1/2"WRP DRIFT TO 11210'SLM. 05/30/13 CTU#3 1.75"Coil (CTV=30.6 bbls). Job Scope: Drift,Jewelry Log, Set CIBP and PT. AOL from SWS shop after monthly swap of BOP's. MIRU CTU#3. Perform fullbody, push/pull, and drawdown BOP tests. Cut 122'of CT. RIH w/WFT MHA+ PDS carrier+3.70"CIBP drift to 11219'and had no wt loss. Log OOH to 10400', paint flag at 11100'. POH.Attempt to liquid pack wellbore, but after 28 bbls pumped whp was 1100 psi and rising fast due to assumed asphaltines. RIH w/WFT 4-1/2"CIBP assy. Set CIBP at 11,160'.Tag down 5K. Circulate bottoms up and POOH. Pump 20-bbls McOH down backside for FP. PT CIBP to—3,000 psi. Good test. Pop off and lay down tools.5/8"ball recovered. RDMO. 06/05/13 T/I/O=0/640/40.Temp=SI.T&IA FLs(EL).AL disconnected. Functioned SSV open.TBG FL near surface. IA FL @ surface. Functioned SSV closed on departure. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 15:00. 06/06/13 ELINE TUBING CUT. INITIAL T/I/O=50/620/50. RIH W/4-1/2"JET CUTTER&CUT TBG @ 10380' MD(3' BELOW COLLAR IN FIRST FULL TBG JOINT ABOVE PKR). TIED INTO TBG TALLY DATED- 11/19/1999. CONFIRMED CUT BY PRESSURING UP ON TBG AND SEEING IA COMMUNICATION. WELL LEFT SI ON DEPARTURE. FINAL T/I/O=280/. 06/08/13 T/I/O=SSV/620/0+,Temp=SI. PPPOT-T(PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test void(0+psi.). Bled void to 0 psi. Functioned LDS, all moved freely(2"). Pumped through void,good returns. Pressured void to 5000 psi for 30 min.test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test void(0+psi.). Bled void to 0 psi. Functioned LDS, 1 LDS is siezed to gland nut(unable to break free), LDS and gland nut will fully function together, all the rest moved normally(2"). Pumped through void,good returns. Pressured void to 3500 psi.for 30 min. test, lost 100 psi in 15 min, lost 0 psi in second 15 min(PASS). Bled void to 0 psi. 07/14/13 T/I/0=110/525/60 Temp.-SI (Circ TxIA w/9.8 Brine) Pumped a 5 bbl meth spear followed by 653 bbls of 9.8#brine(TxIA volume)down the tubing taking returns up the IA to well 15 that flows to HP Echo common line to FS1.As brine load up the backside increased the rate down the tubing decreased caused by reaching max.Tubing pressure.The decision was made to stop pumping returns to HP common line and set up surface tanks for returns to get max. rate possible. Rigged down. Final WHP- 825/820/225. 07/15/13 T/I/O-40/180/30 Temp.-SI (Circ out well with 9.8#brine) Pumped 2 bbls neat methanol spear followed by 700 bbls 9.8#brine.WSR continues on 7-16-13. 07/16/13 WSR continues from 7-15-13. Circ out. Freeze Protect TBG and IA with 35 bbls Diesel. SwV,WV, SSV=Closed, MV=Open, IA/OA=OTG. 07/17/13 T/I/O=vac/vac/0+Temp=Sl MIT-OA**PASSED**to 2000 psi(Pre RWO) Pumped 2.8 bbls 60*crude down OA to reach test pressure. 1st 15 minutes OA lost 58 psi.2nd 15 minutes OA lost 25 psi.Total loss in 30 minutes=83 psi. Bled OAP(—2 bbls). FWHP's=vac/vac/0+SV,WV,SSV=SI MV=0 IA&OA= OTG. 07/18/13 T/I/O=VACNAC/25.Temp=SI.WHPs(Pre RWO).AL spool removed. Integral flange on IA=inspection not current. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 1700 hrs. Page 1 of 2 t • • 05-16B, Well History (Pre Rig Workover) Date Summary 07/18/13 T/I/O=Vac/0/0; Conduct PJSM; Start barriers list= MV&SSV,verified by independently bleeding tubing pressure off each; R/U lubricator and test against SSV to 300 and 3500 psi for 5 min. LTT passed; Open barriers and set 4-1/16"FMC"ISA" BPV#549 through tree for Doyon 14,tagged at 115"; S/I barriers, RDMO; 07/29/13 T/I/O=BPV/Vac/68. Conduct PJSM. Barreirs= IA valve and IA Bled to O. Perform LTT on IA valve. (Passed) Removed 3 1/8 blind flange and installed New FMC 120 piggyback on IA valve. Installed blind flange and torqued flanged to API spec. (405 ft.Ibs.) Pressure tested FMC 120 against closed IA valve to 300 psi low and 3500 psi high for 5 min each. (Both tests passed, charted and saved to TRP folder) cycled both IA valves and left open to gauge. 07/29/13 T/I/O=SSV/VAC/65.Temp=SI. Bleed OAP to 0 psi (pre RWO). Bled OAP to 0 psi in 1 min (gas). Monitored for 30 min. OAP increased 4 psi.Job complete. FWP's=SSV/VAC/4. SV,WV=?. SSV= C. MV=O. IA, OA=OTG. NOVP. 0415 hrs. Page 2 of 2 • III * 7, 0.7 `;;`l% ®r ,,,, ;,it/'t.7 i ...c. , : t T t ,A>04,4*, Common Well Name:05-16 I AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 I End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM I Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. I UWI:/Lat:070°15'58.646'6 Long: —_-- --- 1 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT 1 NPT Depth I Phase Description of Operations (hr) (usft) 7/30/2013 12:00 - 19:30 7.50 MOB I P 1 PRE MOBILIZE RIG. -MOBILIZE RIG F/NGI-01 TO DS5-16B VIA WEST DOCK ROAD. I *FUNCTION&CONFIRM ESD ON MOVING 1 SYSTEM. 19:30 - 00:00 4.50 MOB P PRE PREP RIG TO MOVE OVER WELL. '-PJSM. REMOVE BOOSTER WHEELS. I-INSTALL CELLAR DOORS -PJSM. L/D HERCULITE/RIG MATS. I-PJSM. SPOT RIG OVER DS5-16B WELL. *CONTACTED PAD OPERATOR,PRIOR TO SPOTTING,RIG OVER WELL. WAIVED RIGHTS TO WITNESS. 7/31/2013 00:00 - 01:30 1.50 MOB 1 P I PRE !POSITION RIG. '-SPOT&SHIM RIG OVER WELL DS5-16B._ 01:30 - 06:30 5.00 MOB 1 P 1 PRE SKID&R/U RIG FLOOR. TAKE ON BRINE. R/U HARDLINE. I -PJSM. SKID RIG FLOOR OVER WELL DS5-16B. -R/U RIG FLOOR&SERVICE LINES. -PREPARE&TAKE ON 9.8 PPG BRINE. -PJSM. R/U HARDLINE F/MANIFOLD TO FLOWBACK TANK&TEST SAME. ...E 11 *ACCEPTED RIG AT 0400 HRS. 06:30 - 07:00 0.50 WHSUR P WHDTRE PJSM ON INSTALLING 1502 COMPANION ,FLANGE ON WING VALVE. 07:00 - 07:30 0.50 WHSUR- P WHDTRE CONDUCT H2S/RIG EVACUATION DRILL WITH I MORNING CREW FOLLOWED BY AN AAR. -EVERYONE REPORTED TO SAFE AREA IN A TIMELY FASHION. *FUNCTION RIG ESD DURING EVACUATION. _ I ALL SYSTEMS SHUT DOWN. 07:30 - 09:30 2.00 WHSUR P WHDTRE I INSTALL 1502 COMPANION FLANGE ON WING II VALVE. 09:30 - 12:00 2.50 WHSUR P WHDTRE TEST LUBRICATOR AND PULL BPV.. -PJSM. R/U DSM LUBRICATOR&TEST SAME TO 250/3500 PSI FOR 5 CHARTED MINS EACH. -PULL BPV.NO PRESSURE UNDER BPV. 12:00 - 14:00 2.00 WHSUR P WHDTRE 'RIG UP TO DISPLACE WELL. 1 -R/U LINES TO CHOKE SKID. -PRESSURE TEST ALL LINES TO 250/3,500 I PSI 14:00 15:00 1.00 WHSUR ! P WHDTRE 11 CONDUCT H2S/RIG EVACUATION DRILL WITH I AFTERNOON CREW FOLLOWED BY AAR. I I-EVERYONE REPORTED TO SAFE AREA IN A TIMELY FASHION. 15:00 - 16:30 1.50 CLEAN P CLEAN DISPLACE FREEZE PROTECT FROM WELL -PJSM ON DISPLACING FREEZE PROTECT FROM WELL. -PUMP 20 BBLS DOWN IA TAKING RETURNS 1 UP TUBIN G BACK TO F C O WBA LO CK TANK -PUMPED @ 450 PSI WITH 2.5 BPM. 1 -CHANGE ALINGMENT TO PUMP 80 BBLS DOWN TUBING AND TAKE RETURNS UP IA I I BACK TO FLOWBACK TANK -PUMPED©5.5 BPM WITH 2,000 PSI. Printed 8/30/2013 12:08:35PM i ■ • /* ,,,,, ' /// ,,,:e",,A.,7 7,X97 7, ..., 4,.4' z;;f://4.',w",l',.5-,-,41".1.,,*--"Cil,"4//1''"i 1,, ,,,,/1%.,4;//)/0,/,'".4-4(01:074;#!",*444,,,,40":"7,1*,...,iilri,,A4/4°470,4440A1 7, j./.4fr,,/1//:/,';,,/,,„fli ,,;;„0."/Y' ,(,,,k,,e/f7, .‘,//,,, , , ,.*/„,j/,e„,„7 .co, ,,,, A/4,,,,„4/11,,itte%V/Z,Z.,31**/.4,';!M;V:V,ii'X;:4 71:/,.4/.;Yri/t':>,,,i,/,0// f ''''''Z''''''X'''.:47';,,,,, ,/"///.1/1"f///,/,:/. 4;1:;;;,„I',/.37H::,,A7.,„lr?//r/');'/A;-,://///,/,1:'',1(frozi,/?///:////ds,11'::,/:;,‘>441";/,*14„s",./,'e.,/z".'',„/L''''',/;1,1.:14/21;;C:,1;,/,'#'5,,,,Y l/W,''lir'4„itiH“,e,,',/;)„,:x"„//,',/,,„'.'Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) I Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:0O:OOAM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.O0usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 19:30 3.00 CONDHL ' P CLEAN I CIRN WELL. CIRCULATE CULATE&BOTTOMS CONDITIOUP DOWN THE TUBING,TAKING RETURNS UP THE IA @ 5.5 BPM WITH 2,000 PSI I-MONITOR WELL FOR 10 MINS. WELL STATIC -BLOW DOWN CHOKE PRESURE MANIFOLD VALVE. &LINES. 19:30 22:00 2.50 WHSUR P T WHDRE INSTALL BACK -PJSM W/DSM ON INSTALLING BPV. ATTEMPT TO TEST LUBRICATOR W/NO SUCESS. FUNCTION WING AND MASTER VALVES ON TREE. -TEST LUBRICATOR 250 PSI/3,500 PSI FOR 5 CHARTED MINS EACH. -INSTALL BPV. 1 22:00 - 00:00 2.00 WHSUR P WHDTRE TEST BPV -PJSM ON TESTING BPV. S TB O RE OPER L TEST BPV FTELOW ENSU TO 500 PR PSI FOR INE 10 UP CHARTED WALK LINE MIN. -BLOW DOW MUD PUMP LINES. 8/1/2013 00:00 - 01:00 1.00 WHSUR P WHDTRE 1 NIPPLE DOWN N 4-1/16"FMC TREE. I +- JSM. NIDADAPTERFLANGEAND41/16" — FP' MC TREE. 01:00 - 02:00 1.00 WHSUR P DECOMP {I OBTAIN PARAMETERS ON TUBING HANGER RETRIEVAL TOOLS. I 12-1/4 TURNS TO THE LEFT TO ENGAGE THE HANGER RETRIEVAL TOOL. 9 RN E TO A BLANKING AT TO PLTHU G RETRIEVALTOOL.LEFT ENGGE THE I 9-1/2 TURNS TO THE RIGHT TO RELEASE THE BLANK RETRIEVAL TOOL. 02:00 - 04:00 2.00 BOPSUR P DECOMP NIPPLE UP 13-5/8"5M BOPE STACK. 04:00 - 10:00 6.00 I BOPSUR P DECOMP CHANGE OUT PIPE RAMS. CHANGE LOWER RAMS TO 3-1/2"x 6"VBR. CHANGE UPPER RAMS TO 2-7/8"x 5"VBR. INSPECTED BLIND/SHEAR RAMS. `SPILL DRILL WITH CREW` � I 1 10:00 - 12:30 2.50 BOPSUR P I DECOMP RIG UP BOP STACK. PJSM,TO RIG UP BOP STACK. -INSTALL TURM BUCKLES. I INSTALL CENTER RISER UP BOP AND STACK.FLOW LINE. I INSTALL COVER PLATES ON DRIP PAN UNDER FLOOR. — — I INSTALL MOUSE HOLE. I Printed 8/30/2013 12:08:35PM • • ""! ,19/' ,'",/,,:-,-*',//'./';'•.°,0 4,7',",.//,'-',77,/,,,i'''4/1'4,,,,,,,, 7i''.:". .//977,.%,,,eW'''%:4-72,,,,i',...,,,4 TX,V,,::.„,, "fill?,7441,k,.,:,,,'/64'419; Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 I End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) 1 Project:Prudhoe Bay I Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date 1 From-To I Hrs I Task Code NPT 1, NPT Depth Phase 1 Description of Operations (hr) (usft) 12:30 - 00:00 I 11.50 BOPSUR P ! 1 DECOMP TESTING BOP'S -FUNCTION TEST BOP'S FROM MAIN. -BREAK DOWN 4"&4-1/2"SAFETY JOINT I ASSY. 1 -M/U 4"TEST ASSY. I 1 1 TEST HYDRAULIC AND MANUAL IBOP ON TOP DRIVE,250 PSI/3,500 PSI FOR 5 , 1 ! , I CHARTED MINS.EACH. !-SHELL TEST BOP STACK,TO 250 PSI/3,500 'PSI. -WELL KILL DRILL. -TEST 2-4"XT39 FOSV,2-41/2"IF FOSV,1-4" XT39 DART VALVE,TO 250 PSI/3,500 PSI FOR 5 CHARTED MINS.EACH. I*OA PRESSURE AT 00:00 HRS.=0 PSI *LOUIS GRIMALDI W/AOGCC WAIVED RIGHTS TO WITNESS AT 07:08 HRS ON 7-1-13. 8/2/2013 00:00 - 02:00 2.00 BOPSUR P DECOMP TEST BOPE -SUCK OUT BOP STACK. 1 I-INSTALL 4-1/2"TEST ASSY. -TEST UPR&LPR TO 250 PSI/3500 PSI FOR 5 CHARTED MINS EACH. j --TEST HYDRAULIC DRAW DOWN ON CHOKE LAND MANUAL CHOKE. -TEST#3 KILL LINE VALVE IN PITS&BLIND 1 SHEAR RAMS TO 250 PSI/3500 PSI FOR 5 I CHARTED MINS EACH. 02:00 - 02:30 , 0.50 BOPSUR P � DECOMP � PJSM ON BLOWING DOWN CHOKE AND KILL i LINE,CHOKE MANIFOLD AND SUCK OUT BOP STACK. 02:30 - 06:30 4.00 BOPSUR T P DECOMP I R/U TO PULL BLANKING PLUG&BPV. 1 1-R/U DUTCH RISER&DSM LUBRICATOR. 1 1 TEST SAME TO 250 PSI/3500 PSI FOR 5 1 CHARTED MINS EACH. I *DUTCH RISER&LUBRICATOR TEST WAS LEAKTIGHT AND LESS THAN 250 PSI DECLINE IN LAST 5 MINS. -BREAK OUT LUBRICATOR AT QUICK TEST SUB. I 1-SUCK OUT STACK. --- -PULL ISA BLANKING PLUG. 106:30 - 09:30 3.00 BOPSUR P DECOMP I PULL BPV. -M/U DSM LUBRICATOR TO QUICK TEST SUB. -TEST BREAK AT QUICK TEST SUB TO 3500 PSI. TEST WAS LEAK TIGHT. 1-PULL BPV. -L/D DSM LUBRICATOR&DUTCH RISER. 09:30 10:30 1.00 PULL P I DECOMP PREPARE TO POH&L/D 4-1/2"COMPLETION II I STRING. -INSTALL BAILS&4-1/2"ELEVATORS. '-M/U X-OVER TO FOSV FOR PULLING TBG. -M/U SAFETY JNT W/FOSV. -R/U STACK TONGS FOR PULLING 4-1/2" COMPLETION STRING. 10:30 - 12:00 1.50 PULL 1 P i I DECOMP 1 PULL HANGER TO FLOOR. 1 -156K TO PULL HANGER FREE. I i -PUW=156K Printed 8/30/2013 12:08:35PM '/ Arto*:*".7'440:)4'1%/*//14:0--1''''',C'::::,-:;;:l4>-1):.•>:74'/744V74.77,,,,f-e/7.1fr,;(- ///, ,,,,C-C,4,7,;;:%t?-1.41-''''7,,,,02/04-').'",„/",'("7:,;0/4 ,-7/%;-,j4,7>1!"4-'/12.,;;:,e'7"1"1 Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 ' End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Let:070°15'58.646"6 Long: 1 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.O0usft(above Mean Sea Level) Date From-To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) (usft) ' 12:00 - 13:00 1.00 PULL P 1 DECOMP ,PJSM CIRC B/U THOUGH MUD/GAS SEPERATOR AT 6 BPM W/320 PSI. -CIRCULATED TOTAL OF 500 BBLS THROUGH MUD/GAS SEPERATOR. *OA PRESSURE UP TO 500 PSI AFTER 1 CIRCULATION. BLEED DOWN TO 0 PSI TO rFLOW BACK TANK. 113:00 - 15:00 2.00 PULL P DECOMP j L/D TUBING HANGER. -MONITOR WELL FOR 10 MINS. WELL STATIC. -OPEN ANNULAR PREVENTER. -LID TBG HNG&LANDING JNT. -M/U 4"DP SAFETY JNT W/8'PUP JT&4" FOSV. 15:00 15:30 0.50 PULL 11 P DECOMP 1BLOVV DOWN CHOKE&TOP DRIVE. 115:30 - 00:00 8.50 PULL P t DECOMP PULL OUT OF HOLE UD COMPLETION I I STRING. -PJSM ON POOH,LID TBG. 1-POOH F/10,380'TO 2,424 LID 4-1/2" COMPLETION STRING. I 1 *D2 KICK WHILE TRIPPING DRILL I*AT 10,380'PUW=154K,SOW=137K AT 2,424'PUW=76K,SOW=78K *AT 00:00 HRS 189 JTS OF 4-1/2"TBG&2-GLM ASSY LID. *OA PRESSURE AT 00:00 HRS=50 PSI 8/3/2013 00:00 - 00:30 0.50 I PULL 1 P DECOMP PJSM. LUBRICATE RIG. 00:30 - 02:30 2.00 PULL P DECOMP LAY DOWN 4 1/2"12.6#L-80 IBT TUBING -PJSM ON POOH,LID TBG. 1-POOH F/2,424'LID 4-1/2"COMPLETION STRING. TOTAL OF 249 JTS OF 4-1/2"TBG, 1 13-GLM,1-X-NIPPLE AND 1-CUT JNT(2.75' LONG/OD=4-7/8") 02:30 - 03:30 1.00 PULL P DECOMP CLEAR RIG FLOOR -PJSM. CLEAN&CLEAR RIG FLOOR OF ALL 4-1/2"TBG PULLING&HANDLING EQUIPMENT. 03:30 - 04:30 1.00 I BOPSUR P DECOMP INSTALL WEAR RING 1-PJSM. R/U&INSTALL WEAR RING.(OD= 13-3/8",ID=8-15/16,LENGTH=1.03') 104:30 - 06:30 2.00 CLEAN P 1 DECOMP Ii P/U BAKER POLISH MILL/SCRAPER ASSY. 1-PJSM. MOB BAKER 7-1/2"POLISH MILLx 19-5/8"SCRAPER ASSY TO FLOOR. -M/U 7-1/2"POLISH MILL x 9-5/8"SCRAPER ASSY. 06:30 - 11:30 5.00 1 CLEAN P DECOMP RIH W/BAKER POLISH MILL/SCRAPER ASSY. I -RIH W/BAKER POLISH MILL/SCRAPER E ASSY,P/U 4"DP F/PIPE SHED TO 3,500'. _-D1 KICK DRILL&AAR 11:30 12:00 0.50 I CLEAN 1 P DECOMP SCRAPE 9 5/8"CASING AT PACKER SETTING I 1 1 1 , 1 DEPTH OF 3,500'. , 1 ' -ROTATE AND RECIPROCATE SCRAPER 5 PASSES -PUMP 5 BPM,380 PSI,RPM=40,1K TORQUE 12:00 12:30 0.50 j CLEAN P DECOMP SERVICE RIG. , 1-GREASE AND INSPECT DRAW WORKS AND 1 1ST-80 Printed 8/30/2013 12:08:35PM • • • ii * am + ;? ,4+ a iv .�.�+s, s 1 .� �m ;� 4 A . ,; Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 I End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°1558.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date I From-To Hrs Task Code I NPT NPT Depth I Phase I Description of Operations (hr) (usft) 12:30 17:00 4.50 CLEAN P DECOMP RIH W/BAKER POLISH MILL/SCRAPER ASSY. -RIH W/BAKER POLISH MILL/SCRAPER !ASSY,P/U 4"DP F/PIPE SHED,F/3,507'TO 8,510' 17:00 19:30 2.50 CLEAN P DECOMP SLIP AND CUT DRILL LINE -PJSM. HANG BLOCKS,SLIP OFF LINE,SLIP 1ONLINE SERVICE TOP DRIVE,BLOCKS,INSPECT BRAKES AND LINKAGE,RESET CROWN-O-MATIC. 19:30 - 20:00 0.50 CLEAN P DECOMP F RIH W/BAKER POLISH MILL/SCRAPER ASSY. -RN W/BAKER POLISH MILL/SCRAPER ASSY,P/U 4"DP F/PIPE SHED,F/8,510'TO 8,605' 20:00 - 22:00 2.00 CLEAN N RREP 8,605.00 , DECOMP TOP DRIVE INOPERABLE -TROUBLE SHOOT TOP DRIVE -CHECK OIL LEVEL,RESET TOP DRIVE I HOUSE -CALL OUT MECHANIC AND CHECK 1 HYDRAULIC CARTRIDGES FOR DEBRIS '-FOUND ROCKS IN CARTRIDGES,CLEANED ,OUT AND RE-ASSEMBLED `-TOP DRIVE OPERATIONAL. 22:00 - 00:00 2.00 CLEAN P DECOMP DRESS LINER TIE-BACK SLEEVE. -OBTAIN SPR=(PUMP 2)20 SPM AT 40 PSI/ 30 SPM AT 140 PSI(PUMP 1)20 SPM AT 40 PSI I/30 SPM AT 130 PSI -OBTAIN MILLING PARAMETERS=CIRC AT 5 BPM W/570 PSI,30 RPM WITH 3-5 K TORQUE, P/U WEIGHT=172K SOW=145K ROT=160K -INCREASE RPM TO 50 WITH 5-7K TORQUE I I -RIH AND TAG AT 8,691'WITH 10K WOB,LINER I TOP AT 8,686' -INCREASE PUMP RATE TO 12 BPM WITH 2,380 PSI -PUMP HI-VIS SWEEP SURFACE TO SURFACE,VOLUME OF 608 BBLS AND 6,029 STROKES *OA PRESSURE AT 00:00 HRS=300 PSI 8/4/2013 ,00:00 00:30 0.50 CLEAN II P i DECOMP I LUBRICATE RIG 00:30 02:30 2.00 I CLEAN P DECOMP POOH W/BAKER POLISH MILL/SCRAPER I ASSY. 1 -PJSM. POOH F/8,691'TO 3,500'. 02:30 03:00 0.50 CLEAN P DECOMP I CLEAN PACKER SETTING AREA FOR I I PROPOSED LINER TOP'ZAP'PACKER -ROTATE&RECIPROCATE AT 3,500'WITH I SCRAPER,PUMPING 6 BPM W/420 PSI,20 I I RPM W/1K TORQUE. 03:00 - 04:00 1.00' CLEAN P DECOMP 'POOH W/BAKER POLISH MILL/SCRAPER ASSY. -POOH F/3,500'TO 450'. 04:00 06:30 2.50 l CLEAN P DECOMP L/D BAKER POLISH MILL/SCRAPER ASSY. II-PJSM ON PULL NON-SHEARABLES ACROSS 1 THE STACK. -MONITOR WELL FOR 10 MINS. WELL STATIC. -POOH,RB DRILL COLLARS,UD BAKER POLISH MILL/SCRAPER ASSY. I•MILL TATTLE TAIL INDICATES GOOD POLISH OF LINER TIE-BACK SLEEVE. Printed 8/30/2013 12:08:35PM • • • • 7,77:.,,,,,-4-7,--,,, ,,,,,440,,,41,-//CO/4 '''/ I" ',;:‘,/...(747#4**7( Ad` i`g 7 4/7//.., ° „ 1 1 1` /j,r./i' Common Well Name:05-16 ._.:2.o Event Type:WORKOVER(WO) 1 Start Date:7/30/2013 1 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 1 Spud Date/Time:9/1/1977 12:00:00AM I Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. j UWI:/Lat:070°15'58.646"6 Long: :0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase I Description of Operations (hr) (usft) 06:30 - 10:00 3.50 EVAL P DECOMP RIH W/9-5/8"RTTS PACKER PER 1 1 HALLIBURTON REP. -PJSM. MOB 9-5/8"RTTS TO RIG FLOOR. :-M/U 9-5/8"RTTS&RIH,P/U 4"DP F/PIPE I SHED TO 4,000'. 10:00 - 10:30 0.50 EVAL P DECOMP 1PJSM. SET RTTS PACKER PER HALLIBURTON I REP AT 4,000'. 10:30 12.00 I 1.50 EVAL P DECOMP PRESSURE TEST 9 5/8"CASING F/4,000'TO : 'SURFACE -PJSM. R/U TO PRESSURE TEST 9-5/8"CSG. I-TEST 250 PSI LOW FOR 5 CHARTED j MINUTES/3,500 PSI HIGH FOR 30 CHARTED MINUTES 12:00 - 12:30 0.50 EVAL P 1 t DECOMP RECEIVED CONFIRMATION TO PROCEED FROM TOWN -RELEASE RTTS F/SET POSITION. POOH& RACK BACK ONE STAND OF DRILL PIPE. I '*WTL APPROVED TEST OF 9-5/8"CSG AT 12:00 HRS. _ *OA 50 PSI i 12:30 - 14:30 2.00 EVAL P DECOMP ;POOH&L/D 9-5/8"RTTS :-PJSM. BLOW DOWN CHOKE/KILL LINES -POOH FROM 3,914'W/9-5/8"RTTS PACKER& L/D SAME. I 14:30 - 19:30 5.00 EVAL P DECOMP M/U&RIH W/HES 7"RBP. -MOBILIZE 7"RETRIEVABLE BRIDE PLUG, RIVER SAND,SAND HOPPER TO RIG FLOOR. -PJSM. M/U HES 7"RBP&RIH W/SAME TO 7,142'. ' *SLOW DOWN RIH SPEED WHILE PASSING BY 9-5/8"FOC COLLARS AT 2,316'&2,443'. 19:30 - 20:00 0.50 DHB P i DECOMP GREASE AND INSPECT ST-80,DRAW WORKS. -DRAW WORKS OVER HEATING.ALLOW TIME FOR DRAW WORKS TO COOL DOWN 20:00 - 21:00 1.00 DHB P DECOMP RIH W/HES 7"RBP. -RIH W/7"RBP F/ 7,142'TO 8,566'. 21:00 - 22:00 1.00 DHB P DECOMP OBTAIN PARAMETERS&SET HES 7"RBP -PUW=165K,SOW=145K -OBTAIN SPR: #1=20 SPM AT 30 PSI/30 SPM AT 120 PSI #2=20 SPM AT 40 PSI/30 SPM AT 120 PSI -PJSM. RIH F/8,566 TO 8,661'. -P/U TO PUW 165K,5 TURNS TO THE RIGHT& LOCK IN TORQUE. -WORK TORQUE DOWN -ENSURE RBP IS IN TRAVEL MODE BEFORE RIH TOLAT 8,686'. -RIH F/8,661'TO 8,800'. -TURN STRING 3-ROUNDS TO THE LEFT TO SET RBP. SET DOWN 15K ON TOP RBP. TOOK 10K OVERPULL TO RELEASE F/RBP. -SET BACK DOWN 15K ON TOP RBP. TURN STRING 1/2 TURN TO THE LEFT. TOOK 10K OVER PULL TO RELEASE F/RBP. -RBP SET AT 8,800'.TOP OF RBP FISHING NECK AT 8,796'. 1 i j -POOH F/8,800'TO 8,724'. Printed 8/30/2013 12:08:35PM I • ice' / / �" % �� / / N ,� f '.�',x'f�F .:i�rr�v { % /75,/,,,...0", .4;:„4,19 ,-® b°' 1 ��f%r ,,:. �s a {e �, gT 7` i "4.„��'.K7,./7 :,�'/ �:/i.,<",////,./�� :. / w ' 12,/, ' %� a ® W.' 0;§Sy-d .® . :i fi , ce Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) - (usft) 22:00 00:00 1 2.00 DHB P DECOMP TEST 7"RBP&9-5/8”CSG -PJSM. TEST RBP&9-5/8"CSG TO 290 PSI FOR 5 CHARTED MINUTES(PRESSURE HELD SOLID) *5-STROKES TO PRESSURE UP TO 290 PSI 1-PRESSURED UP TO 3,600 PSI "72-STROKES TO PRESSURE UP TO 3,500 I PSI I-PRESSURE BLED F/3,600 TO 3,250 PSI IN 1 I MIN,3,250 TO 2,980 PSI IN 2 MIN,2,980 TO 2,750 PSI IN 3 MIN,2,750 TO 2,550 PSI IN 4 MIN,2,550 TO 2,370 PSI IN 5 MIN. !*LOSS RATE APPROXIMATELY.5 BPM I-BLEED OFF PRESSURE F/2,370 PSI TO 0 PSI, 11.5 BBLS BLED BACK -ESTABLISHED INJECTION RATES: 0.25 BPM AT 3,390 PSI,0.50 BPM AT 3,500 PSI,.75 BPM !AT 3,650 PSI I-10 MINUTE FLOW CHECK *OA 120 PSI AT 00:00 HRS :*DURING TESTING,OA PRESSURED UP F/100 TO 180 PSI 8/5/2013 00:00 - 00:30 0.50 DHB P DECOMP l SERVICE RIG. I. 00:30 - 01:00 0.50 DHB P DECOMP I DUMP 50'20/40 RIVER SAND ON TOP OF RBP -PJSM. R/U HOPPER W/LINE FOR BRINE ON 4"DP. -DUMP 24 SKS/1200#OF 20/40 RIVER SAND DOWN 4"DP. -ALLOW 30 MINS FOR SAND TO FALLAND 03:30 2.50 DHB SETTLE. 01:00 P DECOMP TAG TOP OF SAND -RIH&ATTEMPT TO TAG TOP OF SAND. TAG AT 8,796'W/5K DOWN.(TOP OF RBP FISHING 1 NECK) I-P/U TO 8,690'. CIRCULATE AT 1 BPM W/80 1 I PSI TO VERIFY DP FREE OF SAND. I I-WAIT 15 MINS&ATTEMPT TO TAG TOP OF !SAND. TAG TOP OF RBP FISHING NECK AT I 1 8,796'W/5K. -P/U TO 8,724'. 03:30 - 06:30 3.00 DHB P 1 DECOMP I DISCUSS PLAN FORWARD WITH TOWN. I-R/U HOPPER W/LINE FOR BRINE ON 4"DP. ,-DUMP 24 SKS/1200#OF 20/40 RIVER SAND DOWN 4"DP. -ALLOW 30 MINS FOR SAND TO FALLAND SETTLE. -RIH&ATTEMPT TO TAG TOP OF SAND. TAG TOP OF RBP FISHING NECK AT 8,796'W/5K. ,-POOH F/8,796'TO 8,566'. -PUMP 40 BBLS DOWN DP AT 2 BPM W/40 PSI. SHUT DOWN PUMP. -ALLOW 15 MINS FOR SAND TO FALL AND I I SETTLE. -RIH F/8,566'&TAG TOP OF SAND AT 8,758'. Printed 8/30/2013 12:08:35PM . 0 • <,4,,,,e,/(,-,y7 47 44'--,',''-.4-///1/.;-",, „-',44- -V/ "2 /..,"////r4/1 /0'47140'4.0' "V'" -.''�!i'" �/ ':% of rr �r S 5�i` f/';!5` r ,- 7s r "�irG,' ii A6 >, Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 1 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI /Lat:070°15'58.646"6 Long: 10148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date I From-To I Hrs 1 Task Code NPT NPT Depth Phase Description of Operations —' (hr) H 06:30 07:00 0.50 1 D B P DECOMP CLEAR DP AFTER TAGGING SAND 1 1 1-POOH TO 8,549' 1-PUMP DOWN DP PRESSURED UP TO 500 PSI W/ANNULAR PREVENTER OPEN. DP PLUGGED OFF. -BLED OFF PRESSURE. WORK DRILL STRING 18,ATTEMPT TO UNPLUG. 1-PRESSURED UP TO 2,000 PSI. DP PLUGGED T OFF. 107:00 - 11:00 4.00 DHB 1 P DECOMP POOH&L/D RBP RUNNING TOOL I 1-MONITOR WELL FOR 10 MINS. WELL STATIC. -PJSM. DROP 2.4"OD DRIFT W/100'TATTLE 1 TAIL. -POOH F/8,549'. L/D RBP RUNNING TOOL. *AT 4,000 MD FROM SURFACE,DP WAS DRY, 1 I INDICATING SAND FELL OUT. *DRIFT RECOVERED IN RBP RUNNING TOOL. 11:00 - 11:30 0.50 BOPSUR P DECOMP PULL WEAR BUSHING. -R/U&RETRIEVE WEAR BUSHING. 11:30 - 12:00 0.50 BOPSUR P DECOMP TEST BLIND/SHEAR RAMS '-CLOSE BLIND/SHEAR RAMS&TEST FROM BELOW TO 500 PSI FOR 10 CHARTED MINS. *TEST WAS LEAK TIGHT WITH NO VISIBLE LEAKS. *OA PRESSURE=100 PSI 12:00 - 13:00 1.00 BOPSUR , P DECOMP EVACUATE BOP STACK OF FLUIDS F/TOP OF TESTED&CLOSED BLIND/SHEAR RAMS -MOBILIZE CELLER PUMP&LINES TO RIG FLOOR. -EVACUATE OUT BOP STACK OF FLUIDS 13:00 16:00 3.00 BOPSUR ' P DECOMP SWAP UPPER PIPE RAMS TO 7"FIXED RAMS -PJSM. REMOVE 2-7/8"x 5"VBR's FROM UPR. -INSTALL 7"FIXED RAMS IN UPR. I-MOBILIZE 7"CENTRILIZERS&7"LINER RUNNING&HANDLING EQUIPMENT TO RIG - — j FLOOR&PREP TO RUN 7"SCAB LINER. 16:00 - 19:00 1 3.00 BOPSUR P DECOMP TEST 7"FIXED RAMS -PJSM. M/U 7"TEST ASSY W/TEST PLUG& RIH. -PRESSURE TEST 7"UPR TO 250 PSI/3,500 PSI FOR 5 CHARTED MINS EACH. R- /D 7"TEST ASSY. 19:00 - 19:30 0.50 BOPSUR I P DECOMP INSTALL WEAR BUSHING. -R/U&INSTALL WEAR BUSHING.(ID=8.9375) 19:30 - 22:30 3.00 CASING P DECOMP I RUN 7"26#L-80 VAMTOP SCAB LINER -PJSM ON RUNNING 7"SCAB LINER -RIH WITH 7"SCAB LINER TO 265'. 22:30 - 23:30 1.00 CASING P DECOMP I D-1 KICK WHILE TRIPPING DRILL 1-WELL SHUT IN TIME=7 MINUTES 4 -AAR 23:30 - 00:00 0.50 CASING P DECOMP 1 RUN 7"26#L-80 VAMTOP SCAB LINER -RIH WITH 7"SCAB LINER F/265'TO 511'. *FILL 7"CSG EVERY 5 JNTS. *OA PRESSURE AT 00:00 HRS=95 PSI 8/6/2013 00:00 09:30 9.50 CASING P DECOMP RUN 7"26#L-80 VAMTOP SCAB LINER. I 1-CONTINUE RUNNING IN WITH 7"SCAB LINER 1 FI 511'TO 2,884'. -FILL EVERY 5 JOINTS. I-D1 KICK WHILE TRIPPING DRILL FOLLOWED BYAAR. 3.5 MINS TO SECURE WELL. Printed 8/30/2013 12:08:35PM I • %% t lr=e ti-'7,,, 1:44.evd,Y.-//,,,,I,/, ("""AP1,2,,,/'/./71.44..%7;e:0:--*-'i YAZ.X-7/ ' 4#91",/,''.4.4/10f,i44/// 1/2!,,,./ / r i r %,'r`. / .fy,-_ Ff Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) 1 Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay I Site:PB DS 05 Rig Name/No.:DOYON 14 I Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. :UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date I From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 11:00 1.50 ; CASING P DECOMP MAKE UP LINER HANGER AND PACKER. -RIG DOWN CASING EQUIPMENT AND 1 CHANGE BAILS. 11:00 - 12:00 I 1.00 CASING P DECOMP ''PICKUP ONE STAND AND RUN PACKER DOWN 30'. -CIRCULATE LINER VOLUME,6 BPM AT 230 I `PSI. -UW 162K,DW 160K. 12:00 - 12:30 0.50 CASING P I 1 DECOMP GREASE AND INSPECT DRAW WORKS AND ST-80. 12:30 - 14:30 2.00 CASING 1 P , DECOMP CONTINUE TRIPPING IN WITH 4"DRILL PIPE :FROM 5,398'TO 8,627' 14:30 - 15:00 0.50 CASING III P ; DECOMP 'OBTAIN PARAMETERS -UW 200K,DW 170K 1-CIRCULATE 2 BPM WITH 80 PSI,WASH 1 DOWN FROM 8,627'TO 8,672' SLOWED PUMPS TO 1 BPM WTH 60 PSI, PRESSURE INCREASED INDICATING ENTERING NO-GO -BLEED OFF PRESSURE. 1-CONTINUE RIH TO 8,691'IN TO TIE BACK 1SLEEVE. PRESSURE UP TO 500 PSI AND PULL UP TO PRESSURE DROP AT 8687',BOTTOM OF MULE SHOE. 15:00 - 16:00 1.00 ' CASING P , DECOMP 'MAKE UP ROTATING CEMENT HEAD -MAKE UP VALVES AND CEMENT LINES. -TORQUE UP TO DRILL STRING AND TOP DRIVE. 16:00 - 16:30 0.50 CASING P DECOMP CIRCULATE THROUGH CEMENT PORT ON CEMENT HEAD WITH RIG. -5 BPM,480 PSI. 16:30 - 17:00 0.50 CASING P DECOMP PREJOB SAFETY MEETING WITH ALL HANDS 1 FOR CEMENTING AND LINER SETTING PROCEDURE. 17:00 - 19:00 2.00 CASING P DECOMP I CEMENT 7"SCAB LINER 1-FILL LINES WITH WATER AN PRESSURE 1 TEST TO 250 PSI LOW AND 4500 PSI HIGH FOR 5 MINUTES. 1-PUMP 156 BBL OF 15.8 PPG CLASS G I 1 CEMENTAT 5 BPM,20 PSI. -SLIRRY DENSITY:15.8 PPG,YIELD:1.17 FT3/SK,MIX FLUID:5.196 GAL/SK. I -TOTAL OF 749 SACKS(94 LB.) -SWAP TO RIG PUMPS. -DROP DRILL PIPE WIPER DART,POSITIVE INDICATION ON TATTLETALE DART LAUNCHED. -DISPLACE CEMENT WITH RIG. -220 BBL DISPLACED AT 5 BPM:ICP 20 PSI 1 17%FLOW,3 BPM FCP 1740 PSI 10%. -REDUCED PUMPS TO 3 BPM FOR LATCH UP TO LINER WIPER DART,NO LATCH UP OBSERVED ON PUMP PRESSURE. -REDUCED PUMPS TO 3 BPM PRIOR TO PLUG 1 1 BUMP. 3 BPM 1740 PSI. ;-TOTAL DISPLACEMENT VOLUME 220 BBL AT 196%PUMP EFFICIENCY. -CEMENT IN PLACE AT 19:06 Printed 8/30/2013 12:08:35PM • • • 7(,/,:°. 'j j "/ /. '; �„''� �;,2 ; F9 s/ �.- 'l / / - Common Well Name:05-16 I AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 1X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay I Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date From-To 1 Hrs 1 Task 1 Code NPT 1 NPT Depth I Phase Description of Operations I- _ (usft) 19:00 - 19:30 1 0.50 1 CASING P DECOMP SET LINER HANGER (hr) -PRESSURE UP TO 3000 PSI. -SET DOWN 40K TO SET HANGER. I I -BLEED OFF PRESSURE TO 1000 PSI. ROTATE TO RELEASE RUNNING TOOL. -PICK UP DRILL PIPE TO PRESSURE DROP,5'. I -CIRCULATE 50 BBL AT 5 BPM WITH 310 PSI. -SET DOWN 57K TO SET LINER TOP PACKER. 119:30 - 20:30 1.00 1 CASING P DECOMP CIRCULATE CEMENT OUT OF THE HOLE. , 9 BPM,650 PSI. I !-LINED UP ON IA WITH ANNULAR CLOSED TO FLOW BACK TANK TO TAKE RETURNS I OUTSIDE AT 150 BBL TOTAL DISPLACEMENT. I STARTED SEEING CEMENT BACK TO FLOW BACK TANK AT 166 BBL. -CLEANED UP AFTER 230 BBL. CONTINUED PUMPING TO 240 BBL DISPLACED. 1*TOTAL OF 64 BBLS OF STRUNG OUT CEMENT RETURNS OBSERVED. 1 : , 1-MONITOR WELL FOR U-TUBE FOR 10 1 1 MINUTES. STATIC. OPEN WELL. 20:30 21:30 1.00 CASING P DECOMP RIG DOWN CEMENT HEAD. 1 PJSM. 4-BLOW DOWN LINES. 1 1 -RIG DOWN CEMENT LINES AND LAY DOWN I 1 I CEMENT HEAD. 121:30 23:00 1.50 I CASING P DECOMP 1 TRIP OUT WITH LINER RUNNING TOOL. 1-PJSM,POOH STANDING BACK4"DRILL PIPE —. F/3,420'T/SURFACE. 123:00 - 23:30 0.50 CASING P DECOMP LAY DOWN LINER RUNNING TOOL. -PJSM. 1 -SERVICE BREAK TOOL AND LAY DOWN. 1-FIRE DRILL. CRT 1.5 MINUTES. - 23:30 00:00 0.50 BOPSUR P DECOMP 1PULL WEAR BUSHING. -PJSM. 1*OA PRESSURE AT 00:00 HRS=100 PSI 8/7/2013 00:00 00:30 0.50 BOPSUR 1 P DECOMP SERVICE RIG. 00:30 - 01:00 0.50 BOPSUR 1 P DECOMP !JET STACK. -PJSM. -RIG UP JETTING TOOLAND FLUSH STACK OF ANY RESIDUAL CEMENT. -PUMP AT 8 BPM WITH 80 PSI.PUMP I 'PRESSURE. -TOTAL OF 20 BBLS PUMPED. 01:00 03:30 2.50 BOPSUR 1 P DECOMP CHANGE OUT UPPER PIPE RAMS. , -PJSM. , -REMOVE 7"FIXED RAMS. -CLEAN RAM CAVATIES. I-INSTALL 9 5/8"FIXED RAMS. 03:30 - 05:30 2.00 BOPSUR P DECOMP 'PRESSURE TEST 9-5/8"RAMS. L 1-PJSM. INSTALL TEST PLUG WITH 9-5/8"TEST JOINT. -TEST 9-5/8"FIXED RAMS TO 250 PSI LOW, 13500 PSI HIGH. -FIRE DRILL=1:30 05:30 06:00 0.50 BOPSUR P DECOMP 1 PJSM -INSTALL WEAR RING(ID 8 15/16' 1.03"LONG) 06:00 - 07:00 1.00 EVAL 1 P DECOMP PJSM I -R/U E-LINE FOR USIT LOG Printed 8/30/2013 12:08:35PM • • r# / Fl...:: e r � � /fie s�'! %�' %i, r .�i r �./e ® /i :// rJ` / r" dar1 w+- •sii P �„ r . � / Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 I Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22 460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date I From-To Hrs 1 Task I Code NPT NPT Depth 1 Phase Description of Operations (hr) (usft) 1 07:00 - 11:00 1 4.00 EVAL P ' DECOMP RIH WITH E-LINE FOR USIT LOG IN ' CEMENT/CORROSION MODE. -FIRST RUN FROM 3,500'TO SURFACE AT 150 I FEET PER MINUTE. I I -SECOND RUN FROM 2,650'TO 100'AT 150 FEET PER MINUTE. -RIG DOWN E-LINE. 11:00 - 12:00 1.00 EVAL ! P DECOMP !RIG UP AND TEST SCAB LINER. -250 PSI FOR 5 MINUTES,3500 PSI FOR 30 I MINUTES -TOOK 5 BBLS TO PRESSURE UP TO 3500 PSI. 12:00 - 12:30 0.50 EVAL P 1 DECOMP COMPLETE PRESSURE TEST ON SCAB LINER -BLEED OFF PRESSURE,BLED BACK 4.75 I BBLS. -SIM-OPS MOBILIZE 9 5/8"RBP TO RIG FLOOR I FOR UPCOMING OPS. _ `OA PRESSURE 95 PSI. 112:30 - 13:00 0.50 EVAL P I DECOMP PJSM 1 1 1-BLOW DOWN KILL LINE -SUCK OUT STACK _,-FIRE DRILL 13:00 - 15:30 2.50 DHB P DECOMP MAKE UP RBP AND RIH FROM 19'TO 2,488 15:30 - 16:30 1.00 DHB P DECOMP OBTAIN PARAMETERS. -PUW=87K,SOW=90K .-CIRCULATE 7 BPM WITH 370 PSI,CIRCULATE SURFACE TO SURFACE WORKING RBP ' SETTING AREA, -TURN 2 TURNS TO THE LEFT AND HOLD TORQUE,SLACK OFF 20K WOB -TURN 1/4 MORE TO LEFT,PUCK UP 10K OVERPULL,SLACK OFF 20K WOB -RBP IS SET COE @ 2,578'TOP OF RBP @ 2,573 16:30 - 18:00 1.50 DHB P DECOMP PJSM ON TESTING RBP. -PRESSURE TEST 250 PSI/3500 PSI FOR 5 MINUTES. -DURING HIGH PRESSURE TEST,ANNULAR LEAKING,BLED OFF PRESSURE AND INCREASED ANNULAR PRESSURE. -PRESSURED TO 3500 PSI AND TEST PASSED -BLED OFF PRESSURE AND RACK BACK ONE STAND DRILL PIPE 18:00 - 19:30 1.50 DHB P 1 DECOMP PJSM -DROP 2200#RIVER SAND WITH SAND - HOPPER DOWN DRILL PIPE. 19:30 - 20:30 1.00 DHB P DECOMP DISPLACE SAND FROM DRILL PIPE. -CIRCULATE 2 BPM AT 40 PSI -CIRCULATE 1 DRILL PIPE VOLUME,26 BBLS -FLOW CHECK WELL,STATIC 20:30 - 21:30 1.00 DHB P DECOMP TRIP OUT OF HOLE WITH RBP SETTING I TOOL. POOH FROM 2,488'TO SURFACE -LAT DOWN RBP RUNNING TOOL 21:30 - 22:30 1.00 CUT 1 P DECOMP MOBILIZE 9 5/8"CASING CUTTER BHA TO RIG I FLOOR. I-BLOW DOWN TOP DRIVE,CHOKE AND KILL I 'LINES. Printed 8/30/2013 12:08:35PM • 4110 r, fir,r r//r�i„ �� r, „�; rr s ;',r rr° .,rr- �r5 fir/ / o 44-4 414"'2(7/#: ":;*,W*;`1,:z";:*.,,,,',: ;)A,Wit`r:7/1.1,ifft” ' ' .*Iii,'"://:;,;••4 '4,;',A1.77,,,,/,;&i,'X'27/ ',z`z ,„,•Ai. •,' Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Rig Name/No.:DOYON 14 Site:ud Date/Time:9/1/1977 12:0 J Bay g p 12:00:00AM I Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UW:/Lat. 070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) L (usft)._. 1,22:30 - 00:00 1.50 CUT P I DECOMP TRIP IN HOLE WITH 9-5/8"MULTI-STRING III CUTTER. PJSM MAKE UP 9 5/8"CASING CUTTER. RIH FROM 12'TO 958'. 'OA PRESSURE 95 PSI 8/8/2013 00:00 - 00:30 0.50 CUT P DECOMP `RIG SERVICE. 00:30 - 01:30 1.00 CUT P DECOMP TRIP IN HOLE WITH MULT-STRING CUTTER. -FROM 958 TO 2479 FT. 01:30 - 03:30 2.00 CUT P DECOMP CUT 9-5/8"CASING. PJSM. -LOTE TOM COLL ,1 FT EP. DEEP. LOCATE CA TOP BOT COL L AR AT AR 2469 AT FT,1 FT P DE SPOT C UTTER 10 FT DOWN FROM 2510 TOFT COLLAR AT 2479 FT. -CIRCULATE UP D i 340 PSI. -ESTABLISH PARAMETERS BOTTOMS AT WITH 4.0 CUTTER BPMAN AT 2479 FT. 80 RPM AT 1 K TORQUE. STAGE PUMP TO 6.0 BPM AND 800 PSI. TORQUE INCREASE TSO 5K. PRESSURE DECREASE TO 350 PSI WITH TORQUE AT 1 K. `CONFIRMED CUT WITH OA PRESSURE INCREASE FROM 0 TO 10 PSI. t 0330 - 05:30 2.00 CUT P DECOMP ARCTIC PACK DISPLACEMENT. PJSM. -INSTALL FOSV ON DP. RIG UP TO CEMENT LINE. RIG UP LRS AND PT LINES: 250/3500 PSI FOR 5 MINUTES. -PUMP 27 BBL 80 DEG DIESELAT 2.0 BPM AND 330 PSI. CLOSE ANNULAR. PUMP 73 BBL DIESEL 80 DEG DIESELAT 2.0 BPM AT 550 PSI. RETURNS OBSERVED AT 3.0 BBL.PUMPED. PUMP 27 BBL 120 DEG 9.8 PPG BRINE AT 2.0 BPM AT 500 PSI. 05:30 - 09:00 3.50 CUT P DECOMP LET DIESEL SOAK. PUMP 40 BBL DEEP CLEAN PILL CHASED WITH 171 BBL HEATED 9.8 BRINE,2 BPM 100 PSI. PUMP TILL DEEP CLEAN PILL TO SURFACE. -PICK UP PUMP RATE FOR ANOTHER 171 BBL, 6 BPM @ 800 PSI. `24 HOUR NOTIFICATION SUBMITTED TO AOGCC AT 0600 HOURS. 09:00 - 12:30 3.50 CUT P DECOMP 1 I 10 MINUTE FLOW CHECK. 1 I 1 1 TRIP OUT OF HOLE. LAY DOWN CUTTER BHA AND MOBILIZE SPEAR TO RIG FLOOR. PULL WEAR RING. 12:30 - 13:30 1.00 CASING P 1 DECOMP PJSM. MAKE UP SPEAR ASSY. MOBILIZE 9 5/8"HANDLING TOOLS TO RIG FLOOR. Printed 8/30/2013 12:08:35PM • • ��//��ee 7,,, ,7„.„,,,,, ..„7„<„,,,,,,,• „A„,,,,, „,.. 407,„:„.„,',,),4,:YI;;','''',OS,,7/0<e'f+';—'4",,,1;,),'", ;if:// / 4./4'7'4V //"./' //../Y,',711 .145,')40e-,-/"...-7 ' „////7"„ ,(,.....,cei:/>!:,'"/„,7''' "4-°` / /-m",,P" /,',/- -7/,/,--r/ ,, io://4„,,,,,,,,,,,e,/,/ „4, 4,;,, , 7, i ////</A/1,ii,"/Vi7,4-7-',,o'''," Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) l Date From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations I (hr)113:30 - 15:00 1.50 CASING P (usft) __ DECOMP RIH WITH 9 5/8 SPEAR ASSY. -FMC TECHNICIONS BOLDS,HAVING 1 DIFFICULTYS WITH LAST LOCK DOWN. 1 I *FMC REPLACE ONE LOCK DOWN SCREW. 1 15:00 15:30 0.50 I CASING P DECOMP LOCK DOWN SCREWS OUT. -PULL ON HANGER 225K,SLACKED OFF I I-PULL 250K TWICE,SLACKED OFF,PULLED I 250K AND HELD WEIGHT. -HANGER BROKE FREE FROM 250K TO 210K, CONTINUE PULLING HANGER WITH 165K TO I 1 RIG FLOOR. 15:30 - 16:30 1.00 CASING P 1 DECOMP lI CIRCULATE THROUGH SPEAR ASSY 8.2 BPM 1 WITH 150 PSI RECIPROCATING PIPE, -AFTER 65 BBLS PUMPED DIVERTED ARCTIC 1 PACK RETURNS TO FLOWBACK TANK 1 ' -SHUT TOP RAMS AND OPENED OA VALVE. 1 1 � -CONTINUE CIRCULATING 6.0 BPM WITH 430 PSI. -TOTAL PUMPED TO FLOW BACK TANK OF 165 BBLS,OVERALL PUMPED 230 BBLS. 16:30 - 17:00 0.50 CASING P - DECOMP 10 MINUTE FLOW CHECK. FLUID LEVEL STATIC. I OBSERVING SOME GAS BREAKING OUT. -SHUT OA VALVE AND LINE UP TO PUMP 1 THROUGH MUD GAS SEPERATOR. -CIRCULATE 6.0 BPM WITH 130 PSI. I-TOTAL PUMPED 181 BBLS. I-10 MINUTE FLOW CHECK FLUID LEVEL STATIC. 17:00 - 21:00 4.00 CASING P ± DECOMP I LAY DOWN 9 5/8"47#BTC CASING AND HANGER. -LAY DOWN CASING HANGER,BREAK OUT TORQUE 50K.WITH RIG PULL TONGS. PJSM TO LAY DOWN CASING. -STEAM CONNECTIONS,ATTEMPT TO BREAK I OUT WITH 50K. 1-APPLY MORE TORQUE,CRUSHING CASING. I-CALLED FOR WACHS SAW. DECOMP WAIT FOR SPEAR ASSY AND WACHS SAW. 21:00 23:00 2.00 CASING N WAIT 2 723.00 I1 -MONITOR WELL. 23:00 - 00:00 1.00 1 CASING ' P 1 DECOMP 1 MAKE UP 9 5/8 SPEAR TO SAFETY JOINT. -BRING WACHS SAW TO RIG FLOOR. 11 Printed 8/30/2013 12:08:35PM • • ;,_ .., ,„ s, ��� s,„r, /,00°,,,,,,,,,, , 0/74::,...,,,,,,,?, ,i,..,A,,,,,,, „5,,,,,,r,,,,,A-4, i.,-;/,:///,,,,,,:.,4.;„,ff,"4, ,,,,,,,:,, /7" /1/4.,:4:::/v./' ,,,f,47#//;,):074.,04-,S,%4;:!er/iit, /9,,N7 b''dvk,<,"%","v4:7/''''/'/'!"/".-9//77;to $49,4417,.,40,./;;/// T,p;,/pl',Ixy7,,,4;4;,/,, //AP 7',X(` 4../' -.`"'511'4v,!?'"'”:,,4;0r. 1."-"C'Y .**/'''''''../;"4"'''''7'''.%2"‘/"44,/'*--/'"1/41*4*Are//fr;;1/-/"4'5' 4" a/4/4// %43.'44/4.,4'`‘P,'"P'74 ..4:, ./''')''''4 4,0177/74''54411j4,44,44444aq4.,'``W"5/"4: Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM 'Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. 1 UWI:/Lat:070 15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date I From-To Hrs 1 Task Code NPT ; NPT Depth Phase 1 Description of Operations 8/9/2013 00:00 - 13:30 13.50 CASING P usft DECOMP LAY DOWN 9 5/8"47#BTC CASING. ;-POOH FROM 2,446'TO CUT JOINT. -BREAK CONNECTIONS WITH RIG PULL TONGS AFTER WARMING UP WITH STEAM. .-WHEN 15K FT/LBS.OBTAINED FROM RIG TONS INSTALL ECKEL POWER TONGS AND --BACK OUT CONNECTION. -ONE CONNECTION WAS UNABLE TO BE BROKE OUT WITH PULL TONGS AND HAD TO BE CUT WITH WACHS SAW. -WACHS SAW RAN BY WELLHEAD 'TECHNICIAN WHILE BAKER FISHING HAND i ON LOCATION FOR SPEAR SAFETY JOINT. 1 -SPEAR SAFETY JOINT AS A WELL 'CONTROL CONTINGENCY ON CUT JOINT. I -RECOVERED CASING HANGER WITH 2'PUP, 1 59 FULL JOINTS OF 9-5/8"BTC CASING,FOUR 120'9-5/8"PUP JOINTS,2 FO COLLARS,ONE CUT JOINT 10.78'LONG WITH 9.6875"OD AT CUT AND 17 BOW SPRING CENTRALIZER'S. ; I*FIRE DRILL. I I*AVERAGE BREAK OUT TORQUE 37K FT/LBS. IWITH RIG PULL TONGS. 13:30 - 18:30 i 5.00 CASING P DECOMP t PJSM,LAY DOWN ALL 9-5/8"CSG TOOLS AND EQUIPMENT. -CLEAN ALL TOOLS AND RIG FLOOR FROM ARCTIC PAK. -BEAVER SLIDE OPERATIONS,LAYING DOWN CSG TOOLS. 1*SIM OPS-CLEAR PIPESHED OF 9-5/8"CSG AND BRING IN TEST JOINT FOR UPCOMING BOPE TEST. 1-DRAIN BOPE STACK AND INSPECT FOR !DEBRIS-ALL GOOD. FLUSH BOPE STACK AND CIRCULATE AT 9.3 BPM WITH 60 PSI AND 1K TORQUE. -RIG DOWN SAFETY JOINTS AND MAKE UP FOSVS FOR UPCOMING BOPE TEST. 18:30 - 19:00 0.50 BOPSUR ! P DECOMP PJSM,ON TESTING BOPE'S WITH 4"AND 1 9-5/8"TEST JOINTS ,*AOGCC REP JOHN CRISP WAIVED WITTNESS TO TEST. 1 19:00 - 20:00 1.00 BOPSUR P DECOMP RIG UP TEST JOINT AND TESTING EQUIPMENT FOR BOP TEST. -FLOOD BOP EQUIPMENT WITH WATER. 20:00 - 00:00 4.00 BOPSUR P r DECOMP 1 BOP TEST. 1 -TEST BOP TO 250 PSI LOW,3500 PSI HIGH FOR 5 MIN EACH. -ALL TESTS CHARTED,SEE ATTACHED BOP :TEST CHARTS. 1-TEST UPPER RAMS WITH 9 5/8"TEST JOINT, 1 1LOWER RAMS WITH 4"TEST JOINT. -- I 1_-TEST WTNESS WAIVED BY JOHN CRISP. Printed 8/30/2013 12:08:35PM • • • � o'=' ,ii./✓.! � �/ ¢' .� 7 r/ ,� ,�A 9�;s'.'��,.�",F ,,r-. 1" � �, �/ �' ram ; , - - /- 1 r „--,..,,,, ,,4...,,„/„,/, -.,7g, 0,./.---/, •,,,,,,; / ,/,/,,,,,,,,,I.146,,,,,-z-,..11,i,',;v-d,,,,p`71.V.?-:,' 4y',.,{,,;z.,.:•,,iyz,"Ar',,py,,z,.,.,,,,,. .,y; * , /,., Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 End Date:8/21/2013 f X3-013MH-C:DRILL(4,390,000.00) Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:0 Prudhoe Bay Site:PB DS 05 Project O:OOAM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date From-To ! Hrs Task Code NPT NPT Depth Phase Description of Operations _ hr usft 8/10/2013 00:00 04:30 4.50 1 BOPSUR P ( ) DECOMP CONTINUE BOP TEST. I TEST BOP TO 250 PSI LOW,3500 PSI HIGH I FOR 5 MIN EACH. ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS. TEST UPPER RAMS WITH 9 5/8"TEST JOINT, LOWER RAMS WITH 4"TEST JOINT. TEST WTNESS WAIVED BY AOGCC REP ! JOHN CRISP. 04:30 - 05:30 1.00 BOPSUR 1 P DECOMP RIG DOWN FROM TESTING BOP. -PJSM. -RIG DOWN TEST EQUIPMENT. -BLOW DOWN SURFACE EQUIPMENT. 05:30 W 06:00 0.50 HSUR P DECOMP PJSM,INSTALL WEAR RING. ID 12.375" -TEST GAS ALARMS 06:00 - 06:30 0.50 FISH P DECOMP !'!MAKE UP 4"XT 39 SAFETY JOINT. 06:30 - 09:00 1 2.50 FISH P - — DECOMP PJSM,MOBALIZE 9-5/8"DRESS OFF ASSY TOOLS TO RIG FLOOR. BEAVER SE RS PJSM,MAKE SLIDE OPE 9-5/8"DRESS ATION .OFF ASSY AS PER BAKER REPS INSTRUCTIONS. 09:00 - 09:30 0.50 FISH P DECOMP ;PJSM, O W "DRESS OFF ASSY RUN AND IN THE 13-3/8H"CASING LE ITH 9-5/8SCRA PER. I 1 -COLLARS RIH WITH 3 TO STANDS 306'. OF 4-3/4"DRILL ! 09:30 - 10:30 1.00 FISH P I DECOMP E WH 9 5/8" ASSY RUN IN AND THE 13-3/8HOL"CASING IT SCRAPER.DRESS OFF -RIH WITH 4"DRILL PIPE FROM DERRICK F/ 306'T/2,400' - DRIVE D PARAMETERSMAKE UP TOP,PUW=95KAN,SOW=OBTAIN 95K. *TAGGED UP AT 2,479'. PICK UP AND POSTION TOOL JOINT AT THE FLOOR. *PLACING FULL SLICK JOINT ACROSS STACK. CLOSE LOWER PIPE RAMS. 10:30 13:00 2.50 FISH P DECOMP PJSM,CIRCULATE OUT ARCTIC PAK BACK TO FLOW BACK TANK. I-PUMP 40 BBL DEEEP CLEAN PILL AT 4 BPM I WITH 400 PSI. CHASE DEEP CLEAN OUT OF HOLE WITH 120°9.8 PPG BRINE. -CIRCULATE AT 10 BPM WITH 1750 PSI. -TOTAL OF 400 BBLS PUMPED. I 10 MINITE FLOW CHECK,WELL STATIC. OPEN LOWER PIPE RAMS. * C WIT PUMPED OBSERVED AND AR CLEANED TIC PACK UP WITH H 215 250 BBLS BBLS PUMPED. I *WELL KILL DRILL HELD. 13:00 14.00 1.00 FISH P DECOMP !DRESS OFF 9 5/8"CASING STUB F/2,479'TI ! 2,480'. ' -UW 95K,DW 98K,RW 96K. 60 RPM,2-4K TQ. 14:00 - 14:30 1 0.50 FISH P DECOMP FLOW CHECK WELL. MONITOR WELL FOR 10 MINUTES. STATIC. ! -STAND BACK 1 STAND. -BLOW DOWN TOP DRIVE. Printed 8/30/2013 12:08:35PM • • 9 Psf7 a ,es � r ,,- '.,;.,,ripo,,,„,.„y %/,,,4,---,:„ ,,,,, ,i., / .-7,7 ,,,,;;:=e E3 s ® 0 r r+ ', AFE No Common Well Name:05-16 Event Type:WORKOVER(WO) Start Date:7/30/2013 1 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) I I Project:Prudhoe Bay i Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM 'Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°1558.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 16:00 1.50 FISH P DECOMP I TRIP OUT WITH 9 5/8"DRESS OFF ASSEMBLY. I I -FROM 'T 2396 TO 306'. I 1-MONITOR WELL FOR 10 MINUTES. STATIC. , *D-1 DRILL. 16:00 - 16:30 I 0.50 FISH P DECOMP STAND BACK 4-3/4"DRILL COLLARS. -PJSM FOR LAYING DOWN BHA. 16:30 18:30 2.00 FISH P I j DECOMP LAY DOWN DRESS OFF ASSEMBLY. -GOOD WEAR PATTERN ON MILL INDICATING CLEAN DRESS OFF ON 9-5/8"STUB. -BREAK OUT AND LAY DOWN SCRAPER ASSEMBLY AND DRESS OFF TOOLS. -CLEAN AND CLEAR RIG FLOOR. 1-PJSM WITH BLIND/SHEARS CLOSED AND CHOKE HCR OPEN TO A CLOSED CHOKE TO MONITOR UNDER BLIND/SHEARS DURING I ACCUMULATOR REPAIR. -CLOSE BLIND/SHEAR RAMS I *INFORMED BY DOYON SUPERINTENDENT I j THAT SOLENOID FOR HIGH PRESSURE BYPASS NEEDS CHANGING. 18:30 - 20:00 1.50 CASING P DECOMP RIG UP CASING TOOLS. -BRING CENTRALIZERS,CASING TOOLS,AND 'ASSOCIATED EQUIPMENT TO RIG FLOOR. I*CHANGE OUT HIGH PRESSURE BYPASS I ACTUATING RAM AND SERVICE ASSOCIATED _t! I SOLENOID ON ACCUMULATOR. 20:30 I 20:00 - 0.50 CASING 11 P I DECOMP SERVICE RIG. -PJSM. -SERVICE TOP DRIVE,BLOCKS,AND CROWN. ' *FIRE DRILL. , *CHANGE OUT HIGH PRESSURE BYPASS ACTUATING RAM AND SERVICE ASSOCIATED SOLENOID ON ACCUMULATOR. 20:30 - 22:00 1.50 CASING P DECOMP !I CUT AND SLIP DRILLING LINE. -PJSM. I-CUT AND SLIP LINE. -INSPECT DEADMAN ANCHOR. -INSPECT AND SERVICE DRAWWORKS. *CHANGE OUT HIGH PRESSURE BYPASS I ACTUATING RAM AND SERVICE ASSOCIATED 1 SOLENOID ON ACCUMULATOR. FUNCTION I I TEST GOOD. -NO PRESSURE ON WELL OPEN BLIND/ SHEAR RAMS. 22:00 - 22:30 0.50 BOPSUR P DECOMP PULL WEAR RING BUSHING. -PJSM. -LAY DOWN WEAR RING BUSHING. -LAY DOWN PULLING TOOL. 22:30 - 00:00 1.50 CASING P DECOMP CONTINUE RIGGING UP FOR 9 5/8"CASING RUN. -STAGE CEMENT HEAD ON RIG FLOOR. -MAKE UP FULL OPEN SAFETY VALVE. -RIG UP POWER TONGS. —_ 8/11/2013 00:00 - 00:30 0.50 1 CASING P DECOMP CONTINUE RIGGING UP CASING EQUIPMENT. . 1 I -PJSM. 1-RIG UP TORQUE TURN EQUIPMENT. -INSTALL SIDE DOOR ELEVATORS. 00:30 - 01:00 0.50 CASING P DECOMP PJSM. 1-ALL HANDS ATTEND CASING RUNNING PRE ' JOB. Printed 8/30/2013 12:08:35PM i i r, / . , i .,,i,�s': ,,,,///'>'''''',4;.:1,-.11,x'''':".;,. rr,F,y, r r' ,,�," i�,; ', ;a 4 1104 />:r13;"-:,, i„/, '',;/'''',/,':44::::1 ...,t1•1 #,/,/,'"e*0),:'/>. '''':''7;;<;(‘lli:;:': :';,..,,,,ejS:7,4''gf,f1%,:j4i.:Ztt/L';,..,1'.;;;;4'(:6y;"5, Common Well Name:05-16 1AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) , il - Project:Prudhoe Bay I Site:PB DS 05 I Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM I Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148'24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT 1 NPT Depth I Phase 1 Description of Operations (hr) I (usft) I 01:00 - 06:00 5.00 CASING P I DECOMP I RUN 9 5/8"47#HYDRIL 563 CASING. -FROM SURFACE TO 2478'. -STAB PIPE WITH STABBING GUIDE. -TORQUE ALL CONNECTIONS TO 15,800 FT-LBS -USE JET LUBE SEAL GUARD ON 'CONNECTIONS. 1 BAKERLOK FIRST TWO CONNECTIONS. I -RUN 59 FREE FLOATING CENTRALIZERS. _ 1 06:00 - 08:00 2.00 CEMT P DECOMP RIG UP CEMENT HEAD. 1 1 I-PJSM,INSTALL BALE EXTENSIONS. I-INSTALL PUP JOINTS TO SPACE CEMENT HEAD OUT. I-INSTALL CEMENT CROSS OVER,HEAD,AND LINES. -OBTAIN PARAMETERS. I -PUW 153K,SOW 155K. -RIH AND LOCATE TOP OF CASING STUB AT 2,481.68'.SWALLOW 2.75'OF PATCH TO 2,484.43' -SET PATCH BY STAGING UP WEIGHT TO 180K,THEN 200K,THEN 225K,THEN 250K. -SLACK OFF TO 200K AND PARK FOR TESTING AND CEMENT JOB. `SPILL DRILL,CRT 45 SECONDS 08:00 09:30 i 1.50 CASING P DECOMP 'i1 SET 9-5/8"ECP AND OPEN HES ES CEMENTER. I 1 -PRESSURE TEST INSIDE OF 9-5/8"CASING TO 1,000 PSI.FOR 5 CHARTED MINUTES. 1 -ROCK PRESSURES UP TO 2,000 PSI.WITH 50 TO 100 PSI.INCREMENTS HOLD FOR 5 MINUTES. 1 -DID NOT OBSERVE PRESSURE DROP I INDICATING INFLATION. l -BLED PRESSURE OFF AND STAGED UP TO 2,000 PSI.WITH 50 TO 100 PSI.INCREMENTS. -EVALUATE CHART CLOSELY AND OBSERVE THAT ECP DID INFLATE ON FIRST PRESSURE UP AT 1,400 PSI.FULLY INFLATED WITH 575 PSI.AN ELEMENT. -CONTINUE TO PRESSURE UP AND OBSERVE ES CEMENTER OPEN AT 2,850 PSI. I, I -PUMP BRINE THROUGH ES CEMENTER I WITH RIG PUMPS TO SIMULATE CEMENTING. I I I -PUMP AT 5 BPM WITH 180 PSI.AND RETURNS OUT EQUAL TO BARRELS PUMPED IN. I -TOTAL OF 10 BBLS.PUMPED. Printed 8/30/2013 12:08:35PM • '' ' 171V:•'' '-'-' --- /73A//," : /1/7/..;-,*e'"4/;`; ,2".„./r17;":„7:://:k-r--,&';':,,,,,,4„,,,7),,,,:i."472,t-,.../,:,,,,"...;:ztt," Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. I UWI:/Lat:070°15'58.646"6 Long: 10148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.0ousft(above Mean Sea Level) Date From-To Hrs Task Code ! NPT I NPT Depth Phase Description of Operations (hr) - I (usft) 1 09.30 - 11:30 2.00 CASING P I DECOMP 10EMENT 9-5/8"TIE BACK STRING. 1 -PJSM WITH ALL PARTIES INVOLVED AND 'ASSIGN ROLES AND RESPONSIBILITIES. -SLB PRIME CEMENT LINES WITH 5 BBLS.OF 1 FRESH WATER. -CLOSE CEMENT HEAD AND PRESSURE TEST I LINES TO 250/4,000 PSI.FOR 5 CHARTED 'MINUTES EACH. `-BLEED PRESSURE OFF AND PUMP 171 BBLS. OF 15.8 PPG CLASS"G"CEMENT WITH 1 1 GASBLOK AT 5 BPM WITH AN AVERAGE OF 100 PSI. -SLURRY COMPOSITION:DENSITY 15.8, YIELD 1.18 FT3/SK,MIX FLUID 5.316 GAL/SK. -TOTAL OF 814 94LB.SACKS. 1-SHUT DOWN AND LAUNCH CLOSING PLUG FOR ES CEMENTER FROM CEMENT HEAD. -SLB PUMP 5 BARRELS OF WATER TO FLUSH I LINES AT 5 BPM WITH 100 PSI.AND SHUT DOWN. 1-SWAP VALVES TO RIG PUMPS AND DISPLACE 9.8 PPG BRINE AT 5 BPM AT 100 ,PSI.,CAUGHT PLUG WITH 69 BBLS. 1 I I 1 DISPLACED.AFTER 100 BBLS.DISPLACED DIVERTED TO FLOWBACK TANK THROUGH OUTER ANNULUS VALVES AND CLOSED 1ANNULAR PREVENTER.OBSERVED CEMENT AT FLOWBACK TANK WHEN 140 BBLS. DISPLACED SLOWED PUMP RATE AT 164 BBLS DISPLACED TO 2.5 BPM WITH 1,100 PSI. LANDED CLOSING PLUG AT 178 BBLS. DISPLACED AND CLOSED ES CEMENTER 1 WITH 1,730 PSI.PUMP PRESSURE. ! ! *CEMENT IN PLACE AT 11:15 ON 08/11/2013. 1 1 *TOTAL OF 28 BBLS.OF CEMENT RETURNS I 1 , 1AT SURFACE. -BLEED PRESSURE OFF,REMOVE CEMENT 1 I LINE FROM CEMENT HEAD AND OPEN VALVES ON CEMENT HEAD AND CONFIRM CEMENTER SHUT WITH NO PRESSURE. -MONITOR WELL FOR 10 MINUTES. 11:30 - 14:00 1 2.50 1 CASING P DECOMP RIG DOWN CEMENT EQUIPMENT. -PJSM. 1 -RIG DOWN CEMENT HEAD AND XOS. 1-LAY DOWN CASING TOOLS AND EQUIPMENT. -VOID FLUID FROM INSIDE 9 5/8"CASING TO 1 FACILITATE CUTTING. 114:00 - 16:30 2.50 BOPSUR P DECOMP NIPPLE DOWN BOP STACK. -PJSM. I -PULL BACK FLOW LINE. 1 11 !-RIG UP BRIDGE CRANES. 1 -REMOVE TURNBUCKLES. 16:30 - 19:00 2.50 WHSUR P DECOMP 1 INSTALL EMERGENCY SLIPS. j -PJSM. -SPLIT BOP STACK ABOVE CASING SPOOL. -CLEAN CASING SPOOL. 1-CENTER CASING IN WELLHEAD. 1-INSTALL EMERGENCY SLIPS WITH 100K OVERPULL APPLIED. 1-SET SLIPS. Printed 8/30/2013 12:08:35PM • Wi r.� ! ,, tr /1/i7'74%;,,,,4.,,,,//2:,/,,,(7,,,,,,:s'::,,,,:, /44.,..e:i.e,„,:>/:,,,,-- -/.:>pZe.„`„/;,„,, ,,,,,/,,,,,,,/,/,.4.-,,,,..4;,,2),,H,„„),. ..>"?;'',. ::/.,:d"-;,/,4',:iii:,„4:,„;,,..,,/p, :i'42,2:461,fico:--JAI. ,- .., „.. Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 I End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 I Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 1 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date 11 From-To I Hrs Task Code 1 NPT NPT Depth 1 Phase Description of Operations (hr) (usft) CUT CASING. 20:00 + 1.00 WHSUR P 19:00 DECOMP I-PJSM. I I -RIG UP WACHS CUTTER,CUT CASING. -DRESS OFF CASING STUB. 20:00 - 23:00 I 3.00 WHSUR P DECOMP INSTALL 9 5/8"PACK-OFF. -PJSM. SAOO I '-INSTALL INTLL NEW PACK FMC FF OT UN TUBING STUB.SPOOL. -RUN IN LOCK DOWN SCREWS. 23:00 W 00:00 1.00 WHSUR 1 P DECOMP !PRESSURE TEST INNER CASING PACK-OFF -PJSM. I-INSTALL TEST EQUIPMENT. -TEST TO 250 PSI LOW FOR 5 MIN,3500 PSI !HIGH FOR 30 MIN. GOOD. I , 8/12/2013 00:00 - 00:30 1 0.50 WHSUR P DECOMP CONTINUE PRESSURE TESTING INNER CASING PACK-OFF. 1 -RIG DOWN TEST EQUIPMENT. -CLEAR AND GLEAN AREA AROUND WELL HEAD FROM PACK-OFF INSTALLATION. 00:30 - 01:30 1.00 WHSUR P DECOMP INSTALL VALVES ON TUBING SPOOL. -PJSM. 1-INSTALL VR PLUG. , INSTALL WORKING VALVES FOR IA. -TEST VALVES AND PLUGS TO 250 LOW/3500 PSI HIGH FOR 5 MINUTES. 01:30 05:30 4.00 BOPSUR P DECOMP NIPPLE UP STACK. I-PJSM. I-INSTALL STACK ONTO TUBING SPOOL. 1-MAKE UP TURNBUCKLES AND FLOW LINE. 1 05:30 - 08:00 2.50 BOPSUR P , DECOMP CHANGE OUT UPPER RAMS -PJSM. -CLOSE BLIND RAMS. 1-OPEN UPPER RAM CAVITY. I 1-REMOVE 9 5/8"PIPE RAMS. I j-INSTALL 2 7/8"X5"VBR RAMS. 08:00 - 09:00 1.00 BOPSUR P DECOMP I RIG UP TO TEST RAMS. -PJSM. -BRING NEW TEST PLUG TO RIG FLOOR. , !-INSTALL NEW TEST PLUG. ■ 09:00 - 10:30 1.50 I BOPSUR P DECOMP TTEST BOP RAMS. I-PJSM. , I-TEST UPPER RAMS WITH 4"AND 4 1/2"TEST JOINT. -TEST LOWER RAMS WITH 4 1/2"TEST JOINT. 1-TEST TO 250 PSI LOW/3500 PSI HIGH FOR 5 1 I _ 1 MINUTES EACH. 10:30 11:00 0.50 BOPSUR P , DECOMP RIG DOWN TEST EQUIPMENT. -PJSM. !-RIG DOWN TEST EQUIPMENT. -BLOW DOWN CHOKE MANIFOLD. t11:00 - 11:30 0.50 BOPSUR P DECOMP I PJSM,INSTALL WEAR RING BUSHING 1-8 7/8"ID. 0.50 CLEAN ± P LAY DOWN RUNNING TOOL 11:30 - 12:00 � DECOMP PJSM,BRING CLEAN OUT BHA TO RIG FLOOR. 112:00 - 12:30 0.50 CLEAN P DECOMP RIG SERVICE. PJSM. -SERVICE ST-80 AND DRAWWORKS. Printed 8/30/2013 12:08:35PM !" � ce // /si je � � a � . f ®� ��� '-'''-4:1/,' ,./17/7,/ ,,,/,47'Y*X.,/-'4"—/- -;,>'''''''/-1;,/ 7#/////),) 'art: ,--trif:r1?" ''"''''=&y.—/) `,////-/. //-/"5" :"A‘ /' .4e-, f%',' /7":3W14,K, Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 1X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 j Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM 1 Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase I Description of Operations (hr) (usft) 1 12:30 - 13:30 1.00 CLEAN I P DECOMP MAKE UP 8 1/2"CLEANOUTASSEMBLY. 1 -PJSM. -MAKE UP 8 1/2"BHA. -RUN 3 STANDS OF DC -FROM SURFACE TO 304'. 1 13:30 14:30 1.00 CLEAN P 1 DECOMP TRIP IN THE HOLE. 1 , -1-PJSM. ! -FROM 304'TO 2393'. 14:30 - 16:30 2.00 CLEAN P DECOMP `DRILL OUT CEMENT AND PLUG. , -WASH DOWN FROM 2393',TAG CEMENTER I AT 2436'. , I 1-OBTAIN PARAMETERS FOR DRILLING. -UW 93K,DW 95K,RW 95K. -100 RPM,1KTQ -14 BPM,1850 PSI. I -CONTROL DRILL FROM 2436'TO 2437'. 16:30 - 17:30 1.00 1 CLEAN N RREP 2,437.00 DECOMP RIG POWER OUTAGE. 1-SECURE WELL.CLOSE ANNULAR. MONITOR PRESSURES. , -TROUBLESHOOT GENERATOR AND BRING -- ---— - - — _ GENERATOR BACK ON LINE. 17:30 - 18:00 0.50 CLEAN P I DECOMP [BACK TO WORK SAFETY MEETING. , -VERIFY WELL PRESSURE IS ZERO. -OPEN ANNULAR AND MONITOR WELL 10 I 1 MINUTES. STATIC. I -DISCUSS WELL CONTROL DURING POWER �� I OUTAGE ON RIG. REVIEW ROLES AND kRESPONSIBILITES. 18:00 - 20:00 2.00 CLEAN P 1 DECOMP I CONTINUE DRILLING OUT ES CEMENTER. -FROM 2437'TO 2440'. ,-UW 93K,DW 96K,RW 96K,WOB 2K. -14 BPM,1850 PSI. -100 RPM,1K TQ. 1-PUMP 20 BBL HI-VIS SWEEP. 20:00 - 21:30 1.50 CLEAN P DECOMP RUN IN TO TOP OF SAND. -FROM 2440'TO 2488'WASH DOWN. , I -SHUT DOWN ROTARY AND PUMPS. -RUN IN TO TOP OF SAND AT 2524'. SET 1 1 DOWN 5K. I I 1-DRY DRILL 70 RPM,1K TQ,4K WOB,FOR 15 1 1MINUTES. 21:30 - 22:00 ,' 0.50 CLEAN P DECOMP !CIRCULATE 1-CIRCULATE 20 BBL HI-VIS SWEEP. } -14 BPM,1850 PSI. ,_'22:00 - 23:00 1.00 CLEAN P 1 DECOMP INSPECT DERRICK AND TOP DRIVE. -STAND BACK ONE STAND FROM 2524'TO I 2488'. 1-PJSM. -INSPECT TOP DRIVE AND DERRICK, UNUSUAL VIBRATION AND NOISE. -NO DISCREPANCY FOUND,FUNCTION CHECK ROTARY AND TOP DRIVE GOOD. -10 MINUTE FLOW CHECK.STATIC. 1-MONITOR WELL ON TRIP TANK. 23:00 - 00:00 1.00 CLEAN P DECOMP :TRIP OUT OF THE HOLE. I -PJSM. 1 -FROM 2488'TO 304'. -L Printed 8/30/2013 12:08:35PM .., 0 i .. �/, � ,, ;�/' ' a .45,0' ° :1,J r.7rx� .5r / r .. r '''''''''<i'd 74,/jr.4.774,'01'/,74,,,, 74/ c'-f /".:7,. ,,,e.,4„,e9V,,,,,,,,,,)' ,.,/,,,v,,I,30.247/,,,,--,„40,-.44,,,,,A.-4e,***".*.id,50v• ---,'"47",, -/-61/ /-,,,,,, tfry://7,/,'* c /7,, .."7"4":"/,,,,,,////// ,,,,,,,:e.,,,,,,r,-;:„640,,,,/;v0e-, ,.‘,3,4„;5",,a„.fi,„,,,,,,,%,,,. Common Well Name:05-16 I AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 1 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 8/13/2013 100:00 - 02:30 2.50 CLEAN P DECOMP LAY DOWN CLEAN OUT BHA. -h I -PJSM. 1-FROM 304'TO SURFACE. I , I-STAND BACK COLLARS. I-LAY DOWN CLEAN OUT ASSEMBLY. , -SOME DEBRIS RECOVERED IN JUNK BASKETS. APPROXIMATELY 2 CUPS. I-MONITOR WELL. STATIC. 02:30 - 03:00 0.50 CLEAN P I DECOMP PICK UP 8 1/2"REVERSE CIRCULATING JUNK BASKET ASSEMBLY. I -PJSM. -FROM SURFACE TO 314'. 03:00 04:00 1.00 CLEAN P DECOMP TRIP IN THE HOLE. -FROM 314'TO 2499' L-SCREW INTO TOP DRIVE 04:00 - 05:30 1.50 CLEAN P DECOMP REMOVE SAND FROM TOP OF PLUG OBTAIN PARAMETERS. -PUW=95K,SOW=95K ROT WT=97K,FREE I TORQUE AT 40 RPM 1K AT 5 BPM WITH 1200 PSI. I-OBTAIN SLOW PUMP RATES. -RIH AND TAG TOP OF SAND AT 2,528. `-DROP 1"BALL. I -PUMP PRESSURE DECREASED FROM 1200 I I PSI TO 580 PSI. I-INCREASE PUMP RATE TO 10 BPM WITH 1800 PSI. , -WASH DOWN FROM 2,528'TO 2,538'-NO TORQUE NOTICED. 05:30 P 07:00 1.50 CLEAN DECOMP CIRCULATE BOTTOMS UP TO CLEAN OUT SAND FROM HOLE -AT 500 BBLS AWAY PUMP PRESSURE WENT I FROM 1770 PSI TO 3400 PSI AT 10 BPM. -CLEAN OUT 5'MORE OF SAND TO 2,543'. I-WASH DOWN WITH NO TORQUE. -PULL UP WITH OVERPULL OF 35K. -SLACK OFF AND TOOK WEIGHT. PULL UP WITH OVER PULL TO 35K ONE MORE TIME. -SLACK OFF TO 75K. ,-TURN PUMPS OFF AND PULLED UP 140K TO FREE AND PULL UP PAST 2,528'. -TURN PUMPS ON AND CONTINUE TO CBU UNTIL SHAKERS CLEAN. 07:00 - 08:30 1.50 CLEAN P DECOMP PJSM,PULL OUT OF THE HOLE WITH RCJB AND 9-5/8"SCRAPER BHA. -MONITOR WELL FOR 10 MINUTES-WELL STATIC. -RACK BACK 1 STAND OF 4"DRILL PIPE. -BLOW DOWN TOP DRIVE. -POOH FROM 2,499'TO 409'. -MONITOR WELL FOR 10 MINUTES BEFORE PULLING NON-SHEARABLES ACROSS 'STACK-WELL STATIC. -POOH FROM 409'T TO 31'. Printed 8/30/2013 12:08:35PM • • , s ! ' r.,, / ', .;.4/1 . f ,' '{ ,4 ;'t� � „2; s.' `r oay' � , /,'''''',-7,;--/7t/y:///7-7.;,7/7,-"x; 0,-,),.'-g9i-4,':;;A:',-;,,y,zi,i1:...e„---,-..w .;,./...„(,,z_.,/ ,,,,,,,, „, ._ , Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3 013MH-C:DRILL(4,390,000.00) 1 Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 I Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 10148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 08:30 - 09:30 1.00 CLEAN P I DECOMP PJSM,BREAK DOWN BHAAND CLEAN OUT I JUNK BASKET. *RECOVERED 1 GALLON OF ALUMINUM AND A I FEW CHUNKS OF RUBBER *BOOT BASKETS WERE CLEAN. -MAKE UP RCJB AND TORQUE. -FIRE DRILL WITH 1:15 RESPONSE TIME BY CREW MEMBERS 09:30 - 11:30 2.00 CLEAN 1 P I DECOMP PJSM,RUN IN THE HOLE WITH RCJB AND I 19-5/8"SCRAPER BHA. I I i-MAKE UP 3 STANDS OF 4-3/4"DRILL COLLARS. -RIH FROM 314'TO 2,499'AND SET DEPTH 11:30 - 12:30 1.00 CLEAN 1 P DECOMP 'REMOVE SAND FROM TOP OF PLUG. -OBTAIN PARAMETERS. -PUW=95K,SOW=96K,ROT WT=96K WITH 40 I RPM AND 1K FREE TORQUE AT 5 BPM WITH 1200 PSI. -TAGGED TOP OF SAND AT 2,543. -WASH DOWN TO 2,548'WITH 1K WOB. CIRCULATE HOLE CLEAN AT 8.8 BPM WITH I I 12900 PSI. fTOTAL PUMPED 351 BBLS 4-FLOW CHECK WELL FOR 10 MINUTES *0 BBL LOSSES FROM MIDNIGHT TO NOON. 12:30 - 14:00 1.50 CLEAN P DECOMP PJSM -POOH FROM 2,49'9 TO 315' -FLOW CHECK WELL FOR 10 MINUTES 1-RACK BACK 3 STANDS 4.75"DRILL COLLARS I-PULL RCJB AND 9 5/8"SCRAPER TO FLOOR BOOT BA AND CHECK BOO BASKETS AND RCJB FOR S DEBRIS,RCJB FREE OF DEBRIS 14:00 - 15:30 1.50 CLEAN P I DECOMP I PJSM ON RUNNING RCJB + I I -RIH WITH RCJB FROM 315'TO 2,499' 15:30 16:30 1.00 CLEAN P DECOMP OBTAIN PARAMETERS -PUW=95K,SOW=95K,ROT=98K -CIRCULATE 8.5 BPM WITH 2,590 PSI,RPM 1K TORQUE I-WASH DOWN FROM 2,499'TO 2,558' I-POOH FROM 2,558'TO 2,548'AND 1 jCIRCULATE BOTTOMS UP 16:30 - 18:00 1.50 CLEAN P DECOMP I FLOW CHECK WELL FOR 10 MINUTES -POOH FROM 2,548'TO 2,499 il-RACK BACK ONE STAND AND BLOW DOWN TOP DRIVE I !-CONTINUE PULLING OUT OF HOLE FROM 2,488'TO 315' 18:00 - 19:30 1.50 CLEAN P DECOMP FLOW CHECK WELL FOR 10 MINUTES I I-RACK BACK THREE STANDS OF 4.75"DRILL II COLLARS I-LAY DOWN BHA,BUMPER SUB,BOOT I BASKETS,BIT SUB AND CASING SCRAPER 19:30 - 20:00 0.50 CLEAN P ! DECOMP PJSM ON BEAVER SLIDE OPS -LAY DOWN BAKER TOOLS AND EQUIPMENT Printed 8/30/2013 12:08:35PM • . ,i'i/., is„ / ' /• , i ir i /,y„ 0 /.. '. , 7, . :fir 4.. aa as Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 I End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations III (hr) (usft) I I 20:00 - 22:30 2.50 CLEAN 2.50 DECOMP TEST 9 5/8"CASING WITH BLIND RAMS I -PJSM -CLOSE BLIND RAMS AND LINE UP TO PRESSURE TEST CASING -PRESSURE UP TO 3650 PSI FOR 30 MINUTES,15 MIN BLEED DOWN=3580,30 MIN I iBLEED DOWN=3510,45 MIN BLEED DOWN I I 13490 12.1 BBLS TO PRESSURE UP,BLED BACK 2 I :BBLS I I 1 I-TEST BLED PAST 3500 PSI ON CHART -ZERO STROKE COUNTER AND RE-TEST CASING I -2.1 BBLS TO PRESSURE UP TO 3750 PSI,15 MIN BLEED DOWN 3675,30 MIN BLEED DOWN 1 3605,45 MIN BLEED DOWN 3570, BLED BACK , 12.1 BBLS.MIT PASSED AS PER WELLBORE I I I INTEGRITY TESTING CRITERIA CALCULATOR. (SEE ATTACHED FILES) -VERIFY TEST RESULTS WITH WTL(RICH j BURNETT),OK TO PROCEED 22:30 - 00:00 1.50 CLEAN P DECOMP 'PJSM -RIH WITH RBP RETREIVAL TOOL ON 4"DRILL —- — _ PIPE TO 1,917' 8/14/2013 '00:00 01:00 1.00 CLEAN P DECOMP RUN IN HOLE WITH 4"DRILL PIPE AND 9 5/8" I RBP RETRIEVING TOOL -RUN IN HOLE FROM 1917'TO 2484' 01:00 - 03:00 2.00 CLEAN P DECOMP I UNSEAT 9 5/8"RETRIEVABLE BRIDGE PLUG -ESTABLISH PARAMETERS AT 2484':PUW 87K, SOW 90K -ESTABLISH SLOW PUMP RATES AT 2484 W I i ITH 9.8 PPG BRINE FLUID:PUMP#1 20 I I SPM=40 PSI,30 SPM=50 PSI/PUMP#2 20 I I SPM=60 PSI,30 SPM=70 PSI. I I-ESTABLISH PUMP RATE OF 14 BBLS/MIN AT 1 780 PSI. ! -WASH DOWN FROM 2484'TO 2575'. REDUCED PUMP RATE TO 10 BBLS/MIN AT ! 1540 PSI TO ATTEMPT TO ENGATE RBP. 1 1-ATTEMPT TO ENGAGE RBP SEVERAL TIMES I WHILE WORKING LEFT HAND TORQUE DOWN.SET 25K DOWN TO ENGAGE RBP. j -PICK UP TO 10K OVER PULL. -CONTINUE CIRCULATING AND PUMP 40 BBL I HI-VIS SWEEP AROUND. -WHILE CIRCULATING BEFORE SENDING SWEEP,OBSERVED SAND AT SHAKERS. SHAKERS CLEANED UP BEFORE SWEEP WAS PUMPED. -PUMPED SWEEP WITH NO SAND OR I CUTTINGS OBSERVED COMING AROUND. I 1-SHUT DOWN PUMPS.PULLED 10K OVER, I MARKED PIPE,SLACKED OFF 10K UNDER, I TURNED PIPE 1/4 TURN TO RIGHT. I -PULLED 10K OVER AND SAW THE BYPASS I I OPEN.PULLED 5K INCREMENTS UNTIL PLUG I PULLED FREE AT 40K OVER.SLACK OFF TO I CONFIRM RBP RELEASED,POSITION DRILL ' t STRING FOR CIRCULATING BOTTOMS UP. Printed 8/30/2013 12:08:35PM �! • %/ 7, / /! // i� ,of. / i.:-/ / /.` ,'.j` ',.�,,% F „%f„f,.'i fF!',`F`'" �':F�s r�;, ��,, �,,/ " ,//,,42,� x //,�/?r• //,///,;4 --e4/74.0,.;/7„ ,/,,,..,,,,,7 *7,o/2, 0,, , .1,A,-;1.,,,,tilf p //,,/„,,,,,,z,k/ - 7, //ft/7 At;,,"" 47 , ,/,„7 ;,; ,,,,,,,,,,e . Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8121/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 04:00 1.00 CLEAN P DECOMP ,WELL KILL DRILL/CIRCULATE BOTTOMS UP THRU CHOKE -PJSM,WELL KILL DRILL-CLOSE BAG AND WELL SECURED IN 1 MINUTE 20 SECONDS. ALL HANDS RESPONDED APPROPRIATELY TO DRILL. LINE UP PITS,CHOKE MANIFOLD TO CIRCULATE BOTTOMS UP THRU GAS BUSTER ESTABLISHED FLOW RATE OF 5 BBLS/MIN THRU GAS BUSTER(6 BBLS TO FILL GAS BUSTER)AT 200 PSI. CIRCULATE BOTTOMS UP THRU GAS BUSTER(205 BBLS) FLOWCHECK WELL BEFORE OPENING UP ANNULAR-WELL STATIC(10 MINUTES) 04:00 - 06:00 2.00 CLEAN P DECOMP PULL OUT OF HOLE WITH 4"DRILL PIPE AND 9 5/8"RBP -PULL OUT OF HOLE FROM 2575'TO SURFACE' _ *PUW 85K,SOW 90K @ 2575' *NO TIGHT SPOTS OBSERVED RACK BACK 4 3/4"DRILL COLLARS LAY DOWN 9 5/8"RETRIEVABLE BRIDGE `PLUG AND RUNNING TOOL. 06:00 07:30 1.50 CLEAN P DECOMP PJSM,CLEAN AND CLEAR RIG FLOOR OF ALL TOOLS AND EQUIP NOT NEEDED -BEAVER SLIDE OPERATIONS. MOBILIZE BAKER BHA TO RIG FLOOR. 07:30 08'30 1.00 CLEAN P DECOMP PJSM,MAKE UP 7"DRILL OUTASSY. MAKE UP 6.125"BIT,BIT SUB,6.125"STRING MILL,4 EA.BOOT BASKETS,BUMPER SUB, OIL JAR,PUMP OUT SUB,AND 9 EA.4.75" DRILL COLLARS. *DISCUSS FLUID MANAGMENT FOR TRIPPING IN THE HOLE. 08:30 - 12:00 3.50 CLEAN P DECOMP ,PJSM,RUN IN THE HOLE WITH 7"DRILL OUT ASSY. RIH WITH 3 STANDS OF 4-3/4"DRILL I COLLARS TO 325'. RUN IN THE HOLE ON 4"DRILL PIPE FROM II 325'TO 7,925'. *0 BBL FLUID LOSS FROM MIDINIGHT TO NOON. *OA PRESSURE AT NOON=OPSI {12:00 13:00 1.00 CLEAN P DECOMP RUN IN THE HOLE WITH 7"DRILLOUT ASSEMBLY(6 1/8"BIT AND BHA) -RIH FROM 7925'TO 8587' -TAGGED CEMENT AT 8587 Printed 8/30/2013 12:08:35PM 0 • ,n . ii i i ii %ii/ a' :..i,„7.� l .i ii � F i „,...7y,/ ,,,, ,......e ,/,,,,, , -' /' .. /,,, 4,//,,,',./ p,,e-,, r!;�' mss„ AFE No Common Well Name:05-16 Event Type:WORKOVER(WO) Start Date:7/30/2013 i End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646'6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) - — 1 (usft) 13:00 - 22:30 9.50 CLEAN P DECOMP i DRILL OUT FLOAT EQUIPMENT AND CEMENT NB PAMETERS. *PICK PUW=UP 177KA ,D SOW=ESTA1217K,LISHED ROT=AR147K @ 120 RPM AND 11 BBLS/MIN @ 2980 PSI,6K ROTATING TORQUE -DRILL CEMENT FROM 8587 TO 8608'. RUBBER AND ALUMINUM COMING ACROSS SHAKERS INDICATING PLUG WERE MILLED UP AT 8608' O HT1 0 I INCREASED-ENC WOB UNTERED FROM ARD 2K SPOTA TO 18K 86 IN 8'.2K I INCREMENTS AND S TO 80 RPMS AT EACH VARYING INCREMENRPMT.DRILLED FROM75 F 18K ON OFPUMPED AT HI-VIS WOB.SWEEP(10 BBLS)WITH FINE CEMENT AND METAL COMING BACK BEFORE SWEEP AND NOTHING COMING OUT AFTER I SWEEP. I -CONTINUE TO DRILL CEMENT FROM 8631' I J TO 8689' -WW 88 ' ' ABOVE ASH PROPOSED DON FROM TO6P 9 OF TO SAND8738)(20' -CIRCULATING AT 11 BBLS/MIN WITH 120 RPMS ON ROTATION WITH 5K TORQUE, OBSERVED SAND COMING BACK IN RETURNS. - W , O AT 10 SHUT RPMS DO NT O OBSERVE PUMPSCONTINUE U T TORQUE TOR OKTEAETRE FROM PACKING OFF. PULL OUT OF HOLE TO TOP OF STAND AT 8684'TO ALLOW SAND TO SETTLE 22:30 - 00:00 1.50 CLEAN P DECOMP DRY DRILL ON TOP OF SAND I I ALLOW SAND TO SETTLE FOR 45 MINUTES I WHILE ROTATING AT 10 RPMS TO MONITOR ! ! j TORQUE. I-RUN IN8 HOLE AND TAG SAND WITH 15K WOB , I AT 8738' I-DRY DRILL AT 8738'WITH 5K WOB FOR 15 i MINUTES AT 80 RPMS *0 BBL FLUID LOSS FROM NOON TO MIDNIGHT I *OA PRESSURE AT 23:00=0 PSI - 8/15/2013 00:00 - 02:00 2.00 ! CLEAN P DECOMP !!CIRCULATE SWEEP AROUND -PICK UP 15'OFF OF TO OF SAND TO 8733' -ESTABLISHED CIRCULATION AT 9.5 BBLS/MIN AT 2260 PSI PUMP 20BBLSWEEPAROUND •SMALLAMOUNT OF SAND OBSERVED IN I RETURNS RIGHT BEFORE SWEEP HIT SHAKERS.RETURNS CLEANED UP AFTER !SWEEP. Printed 8/30/2013 12:08:35PM • • ';:",:,,,,44"-7,/,'*/.1/.,./Y',„;:1-/-1,,`.7, ',p"-5.-/-7:%/7/4- � � � m--t y .6� , 3 % ice' 1 if i.."-,(//,,," 4,77, 1/P/Pe- ' 7'u ,�- ,i .� fir 1A, a at(,, �- Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 4X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date l From-To Hrs Task ' Code NPT NPT Depth 1 Phase Description of Operations 1 (hr) '. (usft) ------ __----- 102:00 - 06:30 4.50 CLEAN P DECOMP PULL OUT OF HOLE ON ELEVATORS WITH 4" I DRILL PIPE AND 6 1/8"DRILL OUT ASSEMBLY -FLOW CHECK WELL FOR 10 MINUTES-WELL STATIC -PULL OUT OF HOLE ON ELEVATORS FROM 8733'TO 500' -NO TIGHT HOLE OBSERVED -PUW @ 8733=192K I-PULL OUT OF HOLE RACKING BACK STANDS IN DERRICK. 1-FLOW CHECK WELL BEFORE PULLING NON 1 SHEARABLES ACROSS THE STACK.WELL 1 STATIC. 1-RACK BACK 1 STAND OF 4"DRILL PIPE TO 325' 1-RACK BACK 3 STANDS OF 4-3/4"DRILL COLLARS. 06:30 - 07:30 1.00 CLEAN P ' DECOMP PJSM,BREAKAND LAY DOWN 7"DRILL OUT 1 1 1 I BHA. I-BREAK APART OIL JARS AND LAY DOWN IN I PIPESHED. -BREAK APART AND LAY REST ON RIG FLOOR I- I TO CLEAN. 07:30 - 08:30 1.00 CLEAN P DECOMP "PJSM,LAY DOWN DRILL OUT BHA. , -BEAVER SLIDE OPERATIONS. -CLEAN AND CLEAR RIG FLOOR OF ALL TOOLS AND EQUIPMENT NOT NEEDED FOR NEXT RCJB ASSY RUN. -MOBALIZE RCJB BHA TO RIG FLOOR. 08:30 - 09:30 1.00 CLEAN P DECOMP 1 PJSM WITH BAKER REP ON MAKING UP RCJB ASSY. -MAKE UP REVERSE CIRCULATING JUNK I BASKET ASSEMBLY -CLEAN MAGNETS 109:30 - 11:30 2.00 CLEAN P DECOMP PJSM,RUN IN THE HOLE WITH 6 1/8" REVERSE CIRCULATING JUNK BASKET ASSY. -RIH ON ELEVATORS 3 STANDS OF 4-3/4" DRILL COLLARS TO 333' ,-RIH ON ELEVATORS 4"DRILL PIPE TO 2,517' I 1 1*NO TIGHT SPOTS OBSERVED 11:30 12:00 0.50 CLEAN 1 P 1 DECOMP *KICK WHILE TRIPPING DRILL RESPONSE I TIME 1 MINUTE AND 45 SECONDS. 1 I *AFTER ACTION REVIEW WITH BP;WTL, RWO/CTD OPS.,WSL AND DDI CREW. *0 BBL FLUID LOSS FROM MIDNIGHT TO NOON. 12:00 - 12:30 0.50 CLEAN P 1 1 DECOMP PJSM,GREASE AND INSPECT TOP DRIVE, BLOCKS AND DRAW WORKS. 12:30 15:30 3.00 1 CLEAN 1 P DECOMP PJSM,RUN IN THE HOLE FROM 2,517'TO 1 1 8,693' 1-RUN IN HOLE ON ELEVATORS 6 1/8"RCJB I ASSEMBLY 1 *NO TIGHT SPOTS OBSERVED Printed 8/30/2013 12:08:35PM • 0 �� � ,4/,' , ���/,' r t,,. rl, +r j .!.�-'��Ji�A,''"�'- .'%,rt',r„'rgt�r�i �[�/�� o�� /.!", it�d _� rg ,,,47-,..'/1/4.,4,-2-7.,/,/,#„,./,-,.-7////, ./,„/// //////,,,// 2/.4-,/;,,-,:e40/5014;,(-7/2.., ,/;;;;7.,/., ,52,,./7-•;,,.;x:----)4.6,--.,.?4,-A.,7xf-*:40{;;.404 -',. - //7,7* 2,,,,,//7 , ,7//, '' / ,,,,, r//?/2.,,,'',—//ow4',z* ;,.e..,:',,4/4/, 7,;,',//,./.<7"fika*,477,0,//'.<,./ :',/,,,,,m,,,,,,,-,Y" ' Common Well Name:05-16 AE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 1X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay I Site:PB DS 05 Rig Name/No.:DOYON 14 1 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 10148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth 1 Phase Description of Operations (hr) , (usft) i 15:30 - 17:30 2.00 CLEAN P DECOMP CLEAN UP ON TOP OF SAND WITH REVERSE 11 CIRCULATING JUNK BASKET -OBTAIN PARAMETERS:PUW=190K, SOW=131 K,ROT=155K -DROP BALL FOR RCJB,ESTABLISH 1 CIRCULATION AT 8 BBL/MIN AT 1840 PSI. -BALL SEATED IN RCJB AT 59 BBLS PUMPED AWAY-PRESSURE INCREASED TO 2220 PSI. -PARAMETERS:40 RPM=5K FREE TORQUE '-WASH DOWN FROM 8693'TO 8748'(10'BITE OF SAND) 1-POOH FROM 8748'TO 8723'.INCREASED PUMP RATE TO 10 BBL/MIN WITH 3300 PSI 1-TURNED ROTARY OFF,CIRCULATED BOTTOMS UP @ 335 BBLS. -4.---___ -POOH FROM 8723'TO 8693' 17:30 - 18:00 0.50 CLEAN P DECOMP FLOWCHECK WELL -SHUT DOWN PUMPS. -FLOWCHECK WELL FOR 10 MINUTES-WELL I 1STATIC 1 -POOH AND RACK BACK 1 STAND -BLOW DOWN TOP DRIVE AND KELLY HOSE —118:00 - 22:00 , 4.00 CLEAN P 1 1 DECOMP rPULL OUT OF HOLE ON ELEVATORS -PULL OUT OF HOLE WITH 4"DRILL PIPE AND 6 1/8"RCJB -POOH FROM 8693'TO 428' -NO TIGHT SPOTS ENCOUNTERED DURING TRIP 22:00 - 00:00 2.00 CLEAN P 1 DECOMP ,CLEAN OUT RCJB ASSEMBLY I -FLOWCHECK FOR 10 MINUTES BEFORE BRINGING NON-SHEARABLES ACROSS I STACK -RACK BACK 3 STANDS OF DRILL COLLARS 1-POOH WITH RCJB BHA.CLEAN STRING I 1,MAGNETS(VERY LITTLE METAL ON MAGNETS) ' -CLEAN OUT DEBRIS FROM RCJB(ABOUT HALF CUP OF ALUMINUM AND CEMENT) -CLEAN OUT BOOT BASKET(ABOUT 2 CUPS SAND IN LOWER BOOT BASKET). 0 FLUID LOSS FROM NOON TO MIDNIGHT/0 FLUID LOSS TOTAL FOR PAST 24 HOURS 8/16/2013 00:00 - 00:30 0.50 CLEAN P DECOMP 1 RUN IN HOLE WITH DRILL COLLARS AND 6 ' 1/8"RCJB BHA -PJSM 1-MAKE UP AND RUN IN HOLE WITH REVERSE CIRCULATING JUNK BASKET BHA -RUN IN HOLE ON ELEVATORS WITH 3 STANDS OF 4 3/4"DRILL COLLARS FROM DERRICK 00:30 04:30 4.00 CLEAN P DECOMP 'RUN IN HOLE WITH 4"DRILL PIPE AND 6 1/8" I I 1 REVERSE CIRCULATING JUNK BASKET ASSEMBLY 1-RUN IN HOLE ON ELEVATORS FROM 333'TO 18598' 1 1 I•NO TIGHT SPOTS ENCOUNTERED DURING ,TRIP Printed 8/30/2013 12:08:35PM O 4i/, f," *'r / h„!,£';' r r'?cf fY ,�,' e .ire . iii „,/,';,;(,/,;.#,y, ,A,,,,4/4::/4, :,,,e,0,/,',/if,072/1':kW';if 44,50'''Ot;47/4 Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69 00usft(above Mean Sea Level) Date From To Hrs Task Code NPT I NPT Depth Phase Description of Operations _- — (hr) ' (usft) 04:30 - 06:30 2.00 I CLEAN P DECOMP 'SLIP AND CUT DRILL LINE-RIG SERVICE -PJSM I-SLIP AND CUT 59.5'OF DRILL LINE AS PER DOYON PROCEDURES -SERVICE AND INSPECT TOP DRIVE,BLOCKS I AND DRAWWORKS 06:30 - 07:30 1.00 CLEAN P I DECOMP I-RIH WITH RCJB BHA. I I-CALIBRATE TOP DRIVE BLOCK HEIGHT AND SET DEPTH. -RIH F/8598'TO/8700' I I-ESTABLISH PARAMETERS:PUW 190K LBS, I I SOW 131K LBS,ROT WT©40 RPM=152K LBS,FREE TORQ=5-6,8 BPM=2220 PSI. I-WASH DOWN F/8748'TO/8758',1 SPOT AT 5K, DRILLED OFF QUICKLY. 1 I -WOB=2,TORQ ON BOTTOM=6-7K 07:30 - 09:00 1.50 CLEAN P I DECOMP I CIRCULATE 30 BBL HI-VIS SWEEP AROUND, 10 BPM @ 3400 PSI. I I -SAND CAME BACK AFTER 3000 STROKES. 09:00 - 13:00 , 4.00 CLEAN P DECOMP PULL OUT OF HOLE WITH 6 1/8"RCJB i ASSEMBLY -MONITOR WELL FOR 10 MINUTES. I-RACK BACK 1 STAND OF 4"DP. i j I-HOLD PJSM TO POOH. I -BLOW DOWN TOP DRIVE. I -LINE UP TO GET A ZERO MARK ON THE TRIP TANK. -POOH F/8693'TO/428' -MONITOR WELL FOR 10 MINUTES BEFORE PULLING NON SHEARABLES THROUGH STACK. -RACK BACK 1 STAND OF 4"DP AND 3 I ;STANDS OF 4-3/4"DRILL COLLARS. 13:00 - 14:00 1.00 I CLEAN 1 P 1 DECOMP I CHECK RCJB FOR DEBRIS AND PULL ,ASSEMBLY -SERVICE BREAK RCJB,LD BOOT BASKETS, JARS AND MAGNETS. 14:00 - 15:00 1.00 I CLEAN P DECOMP CLEAR RIG FLOOR OF BHA LCLEAN RIG FLOOR. 15:00 - 16:00 1.00 ' CLEAN P , DECOMP FLUSH BOP STACK , I -M/U STACK WASHER I -FLUSH STACK -LID STACK WASHER. 16:00 16:30 0.50 BOPSUR I P I' DECOMP PREP FOR BOP TESTING -MAKE UP XO'S TO TEST FOSV I-SUCK OUT BOP STACK. Printed 8/30/2013 12:08:35PM • 1/35-37' 77"/-47,77'77'r Y F �ry � � , , t !/';" ice �..z. � r;'�, 'r r'/./�..✓,F' Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 End Date:8/21/2013 IX3-013MH-C:DRILL(4,390,000.00) I Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 I Spud Date/Time:9/1/1977 12:00:00AM I Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs Task , Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 16:30 - 18:30 1 2.00 BOPSUR P I DECOMP PULL L DEBRIS FROM UPPER RAM CAVITY. I 1-AFTER SUCKING OUT BOP STACK A PIECE OF CAST WAS NOTICED IN THE UPPER RAM I CAVITY. -NOTIFIED WSL. I I I !-HELD PJSM TO OPEN RAM DOOR. -BLIND RAMS WERE SHUT. I -HCR CHOKE AND KILL LINES WERE OPENED. I , -PUMPED ACROSS WELL BORE TO MONITOR WELL DURING OPERATION OF OPENING TOP RAMS. 1 OF-PIECE O CAST INSIDE TOP RAM WAS 1 IREMOVED. 1 —CLEANED UP DOOR SEAL AND BOLTS. -CLOSED DOOR AND CLEANED CELLAR AREA. -INSTALLED WEAR RIG TOOL AND PULLED I I WEAR RING. G 1 18:30 - 19:30 1.00 BOPSUR P DECOMP 1FLUSH BOP STACK -MAKE UP STACK WASHER AND FLUSH STACK. 1119:30 - 21:00 1.50 BOPSUR P DECOMP INSTALL TEST PLUG I i- R/U XO'S TO TEST FOSVS I-INSTALL TEST PLUG. 21:00 - 21:30 0.50 BOPSUR P DECOMP 1HOLD KICK DRILL. -1:30 MINS TO SECURE WELL. -ALL CREWMEMBERS AND 3RD PARTY PERSONNEL RESPONDED. -AAR WITH CREW. -6 BBLS TO FILL MUD GAS SEPARATOR 21:30 - 22:30 1.00 BOPSUR P DECOMP 'SHELL TEST MANIFOLD&BOP STACK 250 PSI LOWAND 3500 PSI HIGH FOR 5 CHARTED II MINUTES 22:30 - 00:00 1.50 BOPSUR P DECOMP 1BOPE TEST. 11-TEST BOPE TO 250 PSI LOW,3500 PSI HIGH I 1 I FOR 5 CHARTED MINUTES EACH. i j-TESTED BAG WITH 4"TEST JOINT. 8/17/2013 100:00 - 05:30 5.50 BOPSUR P I DECOMP TEST BOPE'S -TEST BOPE TO 250 PSI LOW/3500 PSI HI FOR 5 MINUTES EACH -TEST ANNULAR WITH 4"TEST JOINT -TEST UPPER AND LOWER VBR'S WITH 4" I 1AND 4.5"TEST JOINT *ALL TESTS CHARTED(SEE ATTACHED BOP TEST CHARTS) I -TEST WITNESS WAIVED BY JEFF I , I TURKINGTON(AOGCC REP)AT 6:06 PM I8/16/2013 W 05:30 - 07:30 I 2.00 HSUR P 1 DECOMP ',PJSM,PULL TEST PLUG -INSTALL WEAR RING. I -PJSM,BLOW DOWN CHOKE AND KILL LINES. RIG DOWN TEST EQUIPMENT 07:30 - 08:00 0.50 , DHB P DECOMP I PJSM,MOBILIZE HES RETRIEVAL TOOL TO I , I RIG FLOOR. -BEAVER SLIDE OPERATIONS. -MAKE UP 1 STAND TO HES RUNNING TOOL Printed 8/30/2013 12:08:35PM • • ce` 9 e, r ° � � i _';',77'4", i i ' ys -4,,,, ,i / - ,.44,220,/,'/:::,71,-/,/:°://7- * 7,;;;-•#:',/: „,47; .22-7:,,',,:j am`. e ,,�/p/:,-..� 'Y, Common Well Name:05-16 1 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 1X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe y Rig Name/No.:DOYON 14 12:00:00AM Spud Date/Time:9/1/1977 12:0 Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 1 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 4 (hr) (usft) 08:00 - 11:30 3.50 DHB 1 P DECOMP RUN IN HOLE WITH HES RBP RETRIEVAL TOOL -PJSM '-RUN IN HOLE ON 4"DRILL PIPE FROM 14'TO 7,614' 7 11:30 - 12:00 0.50 DHB P DECOMP PJSM,GREASE AND INSPECT TOP DRIVE, IDRAW WORKS AND BLOCKS. !-ADJUST DERRICK CAMERA. I.0 BBL FLUID LOSS FROM MIDNIGHT TO 112:00 - 13:00 1.00 � DHB P DECOMP I RUN N HOLE WITH HES RBP RETRIEVAL i TOOL : -PJSM, I 1-RUN IN HOLE ON 4"DRILL PIPE FROM 7,614' TO/8753' 13:00 - 13:30 0.50 DHB P DECOMP I TAGGED @ 8794'WITH 7K DOWNWEIGHT -SUSPECT TAG ON TOP OF 7"RBP. -PICK UP WITH NO DRAG,RUN BACK IN HOLE PAST SETTING DEPTH OF 8800'TO 8810'. I-CONFIRMED RBP WAS RELEASED. 13:30 15:30 2.00 DHB P DECOMP I PUMP HI-VIS SWEEP. 4I CLOSE BAG,OPEN CHOKE. PUMP SWEEP @ 6 BPM FOR 30 BBLS. I I I-PUMP BOTTOMS UP WITH 6 BPM @ 750 PSI. � ; I I-SET RBP AT 8790'TO CONFIRM PLUG ON , I I TOOL. I-SET DOWN 10K TO CONFIRM SET. - �',, I-RELEASE RBP AND CONFIRM BY RUNNING PAST SET DEPTH(8790') 15:30 - 16:00 0.50 DHB r- P DECOMP INSTALL AIR SLIPS. 1 ,-10 MIN FLOW CHECK. -PJSM -INSTALL STRIPPING RUBBER AND AIR SLIPS. 19:00 3.00 16:00 - ' DHB P DECOMP PULL OUT OF HOLE ON ELEVATORS WITH 7" i 1 RBP -POOH F/8753'TO/14'. 19:00 - 20:00 1.00 DHB P DECOMP I PJSM,LAY DOWN HES RUNNING TOOLAND I RBP. 20:00 - 20:30 0.50 CLEAN 1 P DECOMP I HOLD PJSM TO P/U BAKER TOOLS AND RUN I DRESS OFF ASSEMBLY. 20:30 - 21:30 1.00 CLEAN P DECOMP MAKE UP DRESS OFF BHA WITH JARS, BUMPERS,BOOT BASKETS,POS,CASING I t_ _ SCRAPER AND DRILL COLLARS. 21:30 - 00:00 2.50 CLEAN P I DECOMP RUN IN HOLE WITH DRESS OFF ASSEMBLY. 1-R11-1 WITH DP F/353'TO/7003' 8/18/2013 1 00:00 - 03:00 3.00 CLEAN P DECOMP RIH W/DRESS OFF AND SCRAPER ASSEMBLY. -HOLD PJSM. -REVIEW FLUID MANAGEMENT SOP AND KICK WHILE TRIPPING DOC. -RIH W/4"DP F/7003'TO 10328'. - _-___- i-P/U PIPE FROM PIPE SHED. Printed 8/30/2013 12:08:35PM . S �%l%�.%'d7;7 ,i:.' x,- �,�:i i iYV ,Ar F, ,�,�,,:{ 4 s r ,#/: ;iii i. f - ;, 1 "i4 a .141",-/::/l' e'l?g Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 1 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°1558.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69_O0usft(above Mean Sea Level) Date From-To I Hrs I Task Code NPT NPT Depth Phase Description of Operations 03:00 04:30 + 1 50 I CLEAN P (usft) DECOMP DRESS OFF TUBING STUB I -PJSM -TAG TUBING STUB AT 10383' 1 i-ESTABLISHED PARAMETERS:PUW=225K, 1 SOW=145K,ROT=167K -PUMP AT 5 BBL/MIN @ 940 PSI -ROTATION AT 80 RPM @ 7-8K TORQUE I-DRESSED OFF STUB WITH SHOE. SWALLOWED STUB AND DRESSED OFF 6"OF 1 ;STUB AT 5-7K WOB -PULL OFF OF STUB AND SHUT DOWN PUMPS AND ROTATION. -ATTEMPT TO SLACK OFF BACK ON STUB, BUT COULD NOT WITH OUT ROTATION.ABLE , 1 TO ROTATE 20 RPMS AND GET ONTO STUB. -ATTEMPT 3 TIMES WITH OUT ROTATION WITH NO SUCCESS. -PICK UP OFF OF STUB. 04:30 - 09:00 4.50 CLEAN P ; } DECOMP PUMP SWEEP/SWAP WELLBORE FLUID WITH SEAWATER -PJSM -STAGE TRUCKS AND TAKE ON SEAWATER TO RIG PITS. -LINE UP PITS AND TRUCKS TO SWAP WELL OVER TO SEAWATER -PUMP 40 BBL SWEEP FOLLOWED BY 8.5 I SEAWATER TO SWAP WELL OVER TO 1 SEAWATER. -PUMPED AT 10 BPM @ 3020 PSI AND SLOWED TO 9 BPM @ 2100 PSI AFTER HOLE I WAS DISPLACED. -CLEANUP UNDER SHAKERS AND CLEAN TRIP TANK. fi 09:00 12:00 3.00 CLEAN 1 P ! DECOMP LAY DOWN DRILL PIPE. I 1 1-PJSM. -LD DP F/10383'TO 8428' -HELD KICK WHILE TRIPPING DRILL, I SECURED WELL IN 2:46,HELD AAR W/ALL 'HANDS 12:00 - 12:30 0.50 CLEAN P 1 1 DECOMP SERVICE DRAWWORKS,TOP DRIVE AND BLOCKS. t 1 12:30 - 14:00 1.50 CLEAN P 1 1 DECOMP PULL OUT OF HOLE ON ELEVATORS WITH 4" DRILL PIPE AND DRESSOFF BHA -PJSM I-LAY DOWN DRILL PIPE TO PIPE SHED I-LD DP F/8428'TO 6190' 14:00 - 14:30 0.50 CLEAN P 1 DECOMP KICK WHILE TRIPPING DRILL 1-RESPONSE TIME=1:30 HELD AAR W/ALL HANDS. 114:30 - 17:30 3.00 CLEAN P DECOMP PULL OUT OF HOLE ON ELEVATORS WITH 4" j DRILL PIPE AND DRESSOFF BHA I-LAY DOWN DRILL PIPE TO PIPE SHED F/6190' TO 2800'. 17:30 - 18:00 I 0.50 CLEAN P DECOMP SERVICE ROUGHNECK AND DRAWWORKS I-LUBRICATE ROUGHNECK AND N RREP DRAWWORKS. 1 18:00 - 18:30 0.50 CLEAN 2,800.00 DECOMP I REPLACE HYDRAULIC HOSE ON PIPE SKATE I AFTER HOLDING PJSM. Printed 8/30/2013 12:08:35PM • • r,,�, „,/,,,, ,,,� �, 0/e ra ;/a a a f'r* ,r :�o i 4,i-„,,,,,,,,,,,,,,7,r7,,,e4,,,/,'”eee,/,‘/ Avel-1/. '''.‹,,:et/' /Ai,' /,/,-,e/e/ke ..e.ee,eeee" i` / Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 14X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) - Date From-To 1 Hrs Task Code !- NPT I NPT Depth Phase , Description of Operations (hr) (usft) - 1 ( ) 1 PULL OUT OF HOLE ON ELEVATORS WITH 4" 18:30 20:00 1.50 CLEAN P DECOMP � 1 DRILL PIPE AND DRESSOFF BHA -LAY DOWN DRILL PIPE TO PIPE SHED F/2800' TO 400' 20:00 20:30 0.50 CLEAN P DECOMP FLOW CHECK AND PJSM '-10 MIN.FLOW CHECK,WELL STATIC. — — 1 r -HELD PJSM TO LAY DOWN DRILL COLLARS. 20:30 - 22:00 1.50 CLEAN P DECOMP LAY DOWN BHA -LAY DOWN DRILL COLLARS -BREAK DOWN JARS,MAGNETS,BOOT 1 BASKETSAND OVERSHOT INNER MILL AND I LAY DOWN 22:00 - 23:00 1.00 CLEAN P DECOMP CLEAN OUT AND LAY DOWN BAKER TOOLS. -PJSM. -CLEAN OUT BOOT BASKETS. I-LD BOOT BASKETS AND BAKER TOOLS DOWN BEAVER SLIDE TO GROUND 23:00 00:00 1.00 I RUNCOM P RUNCMP RIG UP TO RUN COMPLETION. -PJSM. � -LAY DOWN SHORT BALES. -PU XO'S. ! s ! 1-PULL WEAR RING. ;-MAKE DRY RUN WITH TUBING HANGER. 8/19/2013 00:00 01:00 1.00 1 RUNCOM P RUNCMP I CLEAR RIG FLOOR. -PJSM. -CLEAN AND CLEAR RIG FLOOR OF ALL 1 TOOLS NOT NEEDED FOR UPCOMING OPS. 01:00 03:00 2.00 RUNCOM P RUNCMP RIG UP TO RUN COMPLETION. -PJSM. -MOB CASING EQUIPMENT TO RIG FLOOR. -RIG UP POWER TONGS AND COMPENSATOR -RIG UP ELEVATORS AND SINGLE JOINT ,ELEVATORS *FIRE DRILL-1 MINUTE AND 17 SECONDS RESPONSE TIME. ,03:00 - 12:00 9.00 RUNCOM 11 P RUNCMP RUN 4.5",12.6#,13CR-85 VAMTOP TUBING (WITH ASSOCIATED JEWELRY)TO 900' -USE JET LUBE SEAL GUARD PIPE DOPE ON ALL CONNECTIONS NOT BAKER LOCKED 1-BAKER LOCK ALL CONNECTIONS BELOW TNT PACKER ' ' -TORQUE CONNECTIONS TO 4,400 FT-LBS 1 -INSPECT PACKER BEFORE GOING INTO ,HOLE -PJSM,RIH FROM 900'TO 6,154'. , *0 BBL FLUID LOSS FROM MIDNIGHT TO NOON. 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM,LUBRICATE AND INSPECT DRAW WORKS,BLOCKS AND TOP DRIVE. 12:30 - 17:00 4.50 RUNCOM P RUNCMP PJSM,RUN 4.5",12.6#,13CR-85 VAMTOP ' TUBING. -RIH FROM 6,154'TO 9988'. 17:00 - 17:30 0.50 RUNCOM P 1 RUNCMP HELD H2S RIG EVACUATION DRILL AND AAR WITH ALL PERSONNEL ON SITE. Printed 8/30/2013 12:08:35PM • • • % / m � .e " -,. . ' � o � f d % i jet / . '''X A.:‘'''<';'7/.i:'''f*7**' e i � 7 �� /. %" Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 I End Date:8/21/2013 —7X3-013MH-C:DRILL(4,390,000.00) Project:Prudhoe Bay Site:PB DS 05 I Rig Name/No.:DOYON 14 I Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°1558.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.00usft(above Mean Sea Level) Date From-To I Hrs I Task Code I I NPT � NPT Depth � Phase Description of Operations 17:30 18:30 1.00 RUNCOM 1 (usft) (hr) P RUNCMP I RUN 4.5",12.6#,13CR-85 VAMTOP TUBING. I-RIH F/9988'TO 10361'. I-PICK UP EXTRA JOINT TO SPACE OUT. -SAW 1ST SET SHEAR SCREWS SHEAR AT 7K AND SECOND SET OF SCREWS SHEAR AT 10K.BOTTOMED OUT AND SET 15K TO CONFIRM NO-GO. -SPACE OUT-NO PUP JOINTS NEEDED -LAY DOWN EXTRA JOINT 18:30 - 19:00 0.50 RUNCOM P RUNCMP I LAND TUBING HANGER. -P/U LANDING HANGER AND LAND HANGER. I-RUN IN LOCK DOWN SCREWS. -FINAL POSITION OF TUBING:MULE SHOE 10396.63',TUBING STUB AT 10382',NO-GO AT 10377.87' -FINAL PUW 172K,SOW 125K. *RAN TOTAL OF 242 JOINTS OF 4.5",12.6# 1 13CR-85 VAMTOP TUBING WITH ASSOCIATED JEWELRY. _. I*RIG RKB AT 27.63 TO UPPER LOCKDOWN SCREWS. *SEE ATTACHED TUBULAR SUMMARY AND jVENDOR FILES FOR DETAILS. 19:00 - 20:00 1.00 RUNCOM P RUNCMP ,HELD PJSM TO RIG UP TO PUMP BOTH WAYS. -REVIEW VALVE LINE UP AND TRUCK PLACEMENT I-REVIEW ROLES AND RESPONSIBILITIES OF HANDS DURING JOB 20:00 - 21:00 1.00 ! RUNCOM ' P i RUNCMP RIG UP HIGH PRESSURE LINES IN CELLAR& CHOKE MANIFOLD. 11, -TEST LINES TO 3500 PSI. 21:00 - 23:30 2.50 RUNCOM P I RUNCMP ;CIRCULATE IN CORROSION INHIBITOR. -PUMP 150 BBLS OF 8.5 SEA WATER DOWN IA FOLLOWED BY 300 BBLS OF SEA WATER W/ CORROSION INHIBITOR TAKING RETURNS THRU TUBING 23:30 00:00 0.50 RUNCOM P RUNCMP PREP TO DROP BALL AND ROD. 1 I -FLOW CHECK FOR 10 MINUTES AT GAS BUSTER. II I-PUMP 2 BBLS DOWN TUBING TO WASH I SEAT. -OPEN BLINDS. -INSTALL LANDING JOINT INTO HANGER TO DROP BALL AND ROD. Printed 8/30/2013 12:08:35PM • • -/':ZZ:;j'V;,:A'9',/,'::;:;e;fi0-"A%,,;>IA-..,74fit/fr,AP *'''7`.3`7,/,,,,,, 1/(;274°'";2‘reir 47/-.''''',"4 --;')/-P•::<;""''-'1''''''/A>: jam® Common Well Name:05-16 1 AFE No Event Type:WORKOVER(WO) I Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) 1 Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table©69.0ousft(above Mean Sea Level) Date From-To 1 Hrs 1 Task 1 Code 11 NPT NPT Depth Phase Description of Operations (hr) ' (usft) , 8/20/2013 4 00:00 - 03:00 3.00 RUNCOM P 1 RUNCMP SET PACKER. 1-PJSM. 1 , , -DROP BALL AND ROD. , � -RU TO TEST TUBING. -PRESSURE UP TUBING(SET PACKER WHILE 1 PRESSURING UP START SET AT 1900 PSI, 1 FINAL SET AT 3000 PSI)TO 3790 PSI AND TEST FOR 30 CHARTED MINUTES.15 MIN I BLEED DOWN=3745 PSI,30 MINI BLEED 1 DOWN=3725 PSI. , -BLEED TUBING TO 2550 PSI. 1-PRESSURE UP IA TO 3750 PSI AND TEST FOR 30 CHARTED MINUTES.15 MIN BLEED DOWN=3640 PSI,30 MIN BLEED DOWN=3600 1 I PSI. -BOTH CHARTS PASSED TESTING CRITERIA ' 1 AS PER 10-45. 1 -CONTACTED WTL RICHARD BURNETT AND i REVIEWED INFORMATION WITH HIM. SECURED APPROVAL TO MOVE FORWARD 1 WITH PLAN AT 2:20 AM 8/20/2013. 1-BLEED TUBING DOWN AND SHEARED DCK 1 1 VALVE.CONFIRMED SHEAR WITH IA 1 '� {BLEEDING DOWN WITH TUBING. 1-CIRCULATE DOWN IA5 BBLS,SWITCHED AND CIRCULATE DOWN TUBING 5 BBLS 03:00 - 04:30 1.50 WHSUR ! P RUNCMP INSTALL TWC -PJSM 1-DRY ROD TWC INTO WELL 1-TEST TWC FROM BELOW TO 1000 PSI FOR 110 MINUTES-GOOD 1-TEST TWC FROM ABOVE TO 3500 PSI FOR 10 MINUTES-GOOD 04:30 - 05:30 1.00 BOPSUR P RUNCMP PREPARE TO NIPPLE DOWN BOPE I 1-PJSM 1 1-SUCK OUT STACK BLOW DOWN CHOKE 1 LINE AND MANIFOLD,BLOW DOWN KILL LINE -EMPTY PITS AND CLEAN -NIPPLE DOWN FLOWLINE AND RISER _ -NIPPLE DOWN BOPS 05:30 - 08:30 3.00 RIGD P 1 RUNCMP RIG DOWN CELLAR. I 1 , 1-PJSM. I 1-CLEAN OUT DRIP PAN. -REMOVE MOUSE HOLE. 08:30 - 10:30 2.00 BOPSUR P RUNCMP NIPPLE DOWN STACK. -PJSM. -N/D STACK. -REMOVE FLOW,BLEED OFF AND HOLE FILL 'LINES. 1 ,-REMOVE RISER AND TURNBUCKLES. I -BREAK BOTTOM OF SPACER SPOOL. -RACK BACK AND SECURE STACK 110:30 - 12:00 ' 1.50 1 WHSUB P WHDTRE HELD PJSM TO INSTALLADAPTOR FLANGE 1 2.00 WHSUR 1 AND DRY HOLE TREE. – — 12:00 - 14:00 P 1 WHDTRE NIPPLE UP DRY HOLE TREE. 1-N/U ADAPTOR FLANGE AND DRY HOLE TREE. 1 1 , -TEST HANGER VOID TO 5000 PSI FOR 30 CHARTED MINI. , 1 1 1-AT SAME TIME CLEAN DRIP PANS AND RIG 1 1 I UP TO TEST LUBRICATOR. Printed 8/30/2013 12:08:35PM • /;,..x/y/ ''jam yMi,r% i � ,7** ilad , e e Common Well Name:05-16 AFE No Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) ' I Project:Prudhoe Bay Site:PB DS 05 Rig Name/No.:DOYON 14 Spud Date/Time:9/1/1977 12:00:00AM Rig Release:8/21/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°15'58.646"6 Long: 0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Date From-To I Hrs 1 Task Code I NPT NPT Depth Phase Description of Operations 1 (hr) (usft) 14:00 - 15:30 1.50 WHSUR P WHDTRE TEST TREE TO 5000 PSI 15:30 - 16:00 0.50 WHSUR P WHDTRE PJSM WITH DSM ON TESTING AND PULLING t— —_ LUBRICATOR. 16:00 17:30 1.50 WHSUR P WHDTRE TEST LUBRICATOR 250 PSI LOW&3500 PSI I HIGH FOR 5 CHARTED MINS.EACH. 1 17:30 - 18:00 0.50 WHSUR P WHDTRE I HELD PJSM TO RIG UP,PUMP FREEZE PROTECT AND U-TUBE. 18:00 - 20:00 2.00 WHSUR P WHDTRE I RIG UP TO FREEZE PROTECT. -R/U HIGH PRESSURE HOSES&1502 FITTINGS TO SQUEEZE MANIFOLD. -TEST LINES TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINS.EACH. 20:00 20:30 0.50 WHSUR O A_._-- - P WHDTRE I HELD PJSM W/LRS ON HOOKING UP TO IA AND PRESSURE TESTING. 20:30 21:00 0.50 WHSUR P WHDTRE PRESSURE TEST LINES TO 3500 PSI. 21:00 - 22:30 1.50 WHSUR P WHDTRE PUMP FREEZE PROTECT DOWN IA. -PUMP 140 BBLS OF DIESEL. -2 BPM @ 460 PSI. 22:30 - 23:30 1.00 WHSUR P WHDTRE LET DIESEL U-TUBE BETWEEN IA&TUBING. -AT SAME TIME R/D HIGH PRESSURE LINES ON RIG FLOOR. 23:30 - 00:00 0.50 WHSUR P WHDTRE 'i RIG DOWN. -PJSM. -R/D AND SUCK OUT HIGH PRESSURE LINES. 8/21/2013 00:00 - 03:00 3.00 WHSUR P WHDTRE INSTALL BPV -PJSM. -INSTALL AND TEST LUBRICATOR TO 250 PSI LOW,3000 PSI HIGH FOR 5 CHARTED MINUTES EACH-PASS. -INSTALL BPV. -SIMOPS-PICK UP AROUND RIG FOR MOVE AND PREP RIG FLOOR TO SKID. 03:00 - 04:00 1.00 WHSUR P WHDTRE TEST BPV -TEST BPV FROM BELOW TO 1000 PSI FOR 10 MINUTES-PASS. 04:00 - 06:00 SECURE TREE 2.00 WHSUR ' P WHOTRE I -SECURE TREE AND CELLAR AREA. 1-RIG DOWN HOT OIL SERVICES. -LAY DOWN LUBRICATOR. RIG RELEASE AT 06:00 HOURS. Printed 8/30/2013 12:08:35PM S North America-ALASKA-BP Page 1 of 2 Cementing Report Common Well Name:05-16/02 I Report no.:1 Report date:8/6/2013 Project:Prudhoe Bay Site:PB DS 05 I Spud Date/Time:9/1/1977 T Event Type:WORKOVER(WO) j Start Date:7/30/2013 End Date:8/21/2013 1 AFE No.: Contractor:DOYON DRILLING INC. I Rig Name/No.:DOYON 14 Rig Release:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) UWI:/Lat:070°15'58.646"6 Long:0148°2422.460"W I Active datum:Kelly Bushing/Rotary Table©a 69.00usft(above Mean Sea Level) General Information Job type: Primary Cement job start date/time: 8/6/2013 5:00PM Job end date/time: 8/6/2013 7:25PM Cement Company: SLB-CEMENTING Cementer: MICHAEL ANDREW Cemented String: CASING PATCH 1 String Size: 7.000(in) String Set TMD: 8,691.71 (usft) Hole Size: 8.500(in) Pipe Movement • Pipe Movement: NO MOVEMENT Rotating Time(Start-End): RPM: Rotating Torque(init/avg/max): (ft-lbf) Reciprocating Time(Start-End): Recip Drag Up/Down: - (kip) SPM: Stroke Length: Fluid Name: Fluids(1 of 2) Slurry Type: CEMENT Purpose: PRIMARY Class: G-CLASS Description: LEAD SLURRY Density: 15.80(ppg) Yield: 1.1700(ft'/sk) Mix Water Ratio: 5.196(gal/sk94) Excess: Mix Method: BATCH Sacks Used: 749.00(941b sacks) Water Volume: 92.7(bbl) Excess Slurry Volume: 0.0(bbl) Density Measured by: Other Volume: Total Vol in Well: 156.0(bbl) Slurry Volume: 156.1 (bbl) Excess Measured From: Mud Type: WATER/BRINE Density: 9.80(ppg) PV: 0.30(cp) YP: 0.000(Ibf/100ft2) Viscosity: 0.00(s/qt) Gels 10 Sec: 0.000(Ibf/100ft') Gels 10 Min: 0.000(Ibf/100ft2) Additives Name Type Amount Units Concentration Unit D047 ANTIFOAM AGENT 0.200 GAUSX • D065 DISPERSANT 0.600 %BWOC D600G GASBLOK 2.000 GAUSX D167 FLUID LOSS 0.200 %BWOC D177 RETARDER 0.010 GAUSX Fluid Name: DISPLACEMENT Fluids(2 of 2) Slurry Type: DISPLACEMENT Purpose: DISPLACEMENT Class: Description: BRINE Density: 8.40(ppg) Yield: Mix Water Ratio: Excess: Mix Method: Sacks Used: Water Volume: Excess Slurry Volume: 0.0(bbl) Density Measured by: Other Volume: Total Vol in Well: Slurry Volume: 220.0(bbl) Excess Measured From: Mud Type: WATER/BRINE Density: 9.80(ppg) PV: 0.30(cp) YP: 0.000(Ibf/100ftl Viscosity: 0.00(s/qt) Gels 10 Sec: 0.000(Ibf/100ft2) Gels 10 Min: 0.000(Ibf/100ft2) Printed 9/4/2013 3:37:52PM I • ,.,\,,,,,,,,,,,,,.,, .k:.\\4,;,,,,,,,N:;:,.k.\\,- ,.,,.,,''",'1 r V,..i,\..,,,,,.\\,.,4\\\:'',;,‘,Ne NIN:HZ,,,..; \N. 1,,,,t,,,kl:i,:.,..,:,'''',i k.''„ ,'•,,.,Z,?,.,k,4.1.,,,\,,,,,,,x,z,!.,\,...;\"1;::,.,,\'‘,„:'‘,..\.<,.,,N .,, \\,,,,,,I,,.,.,, .\..„,„:,,.,,:,,,,.\\,,,,,,k:<.x, ,;‘,,,,i ,,k,,,..,,\,,,,,,,,,,,,:::\... ,,,,,,,s.t:,.‘.,,,,.,..,,,x.,...,.,,,,,,.\.,.,,,,..\\\,, ,,‘,\H‘,,,,::.\\\s.•,,,,L\2 k,,,,\.,, ,,,.il\'' ,,,,‘''\,`■:\.,,,\\''.T\,..\X'''(\''''7:\i'"•,,','',',\;,s‘.:''":‘'''''''.,4,..,A''','::' ,,,,,v::','i'v,!',,:,v,,.'S.,„,‘;,ii;4:,,,,*1;\:'xi,,,,,,,'4,,—‘'i'.';..'*::4.','\1z..,'''>,t\'''''s 1,\I:'',:\,,,,,',N,...,,\:"ck\\''''.!:;,\:,:'''''\''t*;1::s4...1-1,*,;. \*.‘',.:4\''\\‘‘"',.,t,,'''\...1' ' ''t.:1..\\.4:' .4',.,\.?*,‘`Nu\;s\s' .1:1'*'‘N,,‘ ,,,,N.\\,:i'Z'‘!■:\\''''\..,,S,':‘,1,\itz,,,,:':'::*.?:'\';:i41:\,k,.\,. .,,4.!\:,,i,$\\, ...'.\.....,,,,,,, \\:\'''''',':,,,,\:\ \-'S'\.`:''''.\..:'\: \'-',N';'‘':''''''\‘‘\'''..\\*,,,Z* N'ti'''':',\.`,7‘,,,,, *,\\t:\\;1',..,\'V\SC,..4 9.,;\ ''''''.'s. 'S',.,,,\' NI\,,,,. ‘. \'''s,s',:\\\ ''',..\\\S, ,,\, ,t,,''''N''`,,s,,*,,,.,\;',..•,\I\t,,:,` 14,,.,%,„..\to‘,. ‘:..r.,.,*'` „:''' .: \i Nks\\\,,,,,,,\. ,,,,,,,,,X,,,,,\\,,,,:lts4k\.\,,„,",,*,,,,„,,:\,.,,,,N,.`\,,14,:k,;\:1:\NN\sl„..iks:X: \'4\,'■.\\tkt,,‘"‘,,:ka,\A„, ,.z., .,,,„k, _,., Common Well Name:05-16/02 Report no.:1 Report date:8/6/2013 Project:Prudhoe Bay Site:PB DS O5 Spud Date/Time:9/1/1977 Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 AFE No.: Contractor:DOYON DRILLING INC. Rig Name/No.:DOYON 14 Rig Release:8/21/2013 X3-013M1-1-C:DRILL(4,390,000.00) UWI:/Lat:070°15'58.646"6 Long:0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Stage Stage Type Est.Top Est.Bottom Mud Circ. Mud Circ. Top Bottom Plug Pressure Float Pressure Returns Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug Bumped Bumped Held Held Prior Surface Mud Lost Flow (gpm) (psi) (psi) (min) (hr) (bbl) (bbl) After 1 PRIMARY CEMENT 3,491.67 8,691.71 N N Y 1,740.00 N Fluid pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Disp Foam Gas Type Gas Vol BH circ. Bh static Pumped Disp. Rate TMD TMD Pmp date/time job Used temp. temp. (bbl) Rate (bbl/min) (usft) (usft) (scf) (bbl/min) -LEAD SLURRY 156.0 4.80 5.80 3,491.67 8,691.71 N DISPLACEMENT- 220.0 N DISPLACEMENT Casing Test Shoe Test Liner Top Test Test Pressure: (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: (min) Tool: N Positive Test: (ppg) Positive Test Tool: N Cement Found between Shoe and Collar: N Open Hole Length: (usft) Negative Test: (ppg) Negative Test Tool: N Hours Before Start: (hr) Time before test: (hr) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) • Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: N CET Run: N Job Rating: Bond Quality: If Unsuccessful,Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: (hr) How Determined: Printed 9/4/2013 3:37:52PM .\�.. : \` \,.. �, `\.\'\ \.\.„ `\.. \,t.'\\`�\t:`?...:fit:\,.%.�o �,\ �., \\ \ ,;�,.,...°.. ® ��.�\ ,� \\`\. . ,\',,.. \'`,..:, \ \. ��\,,. w, �,\,\, ,,,,‘.\..,N,,.k , a,}.t,; ``v 14..`.,1 .,, •`.,,\„,,, k ., ,\., ..y,,,.` \,,,1 : ;$. �.• Common Well Name:05-16/02 Report no.:1 Report date:8/11/2013 Project:Prudhoe Bay Site:PB DS 05 Spud Date/Time:9/1/1977 Event Type:WORKOVER(WO) Start Date:7/30/2013 I End Date:8/21/2013 AFE No.: Contractor:DOYON DRILLING INC. Rig Name/No.:DOYON 14 [Rig Release:8/21/2013 X3-013MH-C:DRILL(4,390,000.00) UWI:/Lat:070 95'58.646"6 Long:0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Job type: Primary Cement job start date/time: 8/11/2013 9:30AM Job end date/time: 8/11/2013 11:30AM Cementer: CRAIG SAMPSELL Cement Company: SLB-CEMENTING Cemented String: CASING PATCH 2 String Size: 9.625(in) String Set TMD: 2,484.43(usft) Hole Size: 12.250(in) ti * Pipe Movement: NO MOVEMENT Rotating Time(Start-End): RPM: Rotating Torque(init/avg/max): (ft-lbf) Reciprocating Time(Start-End): Recip Drag Up/Down: - (kip) SPM: Stroke Length: Slurry Type: CEMENT Purpose: PRIMARY Class: G-CLASS Description: LEAD SLURRY Density: 15.80(ppg) Yield: 1.1800(ft'/sk) Mix Water Ratio. 5.316(gal/sk94) Excess: Mix Method: BATCH Sacks Used: 814.00(941b sacks) Water Volume: 103.0(bbl) Excess Slurry Volume: 0.0(bbl) Density Measured by: Other Volume: Total Vol in Well: 143.0(bbl) Slurry Volume: 171.1 (bbl) Excess Measured From: Mud Type: WATER/BRINE Density: 9.80(ppg) PV: 0.30(cp) YP: 0.000(Ibf/100ft') Viscosity: 0.00(s/qt) Gels 10 Sec: 0.000(Ibf/100ft') Gels 10 Min: 0.000(Ibf/100ft2) Name Type Amount Units Concentration Unit D047 ANTIFOAM AGENT 0.200 GAUSX • D065 DISPERSANT 0.750 %BWOC D600G GASBLOK 2.000 GAUSX D167 FLUID LOSS 0.200 %BWOC D186 ACCELERATOR 0.250 GAUSX Slurry Type: DISPLACEMENT Purpose: DISPLACEMENT Class: Description: BRINE Density: 9.80(ppg) Yield: Mix Water Ratio: Excess: Mix Method: Sacks Used: Water Volume: Excess Slurry Volume: 0.0(bbl) Density Measured by: Other Volume: Total Vol in Well: Slurry Volume: 172.5(bbl) Excess Measured From: I Mud Type: WATER/BRINE Density: 9.80(ppg) PV: 0.30(cp) YP: 0.000(Ibf/100ftl Viscosity: 0.00(s/qt) Gels 10 Sec: 0.000(Ibf/100ft') Gels 10 Min: 0.000(Ibf/100ft') Printed 9/4/2013 3:39:10PM . \. �\�`\ \, , ``\`�\�`��. \, \ ..,'s,,..\ ,,\ �`''\\. \ ,„\,k,,\,'-,,,,,t.,,"„,,:},,,; �., ,-V'''‘:'\ \ \ �m,,\\, a\ \‘""",,,„'.-cN`—k\\\4\\.\\.-\ \, �� ti \ :\�� �\. ,`'\,, \ .�` ,xa `. ' �.\, ,\,,ti ® '\ �`, \\ °\ \ fit ,% \',:'.. ,\:.:.,\ Common Well Name:05-16/02 Report no.:1 Report date:8/11/2013 Project:Prudhoe Bay Site:PB DS 05 Spud Date/Time:9/1/1977 Event Type:WORKOVER(WO) Start Date:7/30/2013 End Date:8/21/2013 AFE No.: Contractor:DOYON DRILLING INC. I Rig Name/No.:DOYON 14 Rig Release:8/21/2013 X3-013M Event (4,390,000.00) UWI:/Lat:070°15'58.646"6 Long:0148°24'22.460"W Active datum:Kelly Bushing/Rotary Table @69.00usft(above Mean Sea Level) Stage Stage Type Est.Top Est.Bottom Mud Circ. Mud Circ. Top Bottom ping Pressure Float Pressure Returns Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug Bumped Bumped Held Held Prior Surface Mud Lost Flow (gpm) (psi) (psi) (min) (hr) (bbl) (bbl) After 1 PRIMARY CEMENT 0.00 2,484.43 Y Y Y t 29t oo N 28.0 ,\--\\,,,,\-s �, ., .�. .....`� '\ *., ,. �.:. ;';,Via. .. `.... \ '\:..\ \ ;,, :.., �. `� \ .. \. . \. Fluid pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Disp Foam Gas Type Gas Vol BH circ. Bh static Pumped Disp. Rate TMD TMD Pmp date/time job Used temp. temp. (bbl) Rate (bbl/min) (usft) (usft) (scf) (bbl/min) DISPLACEMENT- 172.5 N DISPLACEMENT LEAD SLURRY 171.0 5.00 5.80 0.00 2,484.43 N . ` \ ti��\�� .., >..1�\� .3,.�.*�\�.,�\,•t\ �?,'`'\�.. ���', :\\�1� ',a\\,...E��...� � \\1 \�, . \;\�,.�i\ ` \i� \._�\` �`A�\\� �.`\`? �,ti '�, _ \`,`,� ,., �1\�\>,,,��\�v�\\',,:\N, , „'3\��� Casing Test Shoe Test Liner Top Test Test Pressure: (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: (min) Tool: N Positive Test: (ppg) Positive Test Tool: N Cement Found between Shoe and Collar: N Open Hole Length: (usft) Negative Test: (ppg) Negative Test Tool: N Hours Before Start: (hr) Time before test: (hr) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) • Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: N CET Run: N Job Rating: Bond Quality: If Unsuccessful,Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: (hr) How Determined: 1 Printed 9/4/2013 3:39:10PM n •TREE= 41/16"FMC • 05-16B WELlFEAD= FMC SAFNOTES: WELL ANGLE>70°@ 11280' p/� ACTUATOR= BAKER PJC DRAFT IMIAL KB.ELEV BF E L F V 4p I /%+ I ' 1 2116' 1—F4-7172"FES X MP,D=3.813"iii KOP= 3150' 20"C OhDUCTOR ? ►♦ . Max Angle= 94°(i■ 12278' i 2438' H9-5/8"I-ES ES CEMENTER I Datum IUD= NIA it. .41— 2460' H9-5/8"EXTERNAL CSG R(R,D= 8.70" I Datum ND= 8800'SS 9-5/8"CSG,47#,L-80 HYD 563,1)=8.681" —I 2480' V GAS LFT MANDRELS 9-5/8"BOWEN CSG PATCH,D=9.05" .—I 2480'-2484' ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3803 3766 27 KBG2 DCK 08/12/13 13-3/8"CSG,72#,L-80 BUTT,D=12.347" —I 2723' 3 6695 5737 53 KBG2 DM' SBK2 0 08/12/13 _.1 f ir ► 2 9053 7197 50 KBG2 OW SBK2 0 08/12/13 9-518"X 7"BKR ZXP LTP D=6.19' I 3492' I I 1 7 7906 46 KBG2 DiyiY SBK2 0 08/12/13 %� L V. 1 10 6 9-5/8"X 7"BKR FIMC FIGR D=6.18" —I 3512' �� �I ' ■■_ 8669' ---I9-5/8'X 7"BKR TEBACK SLV,0=?? I 7"L1 R,26#,L-80 VAM TOP HC, — 8692' 0383 bpf,D=6.276" 8675' H9-5/8"X 7"BKR ZXP LTP,D=6.313" I 8683' H9-5/8"X 7"BKR 1W HGR,D=6.250" I 9-5/8"CSG,47#,L-80 BUTT,ID=8.681" —I 10039' 9-5/8"CSG MLLOUT WIDOW (05-16B) 10039'-10067' ' , I 10243' H4-1/7 FESX MP,D=3.813" Minimum ID = 3.80" @ 10045' 4-1/2" H E S XN NIP g K 10272' --17"X 4-1/2"HES TNT FIR,D=3.903" I ' I 1030T I—I4-1/2"FES X NP,D=---3.i13' 4-1/2"180,12.6#,13CR 85 VAM TOP, —I 10378' I `� 10393' H7"X 4-1/2"UNIQUE OVERSHOT I .0152 bpf,D=3.958" ' •I I 10445' I—{4-1/2"FE`5 XN M?KILLED TO 3.80"(06/25/10) I 4-1/2"TBG STUB(08/18/13) —I 10383' ___.....---1 10450' J-17"X 5"BKRTEBACK SLV,D=??" I 10457' H7"X 5"BKR LIFE TOP PKR,D=3.875" I 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 10456' I I 10458' I--14-1/2"WLEG,D=3.958' 10464' H 7"X 5"BKR FAAC LNR HGR,D=3.875" 7"UM,26#,L-80,.0383 bpf,D=6.276" —1 10615' .,„i, ■ ? He"5"X 41/2"XO D=3.958" I PERFORATION StauMARY RIEF LOG:TCP FBRF ANGLE AT TOP PERF:83°@ 11700' . 1111 I 11160' —14-1/2"CEP(05/30/13) Note:Refer to Ftoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 4 11700-11756 C 07/16/03 2-7/8" 4 11765-11790 C 01/29/02 2-7/8" 4 11780-11805 C 05/06/01 2-7/8" 4 11987-12165 C 11/19/99 2-7/8" 4 17795-12961 C 11/19/99 2-7/8" 4 13004-13650 C 11/19/99 2-7/8" 4 13702-13998 C 11/19/99 14043' FISH-CEP PALLED&FUSFED TO BIM (12/25/08) I PBTD —I 14050' I 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" —1 14135' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY IHT 10/02/77 AUDI IMTIAL COMPLETION WELL 05-168 03/07/87 RWO FERMI No: 1991000 11/18/94 CTD SIDETRACK (05-16A) AFI No: 50-029-20262-04 11/20/99 NTES SIDETRACK (05-16B) SEC 32,T11 N,R15E,1913'FNL&38'FWL 08/22/13 D-14 RWO j BP Exploration(Alaska) OF e\\ 1%% s THE STATE Alaska Oil an Gas ofALAsKA Co se rvatiG Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA; Q. Anchorage, Alaska 99501 -3572 ALA`�Y' Main: 907.279.1433 Fax: 907.276.7542 David Bjork SCANNED MAY 1 0 2013 Engineering Team Leader BP Exploration (Alaska), Inc. D P.O. Box 196612 10 Anchorage, AK 99519 -6612 1() Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05 -16B Sundry Number: 313 -199 Dear Mr. Bjork: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / 31-- / Cathy :. Foerster 'l• Chair DATED this iv d of May, 2013. Encl. { • STATE OF ALASKA • Yk" ALASKA OIL AND GAS CONSERVATION COMMISSION 5 0 APPLICATION FOR SUNDRY APPROVAL ��, APR 2 4 20' 20 AAC 25.280 A ® �� n V 1. Type of Request: / l ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool . .∎ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate , ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate . ® Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 199 - 100 • 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 20262 - 02 - 00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 05 -16B Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 028326 1 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14135' - 8808' - 14050' 8808' 10441' 14043' Casing Length Size MD TVD Burst C ollapse Structural Conductor 116' 20" 116' 116' 1530 520 Surface 2723' 13 -3/8" 2723' 2723' 4930 2670 Intermediate 10039' 9 -5/8" 10039' 7824' 6870 4760 Production Liner 1946' 7" 8669 ' - 10615' 6951' - 8256' 7240 5410 Liner 3685' 4 -1/2" 10450' - 14135' 8123' - 8808' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11700' - 13998' 8782' - 8809' 4-1/2", 12.6# L -80 10458' Packers and SSSV Type: 7" x 4 -1/2" HES TNT Packer Packers and SSSV 10428' / 8106' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: June 25, 2013 ® Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Reem; 564 -5743 Printed Name: David Bjork Title: Engineering Team Leader Email: ReemDC@bp.com Signature: � ;�� Phone: 564 - 5683 Date: Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �� �_ j� Sundry Number: ❑ Plug Integrity Ll BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: P fit 5 7 �d ,3SO (.* RBDMS MAY 10 2013 Spacing Exception Required? ❑ Yes 11610 Subsequent Form Required: / 444 APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: 6 - /0 — / 3 Form 10-403 Revised 10 012 Apf TIG 'spa r 12 months from the date of approval Submit In Duplicate , ( t : z ("/ V� I V I V 1' -F s/ J // 3 4 • bp 0 Sundry Request for casing repair Well: 05 -16B Date: 4/23/2013 Engineer: Dave Reem MASP: 2420 psi Well Type: Producer Estimated Start date: June 25 2013 History: 05 -16 was originally completed in 1977 by ARCO. A RWO was completed in 1987 and this was followed by a CST in 1994. 05 -16B was rig sidetracked in 1999. During the RST, new tubing was installed and integrity tests passed. After a failing MIT -IA in 2003, it was identified GLM #3 was leaking. A patch was set over GLM #3 but was unsuccessful in isolating the leak. We pulled the patch and ran a DGLV with extended packing in STA #3 and on 1/5/06 an MIT -IA passed to 3000psi. In 2008, a cement squeeze was completed to shut off perfs @ 11700 - 11805' and the composite plug was milled and pushed to PBTD @ 14,043'ctmd. On 1/18/10 the OART build up rate was 154psi /day. This is manageable by bleeds but it is approaching the limit of 250psi /day. On 4/19/10 a caliper was run and the 4 -1/2" tubing and liner were in good condition, and also an MIT -IA passed to 3000psi and MIT -OA passed to 2000psi. On 3/21/11, MIT - OA passed to 2000psi and MIT -IA failed. An MIT -IA failed again on 3/24/11. We changed out the DGLV @ STA #3 and MIT -IA still failed. A WRP was set @ 10,441' (below production packer) and MIT -T passed to 3000psi. MIT -IA failed indicating the tubing had integrity but the production casing or packer did not. EL found a production casing leak at 5265' on 4/10/11. In 2013, an MIT -OA passed. MIT -IA failed and the LLR on the IA was measured. Last Well Test (02/04/10): Obpd oil, 143bpd water, 2mmscfd formation gas Scope of Work: Pull 4 -1/2" L -80 completion. Run 7" scab liner. Cut -n -pull 9 -5/8" casing, run and fully • cement 9 -5/8" 47# L -80 premium connection tie -back. Run 4 -1/2" chrome completion. • Pre Rig Prep Work: S 1 Pull WRP. Drift to deviation for whipstock/CIBP. S 2 Set CIBP at — 11,150'md. PT CIBP. E 3 Jet cut tubing @ 10,390'md. Reference tubing tally 11/19/1999. Cut desired to be 10' from top of first full jt above the packer. F 4 Circulate well through the cut with seawater and diesel freeze protect to 2000' md. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. ✓ 6 Set BPV in the tubing hanger. O 7 Remove the wellhouse & flow line. Level the pad as needed for the rig. • • Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 7" fixed, blind shears, mud cross' and 3 -1/2" x 6" VBR's). Test the pipe rams and annular to 3,500 psi. 2. Pull and lay down tubing to the jet cut 3. Scrape 9 -5/8" casing, scrape 7" liner and dress -off 4.5" tubing stub. 4. Run 9 -5/8" test packer to 4,000' and test casing to 3,500 psi. 5. Set 7" RBP at — 8750'md, stack 50' of sand on RBP. PT RBP. 6. Polish existing 7" liner tie -back sleeve. 7. Run ported seal -stem, 7" 26# L -80 premium connection scab liner, Baker Liner hanger, and ZXP Liner top Packer. 8. Fully cement 7" scab liner to liner top at — 3500'md. 9. Drill out 7" shoe track to the 7" RBP. Pressure test casing to 3,500 psi. ✓ r - e ,i-d 1 1.114 v Y 10. Run USIT log from — 3450'md to surface to find top of cement in 9 -5/8" x 13 -3/8" annulus. 11. Run and set 9 -5/8" RBP — 100'md below logged top of cement, stack 50' of sand on RBP. 12. Swap upper pipe rams to 9 -5/8" fixed & PT to 3500 psi. ✓ f er ° ''cl t e tiA, 13. Mechanically cut 9 -5/8" casing in top 1/3 of first cement -free joint of 9 -5/8" casing, circulate out Arctic Pack, pull and lay down casing to the cut. 14. Dress off 9 -5/8" casing stub, scrape 13 -3/8" casing. 15. Run 9 -5/8 ", 47 #, L -80 premium connection tie -back with Bowen sealing over -shot and ES- cementer. 16. Fully cement 9 -5/8" tie -back to surface. 17. Swap upper pipe rams to 3 -1/2" x 6" VBRs. PT VBRs to 3500 psi. 18. Drill out 9 -5/8" shoe -track to the RBP, PT casing to 3500 psi. Tf d $. r h k F 19. Pull 9 -5/8" RBP. 20. Pull 7" RBP. 21. Run new 4.5" 12.6 # /ft,)3Cr stacker - packer completion with 7" x 4 -1/2" HES TNT packer. MIT -T & MIT -IA to 3500 psi. v" rte,zd cy4✓ if 22. Set a BPV and RDMO. Post rig Work V 1 Pull BPV S 2 Pull ball and Rod, Pull RHC seat, drift to CIBP @ 11,150'md. 1114 ' I Fit = 1 1/16" FMC SA* NOTES: WELL ANGLE > 70° @ 11280' I • D= FM C 05 -16B ` ACTUATOR= BAKERC NT1AL KB. EL.EV = 65' BF. � ELEV = 40.T t I KOP= -_- _ 3150' I H ? Max Angle' _____.._ @ 12278' 2199' -- 14 -1t2" H E S X IMP, D= 3.813" Datum MD = _ I Datum TVD= 8800' SS - GAS LFT FMNDRELS 72#, L -80 BUTT, ID - 12.347' 27 13 -3/8' CSG, - { ST MD TVD DEV TYPE VLV LATCH FORT DATE IM 1 3738 3708 25 WAG DMY RK 0 04/19/10 Minimum ID = 3.80" @ 10045' 2 7826 6424 52 MvIG DMY RK 0 04/19/10 4 -112" H E S XN NIP 3 10318 8020 39 ! KBG -2LS *OW IFJT 0 03/30/11 * STA #3= DAY HAS EXTENDS PACKING 8669' H TOP OF BKR TACK SLV I 8675' —19-5/8" X r BKR ZXP LNR TOP PKR, D = 6.313" 19 -5/8" CSG, 47 #, L-80 BUTT, D = 8.681" H 10039' 8683' 1-19-5/8" X r BKR MAC HGR, D = 6.250" , 9-5/8" CSG 11ALLOUT WIDOW (06 -1613) 10039' - 10067' J I _.10428' 1 7 ' X 4-1/2' I-ES INT PKR, D = 3175" I 10441' H 3.77" WRP(04 /08/11) I 10445' I- 14 -1/2" I-ES XN NV? AMLLED TO 3.80' (06/25/10) I 10450' --I 7" X 5" BKR TEBACK SLV, D = 2?' I 10457' H 7" X 5" BKR LNR TOP PKR, D = 3.875' 4-1/2" TBG, 12.6#, L -80, .0152 bpf, D= 3.958' H 10456' 1 10458' (-'I -1/2" WLEG, D = 3.958" I 7" LNR, 26#, L -80, .0383 bpf, D = 6.276" --j 10615' 10464' —17' X 5" BKR MAC LNR HGR, D = 3.875" ? --I 5" X 4-1/2 ' XO, D = 1958 PERFORATION SUIMAARY REF LOG: TO? PERF ■ ANGLE AT TOPPERF: 83° @ 11700' Note: Refer to Ptoduction DB for historical perf data SIZE SFF MB2VAL Opn/Sqz SHOT SQZ 2 -7/8' 4 11700 - 11756 0 07/16/03 2 -7/8" 4 11765 - 11790 0 01/29/02 2 -7/8' 4 11780 - 11805 0 05/06/01 2 -7/8" 4 11987 - 12165 0 11/19/99 2 -7/8" 4 12225- 12961 0 11/19/99 cu4 (? to 3901 2 -7/8" 4 13004 - 13650 0 11/19/99 II/ 1 2 -7/8" 4 13702 - 13998 0 11/19/99 I 14043' 1-1 FISH- CBP MILLED & PUSHED TO BIM (12/25/08) I ( PBTD — 14050' I4 -1/2" LNR, 12.6#, L -80, .0152 bpf, D = 3.958" --I 14135' DATE REV BY CONVENTS LATE REV BY COMA/MINTS PRUDHOE BAY UNIT 10/02/77 AUDI IMTIAL COMPLETION 04/25/11 PJC GLV CJO (03/30/11) WELL 05-166 03/07/87 RWO 04/27/11 I) V /PJC GLV OO CORRECTION (04/19/10 PERMT No: ( 1991000 11/18/94 CTD SIDETRACK (05 -16A) 09/24 /12 TTW/ PJC SET WRP (4 /8/11) API No: 50- 029 - 20262 -02 11/20/99 N7ES CTD SIDETRACK (05 -166) 04/10/13 PJC DRAWING CORRECTIONS SEC 32, T11 N, R15E, 3367' FSL & 38 FWL 04/01/11 JLJ/PJC GLV C/O (03/30/11) 04/03/11 WK/PJC GLV/ MN - DCORRECTION BP Exploration (Alaska) TRl , ` 1 -1/16" FMC WELLHEAD = FMC PROAED 05-1 6C SA. NOTES: WELL ANGLE > 70° @ 11280` I.IA . ACTTOR = BAKER C INITIAL KB. REV = 65' Ne BF. REV = 40.7' 20" COND - ? V I 4 -1/2" HES X NP, ID= 3.813" I I4 I ,4' Max Angle = 14 @ 12278' (30VVf N -{ 2500' 1 -19- 518" HES ES cf;sEfJrEft Datum MD = SEALING If Datum ND= 8800' SS OVERSHOT ' GAS LIT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 19 -5/8" CSG, 47 #, L -80 HY D 563, D = 8 681" -I -2500' 4 113 -3/8" CSG, 72#, L -80 BUTT, D = 12.347" -[ 2723' 3 2 19 -5/8" X 7" BKR TEBACK SLV, D = " H -3500' $2. ►5 1 1 9 -5/8" X 7" BKR ZXP LIP, D = 6,313' -I __.' 6 8669' I- 19-5/8" X 7" BKR TEBACK SLV, D = ?? I9- 518"X7 "BKRHMCHGR,D = 6.250" -{ ►� ►�� 7" LNR, 26#, L -80 VAM'TOP HC, -1 ' 8675' - 9-5/8" X 7" BKR ZXP LIP, D = 6.313" 0383 bpf, D - 6 276' 8683' - 19 - 5/8" X r BKR WIC HGR, D = 6.250" 9-5/8" CSG, 47 #, L -80 BUTT, D = 8.681" -1 10039' 9 -5/8" CSG MLLOUT VVNDOW (05 -168) 10039' - 10067' I 10290' I HES X NP, V= 3.813'1 Minimum ID = 3.80" @ 10045' 4-1/2" HES X N NIP z 0 10320' I 7" X 4 -12 TIES TNT PKR, D= S 3 S , r 10360' 1 - 4-1i2-€S X NP, D = 3.813" il l I 4-1/2" TBG, 12.6#1, 13CR -85 VAM TOP, H I 10390' 1 - 112" UNIQUE OVERSHOT .0152 bpf, D = 3.958" /1 I ( 10445' - I4 -1/2" HES XN 1P, NULLED TO 3.80" (06125110) 14 -1/2" TBG STUB (XX/XX/13) / 10450' - 1 . 7" X 5" BKR TRACK SLV , D = ??" 1045T - 17" X 5" BKR LNR TOP Fi<R D = 3.875" 4-1/2" MG, 12.6#, L -80, .0152 bpf, D= 3.958" - 10456' I. i _, 1 10458' - 14 - 1/2" WLEG, D = 3.958" "� 10464' - 17" X 5' BKR FCC LNR HGR, D = 3.875' 7" LNR, 26#, L -80, .0383 bpf, D = 6.276" -1 10615' ? H5" X 4-1/2 " XO, D = 3.958" I - 10955 1-13.70" DEPLOY SL V, D = 3.00" I 13 -1/2" LNR, 9.3#, L -80 STL, .0087 bpf, D = 2.992" - 4-1/2" MONOBORE WHIPSTOCK (XX/XX /13) '--1 - 11030 I - 13 - 1/2" X 3 -3/16" X0,10 = 2 786" 4-1/2" LNR, 12.6#, L -80, .0152 bpf, D= 3.958" -1 - 11030 4 -1/2" CUP (XX/XX/13) -j - 11600 4 -1/2' LNR MLLOUT WINDOW (05 -16C) 11030' - PERFORATION SUMMARY REF LOG TCP PERE ANGLE AT TOP FU @ -_' Note: Refer to Production DB for historical pert data - 12100 H3 -3116" X 2 -78" XO, D = 2.377" SEE SIE INTER/AL Opn /Sqz SHOT SQZ 13 -1 /4' LNR, 6.6#, L -80 TCI, .0079 bpf, D = 2.850" - - 12100 2 7/8" LNR, 6.4#, L -80 STL, .0058 bpf, ID= 2.441 " _i_ - 13423 \ I FSTD H DATE REV BY COMMENTS DATE REV BY i COAMENTS PRUDHOE BAY UNIT 10/02177 AUDI INITIAL COMPLETION 04/24/13 DR/JMD PROPOSEDRVVO WILL: 05 11/18/94 CTD SIDETRACK (05 -16A) PERMIT No: 2100840 11/20/99 NIES CTD SIDETRACK (05 -16B) i All No: 50- 029 - 20262 -03 XX/XX/13 D RWO SK' .'2. 111N, R15E, 1913' FN't. 8 38' FW XXIXX113 NORDIC 1 CTD SIDETRACK (05 -16C) 04/10/13 PJC PROPOSED BP Exploration (Alaska) - OF Ti w�� \ \ I % % THE STATE Al 011 and Gas 1, of - ® ® conservation Commission - =�- 1 1�1 1 111 GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS �yq Main: 907.279.1433 tylp 0 9 `c013 Fax: 907.276.7542 SCAN John McMullen /cm, I a d Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05 -16B Sundry Number: 313 -198 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. erster Chair DATED this 7 day of May, 2013. Encl. STATE OF ALASKA • • . ALA S OIL AND GAS CONSERVATION COMMISSION ri 7 % A FOR SUNDRY APPROVAL APR 2 4 201 20 AAC 25.280 ^ 1. Type of Request: IOGCC ❑ Abandon ® Plug for Redrill ' ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 199 - 100 3. Address: 6. API Numbe ® D evelopment ❑ P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 20262 -02 -00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 05 -16B . Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 028326 - Prudhoe Bay Field / Prudhoe Bay Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14135' . 8808' - 14050' 8808' 10441' 14043' Casing Length Size MD TVD Burst Collapse Structural Conductor 116' 20" 116' 116' 1530 520 Surface 2723' 13 -3/8" 2723' 2723' 4930 2670 Intermediate 10039' 9 -5/8" 10039' 7824' 6870 4760 Production Liner 1946' 7" 8669' - 10615' 6951' - 8256' 7240 5410 Liner 3685' 4 -1/2" 10450' - 14135' 8123' - 8808' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11700' - 13998' 8782' - 8809' 4 - 1/2 ", 12.6# L - 80 10458' Packers and SSSV Type: 7" x 4 - 1/2" HES TNT Packer Packers and SSSV 10428' / 8106' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal -∎ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: May 15, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nathan Sperry, 564 -4258 Printed Name: J • 1 r;l 'r �r Title: Engineering Team Leader Email: Nathan.Sperry@bp.com Signatur - • 141 ' -, / Phone: 564 - 4711 Date: efA(// ,.? Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Z.I �� Sundry Number: „/ 5 ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: - l frvfrra fz plv p lacrtv,tvi i" a- pprovre" per , 2,0 A- 25 - ) / 2 (I J ' .( RBDMS MAY - 8 201 �' Spacing Exception Required? ❑ Yes LJ No Subsequent Form Required: i /2 — 4 D 9 [ 1 APPROVED BY Approved By: /✓ ✓� COMMISSIONER THE COMMISSION Date: 6 7 —/3 Form 10 Revised 10/2 2 ApioRTICitiOrtislvalid for 12 months from the date of approval Submit In Duplicate p 11 To: Alaska Oil & Gas Conservation Commission From: Nathan Sperry 0 by CTD Engineer Date: April 24, 2013 Re: 05 -16B Sundry Approval Sundry approval is requested to plug the 05 -16B perforations as part of the drilling and completion of proposed . 05 -16C coiled tubing sidetrack. History and current status: The 05 -16 was originally completed in 1977. The well was coil sidetracked in 1994 (05 -16A). Well 05 -16B was sidetracked in October /November 1999, as a 2400' horizontal well completed with 2001' perfs in Z1A. In May 2001 25' Z1 B was added. In January 2002 another 25' of Z1B was added. In July 2003 another 50' of Z1 B was added. In November 2008 Z1 B was squeezed shut due to high GOR but oil production dropped as well. Well 05 -16B is no longer a competitive producer due to high GOR and has no remaining well work options. Proposed plan: 05 -16C is to drill a through tubing sidetrack with the SLB /Nordic 1 Coiled Tubing Drilling rig on or around August 1st, 2013. The existing perforations will be isolated by a CIBP set pre -rig. The sidetrack, 05- 16C, will exit the existing 4 -1/2" liner and kick off in zone 2 and land in zone 1. The proposed sidetrack will access a 45 acre target in the Z1A sands in the northern area of DS 05. This Sundry covers plugging the existing 05 -16B perforations via the 05 -16C liner cement lob and a liner top packer if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. ,.1- C nncv TI{ Well 6P�i C dye -- -�� GO# � 'vt 145"r j t w of abv hr Oh fur iv5fysiiec/ vcf s % Waite t ev '4q � f i r 14 c rt aS� q(rgrimp'04 o�c� oI rotc. ,4 I flwielefrec( trn /'r l( S'41ov/I A/l oN, far (ea . rte 1 roi T4J "kr/a' f D f r � � , P616'1' V/; • • rf O.e ° faired, Perm 0 amss/ r etiF 1. Set CIBP at 11,600' MD. No No 2. RWO pre -CTD operations for 4 -1/2" tubing swap No No 3. S Dummy GLM No No 4. S Pull ball and rod from 4 -1/2" production packer set No No 5. S Dummy WS drift to 11,200' MD. No No 6. F MIT -IA to 3,000 psi. No No 7. F MIT -OA to 2,000 psi. - DONE 01/30/13 No No 8. E Set 4 -1/2" monobore whipstock. No No 9. V PT MV, SV, WV. No No 10. V Bleed wellhead pressures down to zero. No No 11. V Bleed production, flow and GL lines down to zero and blind flange. No No 12. 0 Remove wellhouse and level pad. No No SFr rr .��i,± �` `'%r .'rr /✓,�^` �f,' { 1c ,, .% ,/' �,,' �'i •^� ,+i F??, r ' // r'l / m ,1I t., i3) "Jr rf �` ' � ,�j'✓'" ." . � �����1�� � Qs`� � *•-.`! Fig .r Fr :ri . r' 1. MIRU and test BOPE 250 psi low and 3,500 psi high. No k-WS 2. Mill 3.80" window at 11,030' and 10' of rathole. No Yes 3. Drill Build: 4.25" 853' OH, (25 deg DLS planned). No Yes 4. Drill lateral: 4.25" OH, 1542' (12 deg DLS planned). No Yes 5. Run 2 -7/8" x 3 -1/4" x 3 -1/2" liner leaving TOL at 10,955' MD. No Yes 6. Pump primary cement job: 27.0 bbls, 15.8 ppg, TOC at 10,955'. Yes* Yes 7. Perform liner cieanout and RPM /CCL log. No Yes 8. Test liner lap to 2400 psi. No Yes 9. Perforate liner based on log interpretation (- 800'). No Yes 10. Freeze protect well to 2,500' MD. No Yes 11. Set BPV and RDMO. No Yes * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set GLV's 3. Set liner top packer with slickline. 4. ASRC flowback/well test. Nathan Sperry CTD Engineer 564 -4258 CC: Well File Joe Lastufka WELLHEAD 1 1/16" FMS • O 5 -1 6 B SA NOTES: WELL ANGLE> 70° 11280' I ACTUATOR= BAKERC NCT KB. ELEV = 65' BF.BEV =_ -- 40.7' A KOP_= _ _31_50' _ Max ngle = 14 @ 12278' ' 2199' — 14 -1/2" FES X NP, D = 3.813" Datum MD = Datum TV D= _ 8800' SS 13 -3/8" CSG, 72 #, L -80 BUTT, ID = 12.347" — 2723' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3738 3708 25 WIG DMY RK 0 04/19/10 Minimum ID = 3.80" @ 10045' 2 7826 6424 52 MMG DMY RK 0 04/19/10 4 -112" HES XN NIP 3 10318 8020 39 KBG -2LS *DMY NT 0 03/30/11 * STA #3= DMY HAS EXTENDED PACKING 8669' -- I TOP OF BKR TEI3ACK SLV 1 \ 867 5 ' —19-5/8" X 7" BKR ZXP LNR TOP PKR, D = 6.313" 8683' H 9-5/8" X 7" BKR HMC HGR ID = 6.250" 9 -5/8" CSG, 47 #, L -80 BUTT, D = 8.681" H 10039' \ ' 1 \ 9 - 5/8" CSG MLLOUT WINDOW (05 -16B) 10039' - 10067' z N.. 10428' H 7" X 4 -1 /2" HES TNT PKR, ID = 3.875" 1 10441' — 3.77" WRP (04 /08/11) 10445' H 4 -1/2" HES XN NIP, MLLED TO 3.80" (06/25/10) 1 10450' H 7" X 5" BKR TIEBACK SLV , ID = ? ?" 10457' —17" X 5" BKR LNR TOP PKR, ID = 3.875" 4 -1/2" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" -- I 10456' — � T1 t 10458' —14 -1/2" WLEG, D = 3.958" 17" LNR, 26#, L -80, _0383 bpf, D = 6.276" H 10615' `"`1111 10464' --I 7" X 5" BKR HMC LNR HGR, D = 3.875" PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 83° @ 11700' Note: Refer to Production DB for historical perf data SIZE SFF INTERVAL Opn/Sqz SHOT SQZ 2 -7/8" 4 11700 - 11756 0 07/16/03 2 -7/8" 4 11765 - 11790 0 01/29/02 2 -7/8" 4 11780 - 11805 0 05/06/01 2 -7/8" 4 11987 - 12165 0 11/19/99 2 -7/8" 4 12225 -12961 0 11/19/99 2 -7/8" 4 13004 - 13650 0 11/19/99 2 -7/8" 4 13702 -13998 0 11/19/99 14043' H FISH- CIBP MLLED & PUSHED TO BTM (12/25/08) PBTD — 14050' fi r. ¥. 4 -1/2" LNR, 12.6#, L -80, .0152 bpf, ID = 3.958" H 14135' DATE REV BY CONTENTS DATE REV BY COIME TS PRUDHOE BAY UNIT 10/02/77 AUDI INITIAL COMPLETION 04 /25/11 PJC GLV C/O (03/30 /11) WELL: 05 -16B 03/07/87 RWO 04/27/11 DAV /PJC GLV C/O CORRECTION (04/19/10 PERMIT No: `1991000 11/18/94 CTD SIDETRACK (05 - 16A) 09/24/12 11W/ PJC SET WRP (4/8/11) AR No: 50 -029- 20262 -02 11/20199 N7ES CTD SIDETRACK (05 - 16B) 04/10/13 PJC DRAWING CORRECTION SEC 32, T11 N, R15E, 3367 FSL & 38' FM._ 04/01/11 JU /PJC GLV CIO (03/30/11) 04/03/11 WK/PJC GLV / MN ID CORRECTION BP Exploration (Alaska) TREE= 1 /16" FMC • 0 1 C I WELLFEAD= FMC 5 6 SA TY NOTES: WELL ANGLE> 70° 11280' ACTUATOR = BAK —ERC PROPOSED HT WLKB.ELE(= _ 65' BF. ELEV = --4_07i. I H4 - 1/2" FES X NIP, ID= 3.813" KOP = 3150' 1 I Max Angle = )4 @ 12278' Datum MD= GAS LFT MANDRELS Datum ND = 8800' SS ST MD ND DEV TYPE VLV LATCH FORT DATE 13 -3/8" CSG, 72#, L -80 BUTT, ID = 12.347" — 2723' , 4 3 2 Minimum ID = 3.80" @ 10045' 1 4-1/2" HES XN NIP i 8669 H 9-5/8" x 7" BKR TACK SLV , D = ?? 9-5/8" WI STOCK H 10067' -- 8675' -- 1 9 -5/8" X 7" BKR ZXP LTP, D = 6.313" 9 -5/8" CSG, 47 #, L -80, D = 8.681" 1-1 10480' 8683' H 9-5/8" X 7" BKR FMAC HGR, ID = 6.250" 9 -5/8" CSG MLLOUT WMJDOW (05 - 1613) 10039' - 10067' —14-1/2" HES X NP, D = 3.813" Z X --17" X 4-1/2" HES TNT PKR, D = 3.875" i ' ' —14-1/2" FES X NP, D = 3.813" 4 -1/2" TBG, 12.6 #, 13CR -80, —1 I._ l —I4- 112" UNIQUE OVERSHOT 0152 bpf, D = 3.958" /✓1 10445' H 4 -1/2" FES XN NIP, MLLED TO 3.80" (06/25/10)) I4 -1/2" TBG STUB (XX /XXJ13) // — 10450' —I 7" X 5" BKR TEBACK SLV , D = ? ?" J ' 10457' — 7" X 5" BKR LNR TOP PKR, ID = 3.875" 4-1/2" TBG, 12.6#, L -80, .0152 bpf, D = 3.958" —I 10456' 1 08' —14-1/2" WLEG, D = 3.958" 1 �r 10464' — 7" X 5" BKR F vIC LNR HGR, D = 3.875" 7" LNR, 26#, L -80, .0383 bpf, D= 6.276" H 10615' ■ 3 -1/2" LNR, 9.3#, L -80 STL, .0087 bpf, D = 2.992" I— 10955 —� 3.70" DEPLOY SLV, D = 3.00" 4 -1/2" MONOBORE WHIPSTOCK (XX /XX /13) — 11030 I — I3 -1/2" X 3 -3/16" XO, 1D= 2.786" J 4 -1/2" LNR, 12.6#, L -80, .0152 bpf, D = 3.958" — — 11030 _ 4 -1/2" CBP(XX /XX/13) —{ —11600 4 -1/2' LNR MLLOUT W@JDOW (05 - 16C) 11030' - ' PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SIZE SPF NYTERVAL Opn /Sqz SHOT SOZ ( — 12100 — I3 - /16" X 2 -7/8" XO, D = 2.377" 3 -1/4" LNR, 6.6#, L -80 TCII, .0079 bpf, D = 2.850" —1 — 12100 I2 -7 /8" LNR, 6.4#, L -80 STL, .0058 bpf, ID= 2.441" — — 13423 I R3TD H DATE REV BY CON/ANTS DATE REV BY COMMENTS PRUD DE BAY 11Jff 10/02/77 ALX3 INITIAL COMPLETION WELL: 05-160 11/18/94 CTD SIDETRACK (05 -16A ) PERMIT No: 1991000 11/20/99 N7ES CTD SIDETRACK (05 -16B) AR No: 50 029 - 20262 - 02 XX/XX/13 D RWO SEC 32, T11 N, R15E 3367' FSL & 38' FWL XXIXX!13 NORDIC 1 CTD SIDETRACK (05 04/10/13 PJC PROPOSED BP Exploration (Alaska) • NORDIC— CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM • V12 11441 V14 I • R 7 1116 50 psi B OPS ID 00 si HNd • '' .� �o�..r.� • �,r .r.. a >.� '° V15 V11 , 11 7/16 " 5000 psi, Rx-/B Transducers , tlirt 'OGR BO 1 V2 V ` V 16 '` '-IMKI , . MM.." EGASSEc naaites+ ���� .� ® ' ' Artk Note: typical BOP ` „: ii Iii ��A.�.- , a�k� gamest rorzsre° ,L, ,....,,,::::: E '� '1` wiled tubing drilling t I I „ all in 8" 5000 P Rxa6 ... V17 �, .�` , - -77:::::::=7.,= HCR III IC IK OK To Poor Boy Gas Buster �$ ' 21116 5000 psi , RX 24 ,: ° - • - r ,•••. 9.00 "5000 P ei XCR i • ■ I J . . s . €[ a "' Meiji —ft `w ( 2-1/16" "50 psi CHECK - Iiiiiimipir:. ' .� ,, .,,, ..... ,. Manual Choke IL I rrrr. —, ' rorws u ■• �� initi. ^ 1 1116 Cameron FOV Gate Valve n 5000 psi t -ma rim........... EOH (Dies m . FP Line '. E I - Con. Hose iiiii. 0 114 TurnHako ` 10WOG To Production Tree or Cross Over , ti T - \ CoFlex Hose 611 ', 11 11 Bleed OR al • ll \ . : I •,---- • II • Cement Line In -i CV3 CV2 Ground Level Tie -7n T Stand Pipe - E — — ° Manual Choke ■ = - - — .. — Pressure Transducers ■ '41111L.,,: a a _ z..,, ::,..._7,04. ','''''' .i ' . . '' ' I i CV17 4 111 0 AL .... ....... as Tiger Tank - - Mud ` � � y —� In From I; 0 °0 17 = "' Baker � � + MP 1 b MP 2 ® �, O . ‹} ` Choke L)— 0 CV14 s to Pits 7. a x� _ Rig Floor Mud Pump #1 CV16 Reverse Ci u L, , _ _ Cv CT while OOH �, yam. �caw,,�a..,v�o����� �w " �— ICI , 0 0 To Manifold at CV15 1 1un Rey.. a Cin-ul08m line (rhpJ1ai Cones Hose • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • WELL LOG TRANSMITTAL PRoAcrivE DiAgNOSTiC SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 -1 :* M z 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey � 130 West International Airport Road /99 9 _ / y Suite C Anchorage, AK 99518 acf9aa Fax: (907) 245 -8952 1) Leak Detection - WLD /WAF 09- Apr-11 05 -16B BL / EDE 50 -029- 20262 -02 2) RECEry D 2011 cam Signed : a _ Date : Print Name: ' :87 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E-MAIL : pdsanchoraae Wmemorylog.com WEBSITE : www.memorvloa.com C:\Documents and Settings \Diane Williams \Desktop\BP_Transmit.docx • RE: 05-16B Sidetrack Explanation Foerster, Catherine P (DOA) To: 'McMullen, John C'; Roby, David S (DOA); Rebol, Amanda Thanks for the answers. We'll progress the permit. From: McMullen, John C [mailto:McMuIIJC@BP.com] Sent: Monday, July 26, 2010 10:48 AM To: Roby, David S (DOA); Rebol, Amanda Cc: Foerster, Catherine P (DOA) Subject: RE: 05-16B Sidetrack Explanation Specific answers to your July 8 questions in red font below. From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Friday, July 16, 2010 11:28 AM To: McMullen, John C; Rebol, Amanda Cc: Foerster, Catherine P (DOA) Subject: RE: 05-16B Sidetrack Explanation ~, - r~ ~; rL~~~i John and Amanda; Commissioner Foerster is holding up action on your application until we get resolution on the questions asked below. I will be out of the office for the next two weeks, so please make sure to copy Commissioner Foerster on your response. Regards, Dave Roby (907)793-1232 From: Roby, David S (DOA) Sent: Monday, July 12, 2010 10:37 AM To: 'McMullen, John C' Cc: Rebol, Amanda Subject: RE: 05-16B Sidetrack Explanation John, The reason I am asking the questions below is that some of the available data conflicts with other observations and therefore it makes it difficult to determine if the right conclusions are being made. We're just trying to make sure that the right conclusion is made before we can take action on your application. Answering the questions posed below, and providing appropriate supporting data if necessary will help us in our evaluation of the application. Also, one additional question that will help in our evaluation has occurred to me. Will the proposed new well, or another well in the area, be capable of recovering any reserves that may remain at the current wellbores location? Thanks in advance, Dave Roby (907)793-1232 • From: McMullen, John C [mailto:McMuIIJC@BP.com] Sent: Monday, July 12, 2010 10:03 AM To: Roby, David S (DOA) Cc: Rebol, Amanda Subject: RE: 05-16B Sidetrack Explanation Dave - The well in its current bottomhole location, has no future utility. As Amanda has detailed, several interventions have been performed to improve the well's competitiveness. We believe the best option at this point to effectively manage the reserves is to sidetrack the well. No other thru tubing remedial options will be pursued. We look forward to your timely consideration of the information provided to support the approval of the plugging and sidetrack. Thanks, John McMullen CTD Engineering Team Leader 564-4711 From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Thursday, July 08, 2010 9:00 AM To: Rebol, Amanda Subject: RE: 05-16B Sidetrack Explanation Amanda, Do you have any reason/theory as to why, in the absence of any water production, that even with the marginal GOR the well does not produce at a higher oil rate? For example, - Is there possible reservoir damage? Unlikely. We did a cement squeeze in 2008. But we set a bridge plug above the lower perfs before squeezing above it, and after the squeeze, the plug was solidly in place and had to be milled, so unlikely any cement touched the unsqueezed penis. Also the volume of cement was small in comparison to the liner volume so even if some cement did pass the plug, unlikely to have caused substantial damage. - is the reservoir quality where this well was completed just very poor? Poor reservoir quality plays some part, but also a small oil column (<30ft) combines to give low PI. The well is completed in Zone 1A, which has the lowest perm of all zones. A low rate is not unusual from this zone. If you continue the decline from 2001 and 2002, and extrapolate the GOR trend, it looks like the area has been draining even while the well was shut in for mechanical reasons and the GOC has been coming down. The thickness of the oil leg is a major part of the PI. Also the model indicates that as the GOC comes down, the gas saturation in the oil leg increases, decreasing oil relative permeability. The combination of low rate and high GOR can be explained because we are producing from Zone 1A where there is not a lot of LOC. Low perm to start with, low zone thickness, lowered oil relative permeability all play their part. - are their mechanical reasons that the well is incapable of higher production? The had TxIA communication which accounts for the long periods of no production, but this was sorted in 2006. So there are no mechanical issues with the well. The oil and gas rates are close to critical rate where the well would not be able to lift itself, but not yet there. Our lift software calculates BHFP of 7-800 psi, which is about as low as we get in the field. - is the well simply choked back when it is on production to restrict its gas production and thereby allow increased oil production from the other wells in the area? The well was not choked back above header pressure. - etc... Also, please provide more detail as to why no other workover options are viable. For example - could additional perforations be squezzed to reduce the gas rate? The economics aren't there for us to do another squeeze. We'd lose some of the 150-200 b/d the well is capable of now. Also if the gas rate was reduced substantially the well could fall below critical rate and not lift itself. There is no lift gas on DS-5 to help. - is it possible to shoot additional perfs in sands that may not be so gas prone? All Zone 1A was perfed initially. We did add perfs in Zone 1 B, but we squeeezed these in 2008 for gas. So no addperf opportunity. I attach the minilog for clarity. - any reasons/theories why the previous acid job did not work, and why are you not considering attempting another one? I don't think we damaged the formation with the cement. We set a bridge plug to protect the lower perfs and it was solidly in place after the squeeze. We only pumped 5 bbls which is small in comparison the the liner volume. So we don't think there's any damage there for acid to fix. - has hydraulic fracturing been considered? If so why is it not a viable option and if not why not? The oil column in Zone 1 in the GD area is 30-50 ft, at the lower value here. In the 90's we fracced many Zone 1 conventional wells. The challenge then was pumping a design that would keep the frac from growing into the gas. At that time the oil column was thick. Since then all these wells have gone above marginal as the GOC has come down, and have mostly been sidetracked as horizontal completions. GOR increase is a direct function of standoff from the GOC. Horizontal wellbores allow you to stand off almost the full column thickness by placing them at the bottom. Any frac initiating in a horizontal well will grow up and provide a more direct path for gas, resulting in higher GORs. So we don't think. fraccing any Zone 1 well is a good option. In this case, with a smaller oil column than average, we wouldn't want to do one.. - has any diagnostic work been done to attempt to identify specifically where the gas is coming from? We haven't run a log in this well. Since we don't think that a squeeze would be economic, even if we knew where the gas was coming from, we wouldn't squeeze, so the information would be academic. - Etc... It's also important to note that DS-5 has a lower marginal than other pads. The production line to the flow station has a velocity limitation and marginal is in the 40-45,000 scf/STB range. We were cycling the well towards the end of it's life, and it was getting above this fairly quickly. Thanks, Dave Roby (907)793-1232 • • John McMullen Engineering Team Leader a (~ -~ J~~4 ~ 1 t BP Exploration (Alaska), Inc. }~ ,V}~~,,k~,~ ,~i_5'i ~ ~ '~' P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-16B Sundry Number: 310-194 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. fr. DATED this ~~ay of July, Encl. a~3 JULY +G=~1 STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 6 -~5-/a 1. Type of Request: ^ Abandon ®Plug for Redrill ~ ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 199-100 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20262-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 05-16B - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028326 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY - Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14135' ~ 8808' 14050' 8808' None 14043' Casin Len Size MD ND Burst Colla e Structural Conductor 1 1 11 ' Surface 723' 1 - /8" 27 2723' 4 2 70 Intermediate 10 39' -5/ " 100 9' 7824' 7 47 0 Production Liner 1946' 7" 8669 ' - 1 1 951' - 1 1' 7 4 10 Liner 4-1/2" 1 4 ' - 14135' 12 ' - 8 08' 430 7 0 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11700' - 13998' 8782' - 8809' 4-1/2", 12.6# L-80 10458' Packers and SSSV Type: 9-5/8" x 7" BKR ZXP Packer Packers and SSSV 8675' / 6955' 7" x 4-1/2" HES TNT Packer MD (ft) and TVD (ft): 10428' / 8106' 7" x 5" BKR ZXP Packer 10457' / 8129' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 4, 2010 ^ Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned ^ WAG ^ SPLUG ®Suspended - Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Amanda Suddreth, 564-5543 Printed Name John Mc 11 Title Engineering Team Leader Prepares By Name/Number: ~ Phone 564-4711 Date ~ ~ Elizabeth Barker, 564-4628 Signature '' Commission Use Onl Conditions of approval: N tify Commission so that a representative may witness 2' O ,,,, Sundry Number: ^ Plug Integrity OP Test ^ Mechanical Integrity Test ^ Location Clearance d P ~s -~- -~ 3500 ~~~ /3 G C C ~ / / Other: ,~ ~ SDU nrt ~ ~ .T ~ ~ rr".~~) ~6.~C1..~ 11• L~.D ` S ~ . / l p JUN 2 3 20101 4~~9~~d QI~ ~i ~>l1tT CORE' ~s0~isxiAll Subsequent Form Required: I ~ ..-L,/~~ , ~n~hora APPROVED BY ~ r/v ~ Approved By: COM TONER THE COMMISSION Date G Pr I / ~ ~ ~ ~ 3Q . ~ d Submit In Duplicate ~dr~l~~,s'P ORIGINAL. ~~~~/ F~ ..~ v . ~ • To: Alaska Oil & Gas Conservation Commission From: Amanda Suddreth by CTD Engineer Date: June 14, 2010 Re: 05-16B Sundry Approval Sundry approval is requested for well 05-16B. 05-16B was originally drilled as a rig sidetrack in Nov 1999. The well was completed as a 4-1/2" liner, tied back into 4-1/2" tubing. The well targeted Z1A/B sands with 2000' of perforations. Additional perfs (40') were shot in Jan of `02, which increased oil production. More perfs (50') were added in July `03, but these only yielded an increase in gas production. In Aug `03, the well was shut in due to TxIA communication. A caliper log (run Sept 10, 2003) indicated that the tubing was in excellent condition. The GLMs were suspect to leaking, especially GLM #3, which had experienced multiple failures beginning Sept '02. All stations were dummied off, but 05-16B failed three MIT-IAs before a leak detect log was run in Sept'03 and confirmed the leak at GLM #3. In Oct `03, a 30' patch was set over GLM #3, but failed to completely cover the mandrel. It was removed in March '04 and the well was shut-in. In Jan `06, an improved patching procedure was attempted on GLM #3; during this operation, it was discovered that the valve in #3 was out of pocket. The dummy valve was reset, and the well passed the subsequent MIT-IA. 05-16B was POP'd in Apr `06, and there have been no further issues with TxIA communication. As gas production continued to climb, a cement squeeze, followed by an acid job, was performed in the upper perforations. While it shut off some of the gas producing zone, this job did not add to oil production. In Nov, `09 a hot job was performed, to remove paraffin from the well, and increase oil ~,. production, but the job was ineffective. Oil rate continued to drop off, and was replaced by water ~ N°~ ~, (based on separator flow analysis and ASRC testing). Finally, shake out samples were requested in a~ Jan `10, and indicated 100% water cut. 05-16B has been shut-in since, due to no oil production. - ~$o.t~ REASON FOR SIDETRACK 05-166 is no longer economic with such a high water cut. Non-rig solutions have been exhausted and ineffective. A sidetrack is required to adequately drain the fault block and replace production. a ~ _ /~~,~'- The proposed plan for 05-16C is to drill athrough-tubing sidetrack with the SLB/Nordic 2 Coiled u'`~'~ Tubing Drilling rig on or around July 25, 2010. The existing perforations will be isolated by a 4-1/2" monobore packer whipstock, as well as the primary cement job. The sidetrack, 05-16C, will exit the existing 4-1/2" liner and kick off in Zone 2, targeting 1200' of perforations in Z1A. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (scheduled to begin July 4, 2010) 1. S Caliper tubing from 11,330' (DONE 4/19/10) 2. F MIT-IA to 3000psi, MIT-OA to 2000 psi (DONE; PASS 4/19/10) 3. W PPOT-T, function LDS. PT tree (MV, SV, WV) 4. S Dummy WS drift to 10,600' MD (limited by deviation) - 5. C Mill XN nipple at 10,427' SLMD (10,445' MD) w/ LH mill 6. D Bleed wellhead pressures to zero. 7. O Remove wellhouse, level pad. 8. V Set BPV. //'' 6/~~ k ~~~ ~~~ /~ ~ C /, f t`7 c U,^/~l tj wC 11 rd clot; ~ /1 ~ Nr.~ / ~r' v ~ ~ivdlw~ d / ~'/~t p l~~(~~v L~r 4 J , ~f~w ~~~ ~ ~~ r ~~ o ~,n'7.'0, ~f i~t' i"~dl°~ ~, Rig Work: (scheduled to begin on July 25, 2010) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. RIH and set 4-1/2" monobore packer whipstock. with to C~ 3. Mill 3.8" window at 11,600' and 10' of rathole. Swap the well to Power-Vis. 4. Drill Build: 4.125" OH, 308' (35 deg/100 planned) 5. Drill Lateral: 4.125" OH, 1632' (12 deg/100 planned) with resistivity 6. Run 3-1/2" x 2-7/8" solid carbon liner leaving TOL at 11,100' 7. Pump primary cement leaving TOC at 11,100', 24 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNUGR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (1200') 11. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's 3. Pull BPV Amanda Suddreth CTD Engineer 564-5543 P£P ~~rD CC: Well File Sondra Stewman/Terrie Hubble _TREE=. .~ 4-1/16" FMC V~{ELLHEAD = FMC ACTiiATOR= BAKERC KB. ELEV = 65' BF. ELEV = 40.7' KOP = 3150' Max Angle = 94 @ 12278' Datum MD = Datum TVD = 8800' SS • S TES: WELL ANGLE> 70° @ 11280' *** IAx OMM. OPERATING PRESSURE OF THE 9-5/8" 8~ 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (11/19/02 WAVER)*** ***TxIA COMM. OPERATING LIMITS: MAX IAP = 2000 PSI, MAX OAP =1000 PSI (12/04/03 WAIVER)*** 2199' 4-1/2" HES X NIP, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2723' Minimum ID = 3.725" @ 10445' 4-1/2" HES XN NIP PERFORAl10N SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 83 @ 11700' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11700 - 11756 O 07/16/03 2-7/8" 4 11765 - 11790 O 01/29/02 2-7/8" 4 11780 - 11805 O 05/06/01 2-7/8" 4 11987 - 12165 O 11/19/99 2-7/8" 4 12225 - 12961 O 11/19/99 2-7/8" 4 13004 - 13650 O 11/19/99 2-7/8" 4 13702 - 13998 O 11/19/99 os-ass ~+ "' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3739 3709 26 MMG DOME RK 16 12/02/08 2 7826 6403 48 MMG SO RK 20 12/02/08 3 10318 8187 44 KBG-2L *DMY INT 0 01/03/06 " IXTENDm PACKING 8669' TOP OF BKR TIEBACK SLV 8675' 9-5/8" X 7" BKR ZXP PKR, ID = 6.313" 868$' 9-5/8" X 7" BKR HMC HGR, ID = 6.250" 9-5/8" CSG MILLOUT WINDOW 10039' - 10067' (OFF WS) 10428') 7" X 4-1 /2" HES TNT PKR, ID = 3.875" 10445' 4-1/2" HES XN NIP, ID = 3.725" 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 10480' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10456' 7" X 5" BKR ZXP PKR, ID = 4.375" 10457' 7" X 5" BKR HMC HGR, ID = 4.375" 1046 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10 10450' ~ BKR TIEBACK SLV 10458' 4-1/2" WLEG 14043' ~ FISH: MILLED CIBP (12/25/08) PBTD I~ 14050' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 14135' DATE REV BY COMMEMS DATE REV BY COMMENTS 10/02/77 ORIGINALCOMPLETION 01/16/06 KSB/PAG TTPPULLED(01/11/06) 03/07/87 RWO 12/03/08 RLM/PJC SET CIBP (11/13/08) 11/18/94 CTD SIDETRACK (05-16A) 12/12/08 GJF/SV GLV GO (12/02/08) 11/20/99 RIG SIDETRACK (05-18B) 01/12/09 RDB/SV MILLED CIBP (12/25/08) 12/26/03 ATD/TLH WAVER SAFETY NOTE 03/11/04 DAV/TLH PATCH PULLED/PLUG SET PRUDHOE BAY UNfI- WELL: 05-166 PERMIT No: 1991000 API No: 50-029-20262-02 SEC 32, T11 N, R15E, 3367' FSL & 38' FWL BP Exploration (Alaska) TREE=, ~~ 4-1/16" FMC WELLHEAD = FMC ACTi?ATOR= BAKERC KB. ELEV = 65' BF. ELEV = 40.7' KOP = 3150' Max Angle = 94 @ 12278' Datum MD = Datum TVD = 8800' SS • 05-16C Proposed CTD Sidetrack S TES: WELL ANGLE> 70° @ 11280' *** IAx OMM. OPERATING PRESSURE OF THE 9-5/8" 8~ 13-3/8" ANNULUS MUST NOT IXCEED 2000 PSI (11/19/02 WAIVER)*** ***TxIACOMM. OPERATING LIMITS: MAX IAP = 2000 PSI, MAX OAP =1000 PSI (12/04103 WAIVER)*** 4-1/2" HES X NIP, ID = 3.813" 13-318" CSG, 72#, L-80, ID = 12.347" ~~ 2723' Minimum ID = 2.30" @ 11100' TOL 3-1 /2" PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 83 @ 11700' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11700 - 11756 O 07/16/03 2-7/8" 4 11765 - 11790 O 01/29/02 2-7/8" 4 11780 - 11805 O 05/06/01 2-7/8" 4 11987 - 12165 O 11/19/99 2-7/8" 4 12225 - 12961 O 11/19/99 2-7/8" 4 13004 - 13650 O 11/19/99 2-7/8" 4 13702 - 13998 O 11/19/99 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3739 3709 26 MMG DOME RK 16 12/02/08 2 7826 6403 48 MMG SO RK 20 12/02/08 3 10318 8187 44 KBG-2L *DMY INT 0 01/03/06 * IXTENDED PACKING 8669' TOP OF BKR TIEBACK SLV 8675' 9-5/8" X 7" BKR ZXP PKR, ID = 6.313" 8683' 9-5/8" X 7" BKR HMC HGR, ID = 6.250" 9-5/8" CSG MILLOUT WINDOW 10039' - 10067' (OFF WS) 10428' ~ 7" X 4-1 J2" HES TNT PKR, ID = 3.875" 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-i 10480' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~' 7" X 5" BKR ZXP PKR, ID = 4.375" 7" X 5" BKR HMC HGR, ID = 4.375" - 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" C 3-1/2" X 2-7/8" liner ~ 13490' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 14135' 10445' I = 3'80" ,~., ,., . , .. , ........,.. 10450' BKR TIEBACK SLV A 10458' 4-1 /2" WLEG )456' 10457' TOL, roc 10464' ID = 2.30" 10615' 45° TSGR 10615' I~ 4-1/2" pkr w hip $2° 11550' -j3-1/2 x 2-7/8 Xo B DATE REV BY COMMENTS DATE REV BY COMMENTS 10/02/77 ORIGINALCOMPLETION 01/16/06 KSB/PAG TTPPULLED(01/11/06) 03/07/87 RWO 12/03/08 RLM/PJC SETCIBP(11/13/08) 11/18/94 CTD SIDETRACK (05-16A) 12/12/08 GJF/SV GLV GO (12/02!08) 11/20/99 RIG SIDETRACK (05-16B) 01/12/09 RDB/SV MILLED CIBP(12/25/08) 12/26/03 ATD/TLH WAVER SAFETY NOTE 04/28/10 MSE PROPOSED CTD SIDETRACK 03/11/04 DAV/TLH PATCH PULLED/PLUG SET PRUDHOE BAY UNff WELL: 05-16C PERMIT No: API No: 50-029-20262-03 SCE 32, T11 N, R15E, 3367' FSL & 38' FWL BP Exploration (Alaska) • Page 1 of 2 Roby, David S (DOA) From: Rebol, Amanda [reboa2@BP.com] Sent: Tuesday, June 29, 2010 4:50 PM To: Roby, David S (DOA) Subject: RE: 05-166 Sidetrack Explanation Dave My knowledge on this topic is second-hand, but it seems that the problems around the test separator are known at asenior-enough-to-make-things-happen level, and will likely be addressed once the re-org settles out. Thanks! -Amanda From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Tuesday, June 29, 2010 4:05 PM To: Rebol, Amanda Subject: RE: 05-16B Sidetrack Explanation Thanks Amanda, Any plans to repair/replace the DS05 test separator? Regards, Dave Roby (907)793-1232 From: Rebol, Amanda [mailto:reboa2@BP.com] Sent: Tuesday, June 29, 2010 4:01 PM To: Roby, David S (DOA) Subject: FW: 05-16B Sidetrack Explanation Dave- After some additional discussion, I've finally got the full story on 05-16B. -The test separator on DS05 has been plagued with problems, and is thereby an ineffective method of measuring water/oil cut on 05-166 -The ASRC test (using an individual well test separator) is an accurate means of measure, and indicated 0% watercut - 05-166 is producing oil, but at an much lower than competitive rate, and is shut in I realize that the Sundry submitted indicates a high water cut as the primary reason for shut-in and sidetrack, whereas the more accurate reason is an uneconomical oil rate with a higher rate expected post-sidetrack. I apologize for the Criss-crossed information; the conflicting tests on the well have been difficult to track since our recent re-org, since everyone who planned this well is now in a different position. Please feel free to call with any additional questions; if I need to revise and/or re-submit the Sundry, please let me know. Thank you! 6/30/2010 Page 2 of 2 -Amanda Amanda E Suddreth (Rebol) Drilling Engineer, Coil Tubing Drilling Alaska Drilling & Wells 907.564.5543 720.308.7188 From: Kaminski, Alice Sent: Tuesday, June 29, 2010 11:47 AM To: Rebol, Amanda Subject: 05-16B Sidetrack Explanation Hi Amanda, Water is not being produced from 05-16B. The DS 05 test separator has problems with the Micromotion meter. The Micromotion meter is measuring incorrect watercuts. Several attempts were made to update the densities being used in the meter to differentiate between oil and water, but all were unsuccessful. The portable ASRC test separator is testing the DS 05 wells periodically to measure accurate watercuts. The ASRC test separator measured 0% watercut for 05-166 on 12/31/09. 05-166 is being sidetracked because the well is not competitive, does not have any wellwork options remaining, and will access new reserves. Thanks, Alice Kaminski Petroleum Engineer GD New Well Delivery BP Exploration Alaska 907-564-5676 6/30/2010 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ~ MILL Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development 0 Exploratory ^ 199-1000 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20262-02-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028326 ~ PBU-05-16B 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14135 feet Plugs (measured) None feet true vertical 8794 feet Junk (measured) 14043' feet Effective Depth measured 14050 feet Packer (measured) 8675 10428 10457 true vertical 8795 feet (true vertical) 6955 8106 8129 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 94# H-40 26 - 106 26 - 106 1530 520 Surface 2694 13-3/8" 72# L-80 25 - 2719 25 - 2719 4930 2670 Intermediate Production 10015 9-5/8"47# L-80 24 - 10039 24 - 7815 6870 4760 Liner 1946 7" 26# L-80 8669 - 10615 6943 - 8250 7240 5410 Liner 3685 4-1/2" 12.6# L-80 10450 - 14135 8117 - 8795 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 22 - 10458 22 - 8129 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Packer 8675 6955 4-1/2" Howco TNT Packer 10428 8106 5" Baker ZXP Top Packer 10457 8129 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,., ;~~z ~~~ ~ _ ~ ~ ~u~ ~ R ~a~a . _ 1 ~~ Treatment descriptions including volumes used and final pressure: .~I~S~a Q'r ~,,,, ~ ~! z»a~e +~f:T~;.. ~(1ft11'CIISSIOR 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 154 5514 0 221 Subsequent to operation: 14. Attachments: ~ Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary re 2 Title Data Management Engineer Signature Phone 564-4944 Date 7/8/2010 ruins iu-•+vti r~yv wcu ~icuva ~K(~,/~ ~~ O ~ ~~~~ ~ q .~u~~im viiay~~ iuy 05-16B 199-100 PERF ~4TT~4CHMENT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 05-166 12/20/99 PER 11,987. 13,998. 8,803.34 8,808.75 05-16B 5/6/01 APF 11,780. 11,805. 8,790.72 8,793.47 05-16B 1/29/02 APF 11,765. 11,780. 8,789.04 8,790.72 05-16B 1129/02 RPF 11,780. 11,790. 8,790.72 8,791.88 05-16B 7/16/03 APF 11,710. 11,760. 8,782.99 8,788.5 05-168 11/13/08 BPS 11,900. 11,910. 8,796.85 8,797.17 05-16B 11/28/08 SQZ 9,250. 11,900. 7,323.6 8,796.85 05-16B 12/24/08 BPP 11,900. 11,910. 8,796.85 8,797.17 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 05-16B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/24/2010~CTU #9 w/ 1.75" CT: Job Scope: Mill XN Nipple /Drift for Whipstock: MIRU coiled tubing unit. MU and RIH with 3.80" diamond parabolic mill and left hand ~ motor. *"*Job Continued on 25 June 10"** 6/25/2010~CTU #9 w/ 1.75" CT: Job Scope: Mill XN Nipple /Drift for Whipstock: Continue i RIH with milling BHA. Mill through XN nipple at 10441' ctmd. Drift with 3.80" milling BHA to 11650'. Two tight spots observed at 10454' and 11466' ctmd. Milled through restrictions with very little motor work and continued to 11650' ctmd with no additional work or weight changes. Mill No-Go'ed 3.79" after I millin run. MU and RIH with 3.71" OD whipstock drift BHA. RIH and tagged several times at 10.464' ctmd, tried jetting WO success, POOH to inspect tools and found asphaltines packed on side and in connections. MU and RIH with 3" JSN on bottom of whipstock drift. Tag at same depth 10,464' ctmd. Pump 83 Bbls of diesel / xylene and continued to tag at same depth. No progess made. MU and RIH with 3.80" diamond parabolic mill and 3.76" string mill. Sit down at ~ 10462' ctmd. Mill and backream multiple passes from 10430' to 10470' until no motor work or weight changes observed. Dry drift to 11700' ctmd with no problems. PUH and make additional milling and backreaming passes across interval 10430' to 10470'. ***Job continued on 26 June 10*** _._.~d.. ...-. 6/26/2010: T/IA/OA= SI/100/400 Temp=S1 PPPOT-T (PASS) (Pre CTD) PPPOT-T : RU 2 HP BT onto THA 50 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 4800/ 15 minutes, 4750/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycle and torque LDS "Standard" all functioned with no problems. 6/26/2010~CTU #9 w/ 1.75" CT: Job Scope: Mill XN Nipple /Drift for Whipstock: Continued from 25 June 10. Continue milling and backreaming until no motor 'work or weight changes were observed. Made multiple milling and backreaming passes from 10430' to 10470' ctmd. Mill No-Go'ed 3.79" after mill run. MU and :'RIH with 3.71" OD whipstock drift BHA. Drift to 11650' ctmd with no problems. Freeze protect well from 2500' with 50/50 McOH. Perform weekly BOP test. RDMO. ***Job Complete*"* *"*Witnessed BOP Test*** FLUIDS PUMPED BBLS 90 MEOH 17 XYLENE 654 1 % XS KCL 66 diesel 827 Total TREE = 4-1116" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 65' BF. ELEV = 40.7' KOP = 3150' Max Angle = 94 @ 12278' Datum MD = Datum TVD = 8800' SS ~ 05-16B SA~F~EfY~ES: WELL ANGLE> 70° @ 11280' *** IAxOA COMM. OPERATING PRESSURE OFTHE 9-518" & 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (11119/02 WAIVER)*** ***TxIA COMM. OPERATING LIMITS: MAX IAP = 2000 PSI, MAX OAP =1000 PSI (12/04/03 WAIVER)*** 2199' 4-112" HES X NIP, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2723' Minimum ID = 3.725" @ 10445` 4-1 /2" HES XN NIP PERFORATION SUMMARY REF LOG: TCP PERF RNGLE AT TOP PERF: 83 @ 11700' Note: Refer to Production DB for historical pert data SIZE 5PF INTERVAL OpNSgz DATE 2-7J8" 4 11700 - 11756 O 07/16/03 2-7/8"' 4 11765 - 11790 O 01/29/02 2-718" 4 11780 - 11805 O 05/06/01 2-7/8" 4 11987 - 12165 O 11/19/99 2-7/8" 4 12225 - 12961 O 11/19!99 2-7i8" 4 13004 - 13650 O 11119!99 2-718" 4 13702 - 13998 O 11/19/99 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3739 3709 26 MMG DMY RK 0 44/19/10 2 7826 6403 48 MMG DMY RK 0 04!19/10 3 10318 $187 44 KBG-2L *DMY INT 0 01/03/06 GC 1 CNUtI.J YAI;KINCa 8669' TOP OF BKR TIEBACK SLV 8675' 9-518" X 7" BKR ZXP PKR, ID = 6.313" 8683' 9-5/8" X 7" BKR HMC HGR, ID = 6.250" 9-5/8" CSG MILLOUT WINDOW 10039' - 10067' (OFF WS) 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 10480' 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" -10456' 7" X 5" BKR ZXP PKR, ID = 4,375" 10457' ~-- 7" X 5" BKR HMC HGR, ID = 4.375 10464' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10615' 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I~ 14135' 10428• ~ 7" X 4-112" HES TNT PKR, ID - 3.875" 10445' 4-1/2" HES XN NIP, ID = 3.725" 10450' BKR TIEBACK SLV 10458' 4-112" WLEG 14043' FISH: MILLED CIBP (12!25!08} ~1 1-I~ 4tt50' ~ PRUDHOE BAY UNIT WELL: 05-16B PERMIT No: 1991000 API No: 50-029-20262-02 SEC 32, T11 N, R15E, 3367' FSL & 38' FWL BP F~cploration (Alaska) • • Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Monday, December 29, 2008 9:52 AM To: Maunder, Thomas E (DOA) Subject: Emailing: 05-166-OPS-REPORT-ATTACH-.PDF Attachments: 05-166-OPS-REPORT-ATTACH-.PDF ., j, ~ ~,. ~~~ 05-16B-OPS-REPOR T-ATTACH-.PDF ... This is the work summary for the BPS on 11/13/08 The message is ready to be sent with the following file or link attachments: 05-16B-OPS-REPORT-ATTACH-.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «05-16B-OPS-REPORT-ATTACH-.PDF» 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 29, 2008 9:23 AM To: Preble, Gary B (SAIC) Subject: RE: DS 05-166 (199-100) Hi Gary, Do you have any operations reports for the bridge plug installation? Tom From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Mon 12/29/2008 8:15 AM To: Maunder, Thomas E (DOA) Subject: RE: DS 05-16B (199-100) I have made the addition to my copies. I am not informed about future work scheduled on the wells. I will talk to the PE's to see if I can be kept in the loop. Thanks From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 23, 2008 4:40 PM To: Preble, Gary B (SAIC) Subject: DS 05-16B (199-100) Gary, I am reviewing the 404 for the recent squeeze work accomplished on this well. Your "pert detail" sheet shows some sort of bridge plug at 11900', however that item is not shown on the 404. I have made that addition. The detail sheet shows that plug to have been installed 11/13/08. I don't have any information on that operation. It would appear that the plug was set in conjunction with this squeeze. If so, then those operations should be included. I suppose there are plans to reperforate the well. I suspect you will send a 404 for those operations. An observation, for similar operations it is acceptable to combine all the operations in 1 404. I don't know how informed you might be kept with regard to the ultimate scope of a particular well's work, but this might save some paperwork. Best regards, Tom Maunder, PE AOGCC 1/27/2009 ~~~~' STATE OF ALASKA ` y I , ~ ALA~OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL~OPERATIONS v,e~!f~v'-, /oT•/d,Dl~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other CEM SQZE Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory ~ 1ss-looo- 3. Address: P.O. Box 196612 Stratigraphic r Service 6. API Number: Anchorage, AK 99519-6612 50-029-20262-02-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 65 KB PBU 05-166 8. Property Designation: 10. Field/Pool(s): , ADLO-028326 ' PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 14135 - feet Plugs (measured) None ~~~ ~~~~~ true vertical 8794.92 - feet Junk (measured) None hj3~ Effective Depth measured 14050 feet true vertical 8795 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 26 - 106 26 - 106 1530 520 Liner 1946 7" 26# L-80 8669 - 10615 6943 - 8250 7240 5410 Liner 3685 4-1/2" 12.6# L-80 10450 - 14135 8117 - 8795 8430 7500 Production 10015 9-5/8" 47# L-80 24 - 10039 24 - 7815 6870 4760 Surface 2694 13-3/8" 72# L-80 25 - 2719 25 - 2719 4930 2670 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# L-80 22 - 10458 0 0 - Packers and SSSV (type and measured depth) 7" Baker ZXP Packer 8675 4-1/2" Howco TNT Packer 10428 5" Baker ZXP Top Packer 10458 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory (~ Development ~', Service C` Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble ~ ~~, ,~pC,~ ~ [) l,r,~~e Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 12/8/2008 Form 10-404 ReJfsed 04/2006 ~.~' Submit Original Only ~~ 05-16B 199-100 PFRF OTTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 05-16B 12/20/99 PER 11,987. 13,998. 8,790.24 8,795.6 05-16B 5/6/01 APF 11,780. 11,805. 8,777.62 8,780.37 05-16B 1/29/02 APF 11,765. 11,780. 8,775.94 8,777.62 05-16B 1/29102 RPF 11,780. 11,790. 8,777.62 8,778.78 05-16B 7/16/03 APF 11,710. 11,760. 8,769.9 8,775.4 05-16B 11/13/08 BPS 11,900. 11,910. 8,783.75 8,784.07 05-16B 11/27/08 SQZ 9,250. 11,900. 7,315.1 8,783.75 AB ABANDONED PER PERF. APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE w • OS-16B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/13/2008T/I/A=0/260/440 Assist CTU Pump 100 bbls 50/50 dsl/xyl thru coil followed by 2 `bbls neat flush FWHP= 450/260/440 CTU on well and has control 11/13/2008 CTU #9 w/ 1.5" OD CT. Interact publFShing=yes. Jet perfs from 14040'-11600' w/ 100 bbls 50:50 diesel/xyiene. Flag CT @ 11800`. POOH. Saw weight bobble ~@ XN nipple @ 10445'. Run up/down dry 3 #imes. Jet across nipple. Re-check ;dry. Still have weight bobble. POOH. MU Baker 4.5" Composite Pluq Perform partial well kill to flush tubing. RiH with composite bridge plug. Correct depth at ;flag (based on TD tag from previous run} and set composite bridge plus at 11900' MD (mid-plug). Confirm infectivity into remaining pertorations after setting plug. Pull to surface. MU and RIH with 2.50" OD BDJSN. Found bad spots in pipe @ 39616-9597'. Had min wall @ 57% . POOH to repair pipe. Continued on 11/14/08 WSR. 11114/200$ Continued from 11/13/08 WSR. Freeze protect backside to 2000' w/ water/meth. :Blow down coil w! N2. RDMO to shop for pipe repair. ***Job is not complete"*'` FLUIDS PUMPED BBLS 200 50/50 diesel/xyl 200 Total 05-16B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ~ 11/27/2008 CTU #9 w/1.75" CT. Cement Squeeze. <InterACT publishing > MIRU CTU. MU [ 2.29" BDN. Kill well with hot 1%KCL, RIH and swap backside to diesel. a to ` of com osite lu for de th control and flag CT 10' above plug.. POOH and standby on crew change. RIH and retag top of plug. Begin pumping hot 1 KCI injecting into perforations. Reciprocate across perforations with 1 %KCI water *** Job continued on WSR 11/28/2008 **" ~ .......... 11/28/2008~CTU #9 w/1.75" CT. Cement Squeeze. ""* Job continued from WSR 11/27/2008 *** <InterACT publishing > Continue pumping 160* 1%KCI across pert interval. ;Pump 12 bbls of 12% HCI..lnjectivity prior to acid stimulation was 1 bpm at 960 LARC cement laying in from 10890'. Initial pressure 500 psi oreussre bump put 1 bbl of cement behind pipe, while laying in remaining cement in tubing, an additional 4 bbls went behind pipe for a total of 5 bbls. Ramp pressure to 2500 psi pressure across perfs and hold for 60 minutes. Last 33 minutes lost 120 psi. Lost 35psi in the last 12 min of the 1 hr at >2500psi. Clean out CMT down to plug (3 down and 3 up passes) and POOH at 80% washing jewelry. Freeze protect well from 2000' with 40 bbls of 60/40 meth. Final pressure test at 1000 . psi lost 90 psi in 10 minutes. Trap 500. psi on WHP. RDMO CTU. Final WHP i*** Job Complete *** _ _ _ FLUIDS PUMPED __ BBLS 268 1 %KCL 480 XS 1 %KCI 100 1.5PPB BIOZAN 39 FRESH WATER 105 60/40 METH 12 12% HCI 40 CLASS G LARC CEMENT 1044 TOTAL U)-1 bts It' 1 U tf 1 'j'j 1 UUU) L-lassmeo as rroolem well .~ K<t1 i?'12f~((Ya '-' Subject: 05-16B (PTD #1991000) Classified as Problem Well From: "NSU, ADW Wen Integrity EngineerH <NSUADWWeIHntegrityEngineer@BP.com> Date: Fri, 19 May 2006 15:56:41 -0800 . To: "Dean, JamesA"<James.Dean@BP.com>, "GPB, FS1/SIP/STPArea:MgrH <GPBFSITL@BP.com>,"Rossberg R Steven" <Steve~Rossberg@BP~c()m>, nNSU, ADW Well Operations Supervisor" <NSUADWWellOperatiorisSupervisor@BP.com>, "GPB,Wel1s Opt Eng" <GPBWellsOptEng@BP . com>, "AOGCC Jim Regg (E-mail)..<jim._regg@admin.state.ak.us>. uA~C-ÇWll):tori Aubert (E-maiI)..<winton_aubert@admin~state.ak.us>..."NSU~ADWWL & , Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, '!GPB, FSIDS Ops ' ' Le, ad"<GPB~S IDSOpsLead@BP.com>, "GPB,EOC, Specia1ists'~ <GPBEOCSpec, ialists@BP.com> - . - ,. . ," - - - -- , , ,.. ' ÇC: tI~SU, AD.W,WeU:Integrity'Engineer" <NSUADWWel1IntegrityEngineer@BP~com>, "Winslow, Jack L." <LyonsW@BP~corn> . , " i. -c2K- All, Well 05-168 (PTD #1991000) has been found to have sustained casing pressure on the IA. The TIO pressures were 2420/2420/600 on 05/18/06 before a TIFL was conducted and subsequently failed. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Set dummy GL Vs 3. DHD: Re-TIFL SCANNED JUN 2 7 2006 A wellbore schematic has been included for reference. «05-16B.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you I jlnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 05-16B.pdf 05-16B.pdf Content-Type: application/octet-stream Content-Encoding: base64 ~ ,\..ty~P (.,) U7Æ.:D to J ~ 1i J-4.- òA zAzlp;.~ bOOr'· ~ß7Cf5; 5"~&r>ì 3~¿~ It .&'lö ò IL Pi¿r- Co 4-cl L- 1 of 1 5/22/2006 3 :52 PM TREE = 4-1116" FMC WELLHEAD = FMC _ ·~..._~_.m__'_··· _. " .. . .."..~~. . ACTUATOR = BAKERC .....m_.«~...__....~"'.. .."~",,.. KB. ELEV = 65' .~.'~h_"~r_"m~" . .,._-,.., SF. B..EV = 40.7' ~-->.~. KOP = 3150' ~_._.h.....~_.. ."'.'_~' . ....._~ .. _.. ....... _ Max Angle = 94 @ 12278' ~''''~_'..n^~_.'~' n, _ ."._._~_..~~..~ . _..." Datum MD = ~Õãtüm nrõ-;--šŠ-õõ' ss' '~ 05-168 I ~ 113-318" CSG, 72#, L-80, ID = 12.347" l-i 2723' ~ Minimum ID = 3.725" @ 10445' 4-1/2" HES XN NIP l l ~ J I ~ ÆRFORA TION SUMrv1ARY REF LOG: TCP ÆRF ANGLEATTOPÆRF: 83 @ 11700' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L OpnlSqz OA TE 2-718" 4 11700-11756 0 07116/03 2-718" 4 11765-11790 0 01/29/02 2-718" 4 11780 - 11805 0 05/06/01 2-718" 4 11987 - 12165 0 11/19/99 2-718" 4 12225 - 12961 0 11119/99 2-718" 4 13004 - 13650 0 11/19/99 2-718" 4 13702 - 13998 0 11/19/99 I .. I 9-518" CSG, 47#, L-80, 10 = 8.681" l-i 10480' 14-112" TBG, 12.6#, L-80, .0152 bpf, ID::: 3.958" 1-1 10456' 1 17" X 5>1 BKR ZXP A<R, 10 = 4.375" 1-1 10457' 17" X 5" BKR HMC HGR, to = 4.375" I-{ 10464' 17" LNR. 26#, L-80, .0383 bpf, ID = 6.2768 l-i 10615' SAFt.-rY NOTES: WELL ANGLE> 70° @ 11280' *** IAxOA COMM. OPERATING PRESSURE OF THE 9-5/8" & 13-3J8" ANNULUS MUST NOT EXCEED 2000 PSI (11/19102 W AlVER)*** ***TxIA COMM. OPERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 1000 PSI (12/04/03 W AlVER}*** 2199' 1-14-1/2" HES X NIP, 10:: 3.813" 1 ~ GAS LIFT rv1ANDRELS ST MD NO DEV TYÆ VLV LATCH 1 3739 3708 24 MMG DOME RK 2 7826 6416 52 Mrv1G SO RK 3 10318 8013 39 KBG-2L [)fI..ifY INT PORT DATE 16 03/12/06 20 03/12/06, o :01/03/06 8669' l-i TOP OF BKR TIEBACK SL V 1 8675' 1-i9-5/8" X 7" BKR ZXP PKR, to ::: 6.313" 8683' 1-i9-518" X 7" BKR HMC HGR, ID = 6.250" 1 9-5/8" CSG MILL OUT WINDOW 10039' - 10067' (OFF WS) 10428' 1- 7" X 4-1/2" HES TNT A<R. , 10 = 3.875" 10445'1-i4-1/2" HES XN NIP. 10 = 3.725"1 10450' l-i BKR TIEBACK SL V I 10458' 1-i4-1I2" WLEG I 14050' 1 f4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" l-r 14135' 1 DATE 10/02177 03107/87 11/18194 11/20/99 12/26í03 03/11/04 REV BY COMMENTS ORIGINAL COM PLETION RWO CTD SIDETRACK (05-16A) CTD SIDETRACK ( 05-168) ATDITLH WAIVER SAFETY NOTE DA V /TLH PATCH PULLED/Ft.UG SET DA TE REV BY COMMENTS 01/16/06 KSB/PAG TIP PULLED (01/11/06) 03/12/06 KSBfTLH GL V CiO 05/18/06 JLW/TLH GLV CORRECTION PRUDHOE BAY UNIT WELL: 05-16B ÆRf\,1IT No: '1991000 API No: 50-029-20262-02 SEe 32, T11 N, R15E, 3367' FSL & 38' FWL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend 0 RepairWeliD Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate D Time ExtensionO Re-enter Suspended Well 0 Other[!] Pull Patch Name: BP Exploration (Alaska), Inc. 5. Permit to Drill Number: 199-1000 65.00 8. Property Designation: ADL-O028326 11. Present Well Condition Summary: Development ŒJ Stratigraphic 0 9. Well Name and Number: 05-16B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceD 6. API Number 50-029-20262-02-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519.6612 7. KB Elevation (ft): Total Depth measured 14135 feet true vertical 8794.9 feet Effective Depth measured 14050 feet true vertical 8795.1 feet Plugs (measured) Junk (measured) 10436 None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 26 106 26.0 - 106.0 1530 520 Liner 1946 7" 26# L-80 8669 . 10615 6942.7 - 8249.7 7240 5410 Liner 3685 4-1/2" 12.6# L-80 10450 - 14135 8117.1 - 8794.9 8430 7500 Production 10015 9-5/8" 47# L-80 24 - 10039 24.0 - 7814.6 6870 4760 Surface 2694 13-3/8" 72# L-80 25 - 2719 25.0 - 2718.9 4930 2670 Perforation deoth: Measured depth: 11710 -11760,11765 -11780,11780 -11790,11790 -11805,11987 -13998 True vertical depth: 8769.9 - 8775.4,8775.94 - 8777.62, 8777.62 - 8778.78, 8778.78 - 8780.37, 8790.24.8795.6 ,r::O r::'Cf=\\ ',- Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 22 - 10458 R\;.. "," Packers & SSSV (type & measured depth): 4-1/2" Howco TNT Packer @ 10428 ~\' \~ - ß 1~\)4 . ¡\On 5" Baker ZXP Liner Top Packer @ 10457 . W~' 'uù'{(\tt\\$ 7" Baker ZXP Packer @ 8675 0\\ ð. û3S \,sO ~",\. ~n~\\Ot¡~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oll-Bbl 1027 Reoresentative Daily Average Production or Injection Data Gas-Met I Water-Bbl Casing Pressure 31.1 0 1700 13 Well Shut-In 1700 Tubing Pressure 348 884 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentOO ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilŒJ GasD WAG 0 GINJD WINJD WDSPLD' Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ß{r;¡-;tT~ Form 10-404 Revised 12/2003 Title Production Technical Assistant Signature Phone 564-4657 Date 4/5/04 OR , G I ~\.I.A L ~f~i~m~~ ~h-- ~7 IOu4! 05-168 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/09/04 ***WELL SHUT IN ON ARRIVAL*** PULLED UPPER ECLIPSE PKR & PATCH @ 10265' SLM. PULLED LOWER PKR @ 10298' SLM. MISSING ELEMENT. MADE SEVERAL ATTEMPTS W/ 3.625" CENT / WIRE GRAB TO FISH RUBBER. UNSUCCESSFUL. RIH W/ 4-1/2" PXN PLUG BODY. 03/10/04 SET 4112 PXN PLUG @ 10414' SLM RAN CHECK SET SET P-PRONG W/1 3/4" FN 96" OAL WI CENT JUST BELOW FN. TESTED PLUG - GOOD TEST **LEAVE WELL SI- TTP IN THE HOLE** FLUIDS PUMPED BBLS No Fluids Pumped 0 I TOTAL Page 1 '. þ TREE = 4-1/16" FMC WEi.LHEAD = FMC AcrU<\ TOR = BAKER C KB. ELEV = 65' BF. ELEV = 40.7' KOP = 3150' Max Angle = 94 @ 12278' DatumMD= DatumTVD = 8800' SS 113-3/8" CSG. 72#, L-80, ID = 12.347" H 2723' Minimum ID = 2.250" @ 10302' 4-1/2" EC LlPSE PATCH ÆRFORA llON SlJv1MA. RY REF LOG: TCP PERF ANGLEATTOPPERF:83@ 11700' Note: Refer to Production œ for historieal perf data SIZE SFF INTERVAL OpnlSqz DATE 2-718" 4 11700-11756 0 07/16/03 2-718" 4 11765 - 11790 0 01/29/02 2-718" 4 11780-11805 0 05/06/01 2-718" 411987-12165 0 11/19/99 2-718" 4 12225 -12961 0 11/19/99 2-718" 4 13004 -13650 0 11/19/99 2-718" 4 13702 - 13998 0 11/19/99 05-168 I ~ ~ ~ SAFE1YNOTES: WELL ANGLE> 70o@ 11280' *** IAxOACOMM. OPERATING PRESSURE OF THE 9-5/8" & 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI(11/19/02WAIVER)*** ***TxIACOMM. OPERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 1 000 PSI (12/04/03 WAIVER)*** 2199' H4-1/2" I-ES X NP, ID = 3.813" I GAS LIFT MANDRELS ST Iv1D TVD DEV TYPE V LV LA TCH PORT D<\ TE ~L 1 3739 3708 24 MWiG DMY RK 01/27¡Q4 2 7826 6416 52 MWiG DMY RK 01/27¡Q4 - 3 103188013 39 KBG-2L **DMY INT 08l01¡Q3 **ST A TION # 3 = DMY HAS EXTEtÐED PACKING L ¡ ¡-----I ~ 8669' 8675' 8683' HTOPOFBKRTIEBAO<SLV I H9-5I8"X 7" BKRZXPPKR, ID=6.313" I H 9-518" X 7" BKR I-fv1C HGR, ID = 6.250" I I 9-518" CSG MLLOUTWIf\DOW 10039' -10067' (OFFWS) 19-518" CSG, 47#, L-80, ID = 8.681" H 10480' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10456' I I7"X 5' BKRZXPPKR, ID=4.375" H 1045T 17" X 5" BKR HWC H3R, ID = 4.375' H 10464' 17" Lf\R, 26#, L-80, .0383 bpf, ID = 6276" H 10615' 14050' I 14-1/2"Lt-R,12.6#,L-80,.0152bpf,ID=3.958" H 14135' D<\ TE 10102n7 03107/87 11/18/94 11/20/99 01/09¡Q2 01/29m 07l16¡Q3 COMMENTS ORIGINAL COMPLETION RWO CTD SIDETRACK ( O5-16A) CTD SIDETRACK ( 05-168) CI-VKAK CORRECllONS AlD/KK AIFERFS JGM/KK A IFERFS RBI BY DATE REV BY COMM:NTS 10/20/03 BWcN'TLI- SET ECLPSEPATCH 11/25103 .l.JffiH (!LV C/O 12/26/03 ATD/TLH WAIVER SAFETY NOTE 01/27/04 JLJffiP GLV C/O 03/11/04 D<\ V /TLH PA Ta-I RJLLEDiPLlX3 SET PRLDHOEBAY lJII[f WELL: 05-16B PERMr f\b: 1991000 API f\b: 50-029-20262-02 SEC 32, T11 N, R15E, 3367' FSL & 38' FWL BP Exploration (Alaska) -, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend 0 Repair WellŒ] Pull TubingD Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 199-1000 OtherD Name: BP Exploration (Alaska), Inc. 65.00 8. Property Designation: ADL-0028326 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: 05-16B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D 6. API Number 50-029-20262-02-00 Development ŒJ 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 14135 feet Plugs (measured) Junk (measured) None true vertical 8794.9 feet Effective Depth measured 14050 feet true vertical 8795.1 feet None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 26 106 26.0 106.0 1530 520 Liner 1946 7" 26# L-80 8669 - 10615 6942.7 - 8249.7 7240 5410 Liner 3685 4-1/2" 12.6# L-80 10450 - 14135 8117.1 - 8794.9 8430 7500 Production 10015 9-5/8" 47# L-80 24 - 10039 24.0 7814.6 6870 4760 Surface 2694 13-3/8" 72# L-80 25 - 2719 25.0 2718.9 4930 2670 Perforation deDth: Measured depth: 11710 - 11760, 11765 - 11780, 11780 - 11790, 11790 - 11805, 11987 - 13998 True vertical depth: 8769.9 - 8775.4,8775.94 - 8777.62,8777.62 - 8778.78,8778.78 - 8780.37,8790.24 - 8795.6 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 2-7/8" 6.5# L-80 4-1/2" Eclipse Patch Packer 4-1/2" Eclipse Patch Packer 4-1/2" Howco TNT Packer 5" Baker ZXP Liner Top Packer 7" Baker ZXP Packer @ 22 @ 10306 10458 10332 @ 10302 @ 10332 @ 10428 : 1~~ka 0i18¡ Gas Cons" Cumrt¡¡ssion RECEIVE[) FEB 2 4 2004 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 317 7.4 0 150 222 317 7.3 0 150 344 Reoresentative Dailv Averaae Production or Iniection Data 13 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒJ Service 0 Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown 0 OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garr Catron C '\"'11:, ',i!\\!\I!E:.r n~A~ Title Production Technical Assistant Signature 2/18/04 Form 1 0-404 Revised 12/2003 05-16B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/20/03 CORRELATED TO SWS LDL RAN 9/10/03. RUN #1: 3.74" X 251, LOWER PACKER ELEMENT SET AT 103321. GOOD INDICATION, SET BACK DOWN ON PACKER. RUN #2: 3.741 X 431, STABBED INTO LOWER PACKER WITH UPPER PACKER/PATCH ON 4TH TRY. SET UPPER PACKER ELEMENT SET AT 103021. GOOD INDICATION. POOH. PATCH SET OVER GLM #3 AT 103181. DID NOT TAG TO. JOB IS COMPLETE. LEAVE WELL *SHUT IN* FLUIDS PUMPED S:LS :TOT AL No Fluids Pumped Page 1 TREE = 4-1/16" FMC W8..LHEAO = FMC A cn..LA. TOR = BAKER C KB. ELEV = 65' BF. ELEV = 40.7' KOP= 3150' Max Angle = 94 @ 12278' Datum MO = Datum TVO - 8800' SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" Minimu m ID = 2.250" @ 10302' 4-1/2" ECLIPSE PATCH ÆRFORA llON Sllv1MA RY REF LOG: TCP PERF ANGLE AT TOP PERF: 83 @ 11700' Note: Refer to Produetion œ for historieal perf data SIZE SFF INTERV A L Opn/Sqz DATE 2-718" 4 11700 - 11756 0 07/16/03 2-718" 4 11765 - 11790 0 01/29/02 2-718" 4 11780 - 11805 0 05/06/01 2-718" 4 11987 - 12165 0 11/19/99 2-718" 4 12225 - 12961 0 11/19/99 2-718" 4 13004 - 13650 0 11/19/99 2- 718" 4 13702 - 13998 0 11/19/99 05-168 SAÆTY NOTES: WELL ANGLE> 70° @ 11280' *** IAxOACOMM. OPERATING PRESSURE OF THE 9-5/8" & 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (11/19/02 WAIVER)*** ***TxIA COMM. OPERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 1000 PSI (12/04/03 WAIVER)*** 4-1/2" HES X NIP, 10 = 3.813" GAS LIFT MANDRELS ST MO TVO OEV TYPE VLV LATCH 1 3739 3708 24 MMG OMY RK 2 7826 6416 52 MMG OMY RK 3 10318 8013 39 KBG-2L ""OMY INT **STATION # 3 = DMY HAS EXTENJED PACKING PORT DA. TE 01/27104 01/27104 08101103 -I TOP OF BKRTIEBA0< SLV I -19-5/8" X 7" BKRZXPPKR, 10=6.313" I -19-518" X 7" BKR HMC HGR, 10 = 6.250" I 9-5/8" CSG MLLOUTWINOOW 10039' -10067' (OFFWS) 9-5/8" CSG, 47#, L-80, 10 = 8.681" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" ( 7"X 5" BKRZXPPKR, 10=4.375" I 7' X 5" BKR HMC HGR, 10 = 4.375" (7' LNR, 26#, L-80, .0383 bpf, 10 = 6.276" ( 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" DA.TE RBI BY COMMENTS DATE REV BY COMMENTS 10/02n7 ORIGINAL COM PLErION 08/02103 rvI-I/1L H GL V C/O 03107/87 RWO 10/04/03 DA.OTLP GLM STA #3 - EXT PAO<ING 11/18194 CTD SIDErRACK J 05-16A) 10/20/03 B Me N'TU- SET ECLlPSEPATQ-I 11/20199 CTD SlDErRACK ( 05-166) 11/25/03 JLJ/1LH GL V C/O 01/09102 CI-VKAK CORRECllONS 12/26/03 ATOrrLH WA IVER SAFETY NOTE 01/29102 A lD/KK A [PERFS 01/27/04 JLJrrLP GL V C/O 11/19102 J RC/KK W AIV ER SA FETY NOTE 07/16103 JGM/KK A [PERFS PRUDHOE BAY UNIT WELL: 05-16B PERMT No: 1991000 API No: 50-029-20262-02 SEC 32. T11 N, R15E, 3367' FSL & 38' FWL 6P Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS . .. , . 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator (' (~ Suspend D Repair WellŒJ Pull Tubing D Packers & SSSV (type & measured depth): Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: OtherD Perforate D WaiverD Stimulate D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 199-1000 Name: BP Exploration (Alaska), Inc. Development [K) Stratigraphic D 9. Well Name and Number: 05-16B 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool ExploratoryD Service D 6. API Number 50-029-20262-02-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 65.00 8. Property Designation: ADL-0028326 11. Present Well Condition Summary: Total Depth measured 14135 true vertical 8794.9 feet None feet Plugs (measured) Junk (measured) None Effective Depth measured 14050 feet true vertical 8795.1 feet Casing Conductor Liner Liner Production Surface Perforation depth: Measured depth: 11710 - 11760, 11765 - 11780, 11780 - 11790, 11790 - 11805, 11987 - 13998 True vertical depth: 8769.9 - 8775.4,8775.94 - 8777.62,8777.62 - 8778.78,8778.78 - 8780.37,8790.24 - 8795.6 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 37 - 10820 2-7/8" 6.5# L-80 @ 10306 - 10332 7" Baker ZXP Packer 4-1/2" Eclipse Patch Packer 4-1/2" Eclipse Patch Packer 4-1/2" HES RCP Packer 5" Baker ZXP Liner Top Packer Length 116 1946 3685 10015 2699 Size 20" 94# H-40 7" 26# L-80 4-1/2" 12.6# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 TVD 24.0 - 140.0 6942.7 - 8249.7 8117.1 - 8794.9 24.0 - 7814.6 24.0 - 2722.9 MD 24 - 140 8669 - 10615 10450 - 14135 24 - 10039 24 - 2723 Burst Collapse 520 5410 7500 4760 2670 1530 7240 8430 6870 4930 @ 8675 @ 10302 @ 10332 @ 10428 @ 10457 RECEIVED . JAN 2 0 2004 Alaska Oil & Gas Cons. Commission Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Prior to well operation: Subsequent to operation: Oil-Bbl I Gas-Mef I Water-Bbl Casing Pressure I Tubing Pressure 317 I 7.416 I 0 300 I 222 WELL IS CURRENTLY SHUT-IN 14. Attachments: Copies of Logs and Surveys run- Signatur Form 1 0-404 Revised 12/2003 15. Well Class after proposed work: Exploratory D Development IX! Service D 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by Sharmaine (907) 564-4424. Sundry Number or NIA if C.O. Exempt: Title Technical Assistant Phone 564-4424 Date 1/15/04 II :.r)I'...t 'iI'II!8. ¡\1:-::>.~ .J~ ~111'(-:- ..., ¡ . ( ( 05-168 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/20/03 CORRELATED TO SWS LDL RAN 9/10/03. RUN #1: 3.74" X 25" LOWER PACKER ELEMENT SET AT 103321. GOOD INDICATION, SET BACK DOWN ON PACKER. RUN #2: 3.741 X 431, STABBED INTO LOWER PACKER WITH UPPER PACKER/PATCH ON 4TH TRY. SET UPPER PACKER ELEMENT SET AT 103021. GOOD INDICATION. POOH. PATCH SET OVER GLM #3 AT 103181. DID NOT TAG TO. JOB IS COMPLETE. LEAVE WELL *SHUT IN* FLUIDS PUMPED BBLS 0 TOTAL Page 1 (" TREE = 4-1/16" FMC W8.LHEAD = FMC ACTUATOR = BAKER C KB. 8.EV = 65' BF. 8.EV = 40.7' KOP= 3150' rv1ax Angle = 94 @ 12278' Datum MD = Datum N D = 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.250" @ 10302' 4-1/2" ECLIPSE PATCH PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 83 @ 11700' Note: Refer to Produetion DB for historieal perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11700 - 11756 0 07/16/03 2-7/8" 4 11765 - 11790 0 01/29/02 2-7/8" 4 11780 - 11805 0 05/06/01 2-7/8" 4 11987 - 12165 0 11/19/99 2-7/8" 4 12225 - 12961 0 11/19/99 2-7/8" 4 13004 - 13650 0 11/19/99 2-7/8" 4 13702 - 13998 0 11/19/99 05-168 SAFETY NOTES: WELL ANGLE > 700@ 11280' *** IAxOACOMM. OPERATINGPRESSUREOFTHE9- 5/8" & 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (11/19/02 W AlVER)*** ***TxIA COMM. OPERATING LlMITES: MAX lAP = 2000 PSI, MAX OAP = 1000 PSI (12/04/03 W AlVER)*** -14-112" HES X NIP, ID = 3.813" I GAS LIFT MANDR8.S ST MD ND DEV TYÆ VLV LATCH 1 3739 3708 24 MMG DOME RK 2 7826 6416 52 MMG SO RK 3 10318 8013 39 KBG-2L **DMY INT **STATION # 3 = DMY HAS EXTENDED PACKING PORT DA TE 16 11/03/03 20 11/03/03 0 08/01/03 -1 TOP OF BKR TIEBACK SL V I -19-5/8" X 7" BKRZXPPKR,ID= 6.313" I -19-5/8" X 7" BKR HMC HGR, ID = 6.250" I 9-5/8" CSG MILLOUT WIN DOW 10039' - 10067' (OFF WHIPSTOCK) 7" X 4-1/2" HES TNT PKR, ID = 3.875" 19-5/8" CSG, 47#, L-80, ID = 8.681" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 17" X 5" BKR ZXP PKR, ID = 4.375" I 17" X 5" BKR HMC HGR, ID = 4.375" I 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 14050' 1 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I DATE REV BY COMMENTS DATE REV BY COMMENTS 10/02n7 ORIGINAL COM PLETION 07/16/03 JGMlKK ADÆRFS 03/07/87 RWO 08/02/03 MHITLH GL V C/O 11/18/94 CTD SIDETRACK ( 05.16A ) 10/04/03 DA CITLP GLM STA #3 - EXT PACKING 11/20/99 CTD SIDETRACK ( 05-16B ) 10/20/03 BJMeNITLH SET ECLIPSE PA TCH 01/09/02 CH/KAK CORRECTIONS 11/25/03 JLJITLH GL V C/O 01/29/02 A TD/KK A DPERFS 12/26/03 A TD/TLH WA rv ER SAFETY NOTE 11/19/02 JRClKK WA IV ER SA FETY NOTE PRUDHOE SA Y UNIT WELL: 05-16B ÆRMIT No: 1991000 API No: 50-029-20262-02 SEC 32, T11 N, R15E, 3367' FSL & 38' FWL BP Exploration (Alaska) ( STATE OF ALASKA (' ;. ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 SuspendD Operation ShutdownD Perforate Œ] WaiverD OtherD Alter CasingD Repair WellD Plug PerforationsO Stimulate D Time Extension 0 Change Approved ProgramD Pull TubingD Perforate New PoolO Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 199-1000 Development IX] ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20262-02-00 7. KB Elevation (ft): 9. Well Name and Number: 65.00 05-16B 8. Property Designation: 10. Field/Pool(s): ADL-0028326 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 14135 feet true vertical 8794.9 feet Plugs (measured) None Effective Depth measured 14050 feet Junk (measured) None true vertical 8795.1 feet Casing Length Size MD TVD Burst Collapse Conductor 116 20" 94# H-40 24 - 140 24.0 - 140.0 1530 520 Liner 1946 7" 26# L-80 8669 - 10615 6942.7 - 8249.7 7240 5410 Liner 3685 4-1/2" 12.6# L-80 10450 - 14135 8117.1 - 8794.9 8430 7500 Production 10015 9-5/8" 47# L-80 24 - 10039 24.0 - 7814.6 6870 4760 Surface 2699 13-3/8" 72# L-80 24 - 2723 24.0 - 2722.9 4930 2670 Perforation deDth: Measured depth: 11710 - 11760, 11765 - 11780, 11780 - 11790, 11790 - 11805, 11987 - 13998 True vertical depth: 8769.9 - 8775.4,8775.94 - 8777.62,8777.62 - 8778.78,8778.78 - 8780.37,8790.24 - 8795.6 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 37 - 10820 RECEIVED Packers & SSSV (type & measured depth): 7" Baker ZXP Packer @ 8675 4-1/2" HES RCP Packer @ 10428 JAN 2 0 2004 5" Baker ZXP Liner Top Packer @ 10457 12. Stimulation or cement squeeze summary: Alaska Oil & Gas Cons. CommiSSion Intervals treated (measured): Anchorage Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 335 7.571 0 1280 207 Subsequent to operation: 262 6.633 0 650 306 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development~ Service D Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D Oil IX) GasD WAG D GINJD WINJD WDSPLD Daily Report of Well Operations -...x Prepared by Sharmaine (907) 564-4424. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sharmaine Copeland Sharmaine Copeland Title Technical Assistant Signatu Phone 564-4424 Date 1/15/04 ~-,,,"r;-- /,', ""."~"""'" R fìI [ì¡,D 11j) llj)OO~ 0 0 I G I N A l'. ,,' "D¡;'~1 fA", 21 81 Form 10-404 R~~rsD("iÙÚ2b'03)1 ~»t~u\~ 11::9 ¿I ,Ct ~ I . '. RØ)YS p- II. IJVI ( ~ . ( 05-16B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/15/03 Continued from WSR of 7/15/03. On line with hot dead crude. RIH to 11800 jetting tubing and liner with dead crude. No problems. RIH with GR/CCL Log down from 1105011 to 11810. at 60 fpm log up from 11810' to 11050' at 60 fpm. POH. Verify data. Data 07/16/03 11710'-11760' 4 SPF FLUIDS PUMPED BBLS 299 CRUDE 47 DIESEL 312 1% KCL 658 TOTAL Page 1 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 11/11/03 NO. 3O28 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD P1-02A d'~ '('~') (~-') 10672311 RST-SIGMA 09/14/03 D.S. 5-02~ ~ ~L~ 10658550 MCNL 06/10/03 D.S. 6-16~.'~ -_~ ~ 10668555 MCNL 06/16103 E-14A ( ~ ~1 ~.~ 10560299 RST-SIGMA 09/42/03 P~-OS 1~ ~ '- k-~ ~os743s~ .ST-S~A ~0/04/03 P~-O~ ~ ~-I~ ~oss03~ .ST-S,~M~ ~o~s~03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. R CEiVED Anchorage, Al~.s, ka 99508 Date Delivered: NOV 24 200~ Gas (;ons. (x)mmieeion Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth . 09/30/03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2981 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S. 5-16B I ~ C~ --[ ~ LDL 09/10/03 P2.60.~<~:~ ~'-~"-~, ~q~_~\ PROD PROFILE WIDEFT 09113/03 H.26 ' PROD PROFILE 09117103 E-21A ~i~'~ ~1 _c[ ~<~ SBHP SURVEY 09/16/03 NK-29I'C~i ~ ~ ~ ~( ~ PROD PROFILE W/DEFT 09~09~03 D.S. 3-29 '~ ~ ~ ~ ~.)~C~ PROD PROFILE W/DEFT 09119103 D.S. 15-18 ~ C~'~--O('O(~ SBHP SURVEY 09/19/03 U-08A I ~'~- c-~-~ . .SBHP SURVEY 09/20103 W-24.,, t ~ '"("'~ .-~) / LDL 09/23/03 D.S. 9-06. ~'~/~(~L~ ~_~ PROD PROFILE W/DEFT 09/20/03 D.S. 2-08B '~(:~ -~c~ 23375 CH EDIT MCNL 05/31103 ~N-23A~.. ' ' ~-- 23373 OH EDIT LWD IMPULSE DATA - 04/30/03 W-23A ~,j~(~'~~ ('fP 23373 MD VISION RESISTIVITY 04/30/03 W-23A ~ -- 23373 TVD VISION RESISTIVITY 04/30/03 ,W-23A// 23373 MD BOREHOLE PROFILE 04/30/03 MPS-02~ ~/~--~...1~-~/- 10624537 CH EDIT SCMT GR (PDC) 08/09/03 MPS-02//'~:::~-~/ /~/- ~ 23435 SCMT 08~09~03 MPS-18~ ~/.~--~.~ _~') 10559235 CH EDIT SCMT GR (PDC) ' 03/03103 MPS-18//C~L--~ c.~ ~.~, 10559235 SCMT 03~03~03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth PBU 05-'16B Class A Well Return to production Subject: Date: From: To: CC: PBU 0fi-16B Class A Well Return to production Sun, 1 Dec 2002 17:55:51 -0600 "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegfityEngineer@BP.com> "AOGCC Tom Maunder (E-mail)" <Tom_Maunder~admin.state.ak.us>, "AOGCC Bob Fleckenstein (E-maiD" <Bob_Fleckenstein~admin.state.ak.us>, "- Jim Regg AOGCC (E-mail)" <Jim_Regg@admin.state.ak.us>, "- Winton Aubert (E-mail)' 'AOGCC (E-mail)" <Winton_Aubert~admin.state.ak.us> "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor~BP.com>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegdtyEngineer~BP.com>, "Rossberg, R Steven" <RossbeRS~BP.com> Gentlemen, PBU well 05-16B (Class A) was returned to production on 11/30/02. Please find the attached test records that demonstrate the two competent barriers required to produce this well. Please call if you have any questions. Thanks, Preston Evans Well Integrity Engineer 659-5102 Name: 05-16B.pdf 05-16B.pdf Type: Acrobat (application/pdf) Encoding: base64 Well 05-16 PPPOT 11-24-02.xls Name: BP Well 05-16 PPPOT 11-24-02.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 J.05-16B MIT-OA 09-20-02.xls 6B MIT-OA 09-20-02.xls It Name:Type: Microsoft05-1 Excel Worksheet (application/vnd.ms-excel)' Encoding: base64 I~.05-16B TIFL 11-17-02.xls Name: 05-16B TIFL 11-17-02.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 1 of 1 12/4/2002 11:20 AM TR~E= 4.-1116" FM( WELLHEAD = FMC ACTUATOR = BAKB:{ KB. ELE'V = 65' BF. EI..EV = 40.7' KOP= 3150' Max Angle = 94@ 12278' Datum MD = Datum TVD = 8800' SE 05-16B SAFETY NOTES: W B,L ANGLE > 70 DEG @ 11280' & · 90 DEG @ 12180'. *** lAX OA COMM. OPERATING PRESSURE OFTHE 9-5~" ANNULUS & 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (11/19102 WAIVER)*** 2199' ¢-1/2" I-ES X NP, ID = 3.813" I I 13-3/~' CSG, 72#, L-80, ID= 12.347" H 2723' Minimum ID = 3.725" @ 10445' 4-1/2" HES XN NIPPLE GAS LIFT M~NDRELS PERFORATION SUMMa, RY REF LOG: TCP PERF ANGLEATTOP PELF: 83 @ 11780' Note: Refer to R'oduc~on DBfor historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11765-11790 O 01/29/02 2-7~8" 4 11780-11805 O 05/06/01 2-7/8" 4 11987-12165 O 11/19/99 2-7~8" 4 12225-12961 O 11/19/99 2-7/8" 4 13004-13650 O 11/19/99 2-7/8" 4 13702-13998 O 11/19/99 I9-5/8"CSG, 47#, L-80, ID: 8.681" H 10480' 14-1/2"TBG, 12.6#, L-80, .0152 3.95~" 10456' 17"x ~' BKRZXPPKR, ~D = 4.375" H 104ST 17" X ~' BKR I-Iv~C HGR, ID = 4.375" 10464' 17" LNR, 26#, Lq~0,.0383 bpf, ID=S27D' H 10615' 866~ 8675' 8683' HTOP OF BKRTIEBACK SLV I H9-5/8"X 7"BKR ZXPPKI~ ID= 6.313" I H9-5/8"X 7" BKRHMCHGR, ID=6250" I 9-5/8" CSG MILLOUTWINDOW 0039' - 10067' (OFF WHIPSTOCK) 10428' H 71' X 4-1J2'' PES TNT PKR, I / ID = 3.875" I 4-1/2" HBS XN NP, ID = 3.725"I 10450' HBKR TIEBACK SLY I 1o45s' H I 14-1/Z' LNR, 12.6#, L-80, .0152 bPf, D = 3.958" H 14135' DATE REV BY COMMEN3S DATE REV BY COIVIVlENTS 10102177 ORIGINAL COIvI:=LETION 11/19/02 JRC/KK WAIVERSAFETY NOTE 03/07/87 RWO 11/18/94 CTDSIDETRACI< ( 5-16A ) 11120199 CTDSIDETRACK ( 5-16B ) 01/09/02 CH/KAK CORRECTIONS 01/29/02 ATD/KK ADPERFS PRUDHOE BAY UI~IT WELL: 0~16B PEI~Vlrr No: 199100 APl No: 5~029-20262-02 SEC 32, T11N, R15E 3367' FSL & 38' FWL BI= E~ploration (Alaska) WELLHEAD PACKOFF TESTING FORM WELL: DATE: TESTED BY: DS: 05-16 11/24/2002 FMC TEST FOR: TYPE & GEN FSO # 32621 FIVlC I Well Status: TBG: CONTROL: INITIAL PRESSURE DATA TYPE: 1900 IA: 800 N/A BALANCE: NIA OA: 180 Tubincl Hanger Test PASS FAIL Pressured To: 5000 Press. @ 15 min: 4800 Press. @ 30 min: 4800 Test Port Press. @: 0 Bled to 0 Psi YES / NO Were Lockdown Screws Tightened ? YES / NO Torqued to fi/lbs Comments: Alinment pin is OUT. Inner Casing Hanger Test PASS FAIL PLASTIC PACK Pressured To: 3000 Press. @ 15 min: 2900 Press. @ 30 min: 2850 Test Port Press. @: 250 Bled to 0 Psi YES / NO Were Lockdown Screws Tightened ? YES / NO Torqued to 600 fi/lbs Comments: Lockdown screws were ti'~ ~,'..e~ed to 600 ft-lbs (Max) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / 05 09/20/02 Dave Wendt; John Petty Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. Well 05-16B I Typelnj. I N/A MD/TVDI 10,428'I 8,099' Tubing 1900 1900 1900 1900 Interval I P.T.D. 1991000I IType test M Test pail 2025~ I. Casing 1800 1800 1800 1800 P/F P Notes: MIT-OA O. Casing 0 3000 2880 2840 Well Inj. MD/TVDI Interval P.T.D. I Type Casing P/F Notes: O. Casing WellI Type Inj. MD/TVDI Interval P.T.D., I I Testpsi' I ITubing Type test P/F Casing Notes: Well Type Inj. MD/TVDI Tubing P.T.D. ITypetest I Testpsi[ I ICasing IIntervalP/F Notes: Well Type Inj. MD/TVDI Tubing Interval P.T.D. ITypetest ITestpsi' I ICasing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Vanance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 05-16B MIT-OA 09-20-02 xls WELL INTEGRITY TESTING TUBING INTEGRITY FLUID LEVEL SURVEY Well: 05-16B DATE: 11/17/02 TESTED BY: Aaron Brueggeman TIFL: PASS Well Status: SHUT IN TBG: 1950 Control: .... INITIAL PRESSURE DATA GAS LIFTED: IA: 1950 OA: 300 Balance: .... NO ORIFICE DEPTH: N/A INITIAL FLUID LEVEL: 7826' BLED FROM 1950 POST BLEED PRESSURES: WELL BACK TO PRODUCTION: psi To 780 TBG: TIFL SUMMARY LIVE GLV'S AT: N/A POST BLEED FLUID LEVEL: 7826' psi in 4 HRS and MINS 1800 IA: 780 OA: 200 NO FLUID LEVEL DATA TIME TBG IA OA FLUID LEVEL COMMENTS 11:00 1950 1950 300 7826' Bled IA 3:00 1800 780 200 7826' Shut in bleed and monitor for 1 hr 4:00 1800 790 200 7826' OBSERVATIONS / COMMENTS 1. Operations performed: ADD PERFS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIOn..,?!;! ~ ?i REPORT OF SUNDRY WELL OPERATIONS Operation shutdown_ Stimulate _ -~ ~ ~P|b'ggi'ng _" Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1912' FNL, 5241' FEL, Sec. 32, T11N, R15E, UM At top of productive interval 1581' FNL, 1159' FEL, Sec. 30, T11 N, R15E, UM At effective depth 593' FNL, 3118' FEL, Sec. 30, T11N, R15E, UM At total depth 593' FNL, 1718' FEL, Sec. 30, T11 N, R15E, UM 5. Type of Well: Development __X Exploratow__ Stratigraphic__ Service__ (asp's 697092, 5949530) (asp's 695728, 5955108) (asp's 693741, 5956045) (asp's 693603, 5956041) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 05-16B 9. Permit number / approval number 199-100 10. APl number 50-029-20262-02 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 116' Surface 2699' Intermediate 10015' Liner 1946' Siedtrack Liner 3685' 14135 feet Plugs (measured) 8795 feet 14000 feet Junk (measured) 8796 feet PBTD @ 14000' (05/05/2001) Size Cemented Measured Depth True Vertical Depth 20" 248 sx PF 140' 140' 13-3/8" 5950 sx PF II 2723' 2723' 9-5/8" 700 sx Class G, 300 sx 10039' 7815' PF 7" 339 sx Class'G' 8669' - 10615' 6943' - 8250' 4-1/2" 465 sx Class 'G' 10450' - 14135' 8117' - 8795' Perforation depth: measured Open Perfs 11765'-11790', 11780'-11805', 11990'-12165', 12225'-12965', 13015'-13605', Open Perfs (continued) 13700'-14005' true vertical Open Perfs 8776'-8779', 8778'-8780', 8790'-8799', 8798'-8795', 8794'-8795', 8797'-8795' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 10456' MD. Packers & SSSV (type & measured depth) 9-5/8" x 7" BKR ZXP PKR @ 8675'. 7" x 4-1/2" HES TNT PKR @ 10428'. 7" x 5" BKR ZXP PKR @ 10457' MD. 4-1/2" HES HXO Nipple @ 2199' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 01/28/2002 Subsequent to operation 02/07/2002 OiI-Bbl 512 Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl 5602 8 775 5629 63 Casing Pressure Tubing Pressure 320 391 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil__X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ t~.~~)~ Title: Technical Assistant DeWayne R. Sct'inorr Date April 15, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICA"z"~'x'"'~%'TE~I'~ \, 05-16B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/28/2002 PERF(ADD-PERF)' HOT OTL TREATMENT 01/28/2002 PERF(ADD-PERF)' HOT OTL TREATMENT; PERFORATING 01/29/2002 PERF(ADD-PERF)' PERFORATTNG EVENT SUMMARY 01/28/O2 01/28/o 2 ASSIST CTU. PUMP 340 BBLS DIESEL DOWN TUBING @ 170'. MIRU CT #1. RIH WITH 3" JET SWIRL NOZZLE. HOT DIESEL WASH TUBING/LINER TO 14003' CTM WITH WELL FLOWING ON GAS-LIFT. POOH JET WASHING LINER W/175 DEGF DIESEL. LD NOZZLE BHA AT END OF REPORT .... 01/29/02 MAKE UP PDS MEMORY GR/CCL AND RIH. LOG FROM 11400 TO 11900. POOH. GOOD DATA. MU SWS 2-7/8" PJ 4SPF 25' GUN. RIH. SHOOT 11765 - 11790' W/ WELL FLOWING. POOH. ASF. RDMO. ***LEFT WELL FLOWING AND TURNED WELL OVER TO DSO*** Fluids Pumped 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 0 TEST) 106 60/40 METHANOL WATER 66O DIESEL 766 TOTAL ADD PERFS 01/29/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2-7/8" PJ2906, 4 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 11765'-11790' Page 1 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1991000 Well Name/No. PRUDHOE BAY UNIT 05-16B Operator BP EXPLORATION (ALASKA) 1NC APl No. 50-029-20262-02-00 MD 14135 TVD 8795 Completion Date 11/20/1999 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__9.o Samples N~o Directional S~ y ~_..,,~. DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Interval Data Digital Digital Log Log Run OH / Dataset Type Media Format Na~ne Scale Media No Start Stop CH Received Number Comments i~ ................................... '-'/'-RY' 'SRam' RP'T ~'b-6 ........ 14"~,,~ ..... Oi:-I .... 1)4)2~6 ............... S~SERI~Y"'i ~'~ DGR/EWR-MD , 25 FINAL 10045 14141 OH 5/4/2000 .,. f DGR/CTN/SLD-MD 25 FINAL 12200 14141 OH 5/4/2000 LL/'/ DGR/EWR-'TVD 25 FINAL 7818 8795 OH 5~4~2000 O 1/28/2000 09524 10020-~ 4099 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/{~ Ch ip S,~P~'} . Analys~_ y / N_ Daily History Received? ~ N Formation Tops Receuived? ~N Comments: Compliance Reviewed By: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1912' FNL, 5241' FEL, Sec. 32, T11N, R15E, UM At top of productive interval 1581' FNL, 1159' FEL, Sec. 30, T11N, R15E, UM At effective depth At total depth 593' FNL, 1718' FEL, Sec. 30, T11N, R15E, UM Pedorate _X Other_ 5. Type of Well: Development ~X Exploratow__ Stratigraphic__ Service__ (asp's 697092, 5949530) (asp's 695728, 5955108) (asp's 693603, 5956041) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 05-16B 9. Permit number / approval number 199-100 10. APl number 50-029-20262-02 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 1 16' Surface 2658' Production 9974' Liner 1946' Liner 3685' 14135 feet Plugs (measured) 8795 feet 14000 feet Junk (measured) 8796 feet Tagged PBTD @ 14000' on 5/05/2001. Size Cemented Measured Depth True Vertical Depth 20" 248 Sx PF 1 16' 11 6' 13-3/8" 595O Sx PF II 2723' 2723' 9-5/8" 700 Sx Class G & 300 Sx PF 10039' 7815' 7" 339 Sx Class G 1 0615' 8250' 4-1/2" 465 Sx Class G 14135' 8795' Perforation depth: measured 11780'-11805'; 11990'-12165'; 12225'-12965'; 13015'-13650'; 13700'; 14005'. true vertical 8778' - 8780'; 8790' - 8799'; 8798' - 8795'; 8794' - 8795'; 8797' - 8795'. Tubing (size, grade, and measured depth) 4-1/2", 12.6¢, L-80 Tbg @ 10456' MD. Packers & SSSV (type & measured depth) 7" X 4-1/2" Howco TNT PACKER @ 10428' MD. 4-1/2" HES X Nipple @ 2199' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 49 630 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 2962 0 12546 40 Casing Pressure Tubing Pressure 439 413 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .__X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Title: DS 5 Surveillance Engineer Date May 14, 2001 Prepared by Paul Rauf 564-5799 SUBMIT IN DUPLICATE~J~ 05-16B DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date - Event Summary 05/05/2001: 5/06/2001: MIRU CTU. PT'd equip to 4000 psi. RIH w/CT & performed Hot Oil Tubing Wash to remove parrifin obstruction f/3050' to 3850'. Continued pumping hot oil to PBTD to 14000' MD. POOH. RIH w/GR logging tools. Encountered obstruction @ 11341' so POOH w/ logging tools to pick up shroud. RIH w/GR tools & shroud. Logged f/11400' - 12050' MD. POOH w/logging tools. RIH w/ CT conveyed perforating guns. Shot 25' of add perforations f/: 11780'- 11805' MD (Zone lB) Tie-in Log: Sperry MWD 11/02/1999. Used 2-7/8" PJ carriers & all shots @ 4 SPF, random orientation, & 60° phasing. POOH w/ guns - ASF. RD CTU. POP'd well & did welltest. Page 1 WEIJ, LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs · D.S. 05-16B, May 04, 2000 AK-MM-90178 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Fan Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 05-16B: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-20262-02 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20262-02 2"x 5"MD Neutron & Density Logs: 50-029-20262-02 ._.t-~- ............ ';}" x 5" TVD Neutron & Density Logs: /" 50-029-20262-02 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia : / 04 2000 0ii & Gas Cons. Commission 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company DRILLilMB C=;E RL/I C E =: -RECEIV'ED 2000 WELL LOG TRANSMITTAL Alaska Oil & Gas Cons. Commission Anchorage To: State of Alaska April 28, 2000 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 5-16B, AK-MM-90178 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention Jim Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, Ct(3, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20262-02. RECEiVEO MAY 02 2000 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company 29-Dec-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 05-16B Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 9,996.00' MD Window / Kickoff Survey: 10,039.00' MD Projected Survey: 14,135.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen ~r Survey Manager Attachment(s) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [] Gas [] Suspended [] Abandoned [] Service 7. Permit Number 2. Name of Operator 199-100 ARCO Alaska Inc. 3. Address 18. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 I 50.029-20262-02 4. Location of well at surface ~ii~ll~lllBil~l~.-' ' ~,/~lnit or Lease Name 3367' NSL, 38' EWL, SEC. 32, T11N, R15E, UM :?' ~./i: i?. i: .' .' : :~: ~ ?': , - ', [~~ .~'rudhoe Bay Unit At to,p, of productiv,e interval i ~ ~-"~:~ ~:'. '"~ ! ?i~. 'Well Number 3699A NSL,i h1180 WEL, SEC. 30, T11N, R15E, UM ~ _~.~/. ~'~ , ./,~ ,~i~~ 05-16B ttotadept ! ~,~;~;'i!:i~ : r~~~ Field and Pool 4687' NSL, 3279' WEL, SEC. 30, T11N, R15E, UM; ~_~__~' i .-. ~~:"~¢ Prudhoe Bay Field / Prudhoe Bay 5. KBEElevati°n= 65'in feet (indicate KB, DF, etc.) 116' ADLLeaSb'028326Designati0h and benal No.~1 Pool 12. Date Spudded11/4/99 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re 16' N°' °f C°mpleti°nsl 1/14/99 11/20/99 N/A MSL One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey I0. Depth where SSSV set 121. Thickness of Permafrost 14135 8795 FTI 14050 8795 FTI [~Yes I~No (Nipple) 2199' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, LWD, PWD, CNL, RES, GR, DEN, NED 23. CASING~ LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 116' 30" 248 sx Permafrost 13-3/8" 72# N-80 Surface 2723' 17-1/2" 5950 sx Permafrost II 9-5/8" 47# L-80/RS-95 Surface 10039' 12-1/4" 700 sx Class'G', 300 sx Permafrost 7" 26# L-80 8669' 10615' 8-1/2" 339 sx Class 'G' 4-1/2" 12.6# L-80 10450' 14135' 6-1/8" 465 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10458' 10428' MD TVD MD TVD 11990' - 12165' 8790' - 8799' 12225' - 12965' 8798' - 8795' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 13015' - 13650' 8794'- 8795' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13700' - 14005' 8797' - 8795' Freeze Protect with 155 Bbls of Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 0 R i G [ ,~.. I/~t I December 3, 1999 Gas Lift j '~J Lo Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATE OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. D 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED o E¢ 2 9 199oj Form 10-407 Rev. 07-01-80 Artc~lilit~ In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Sag River 10612' 8247' Shublik 10662' 8287' Sadlerochit 10734' 8344' Zone 1 B 11303' 8720' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerdeUubble '~./~, ~ Title Technical Assistant III Date I'''~' ?~"?'(~? 05-16B 199-100 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 28 Oct 99 29 Oct 99 PB DS 05 Progress Report Well 05-16B Page Rig Nabors 7ES Date 1 30 November 99 00:00-06:00 00:00-03:00 03:00 03:00-06:00 03:00-06:00 06:00-17:00 06:00-10:00 10:00 10:00-17:00 17:00 17:00-20:00 17:00-19:00 19:00 19:00-20:00 20:00 20:00-23:00 20:00-23:00 23:00 23:00-05:30 23:00-04:00 04:00 04:00-05:30 05:30 05:30-06:00 05:30-06:00 05:30-06:00 Duration 6hr 3hr 3hr 3hr llhr 4hr 7hr 3hr 2hr lhr 3hr 3hr 6-1/2 hr 5hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr Activity Move rig Rigged down Drillfloor / Derrick R/D rig floor and prepare to L/D derrick. L/D derrick. Equipment work completed Rig moved 75.00 % Move camp, rig substructure, shop to DS 5. Prepare rig to raise derrick while work on mud pits. (Mud pits still on DS 2) Rig moved 75.00 % Raised derrick. Bridal down, pin blocks to top drive. R/U rig floor. Finished move pits to DS5. Pits on location at 0830 hrs. Move rig (cont...) Rig moved 90.00 % (cont...) Raised derrick. Bridal down, pin blocks to top drive. R/U rig floor. Finished move pits to DS5. Pits on location at 0830 hrs. At well location - Cellar Rig moved 100.00 % Moved rig to line up on well. Lay matting boards and herculite. (Finished grading location at 1030 hrs). Spot sub base over well. Lay matting boards and herculite. Spot pit complex. Spot camp, shop. Finish berm around rig. String geramino line. At well location - Cellar Fluid system Fill pits with Seawater Take on seawater. Tested tubing hanger on well. Circ and test lines. Completed operations Held safety meeting Held pre-spud safety and environmental meeting. Reviewed pre-spud checklist. Completed operations Wellhead work Removed Xmas tree Tested BPV to 500 psi and N/D tree and adaptor. Install double valve on annulus. Equipment work completed Nipple up BOP stack Rigged up BOP stack Installed blanking plug. Jack rig to clear BOP stack over hole. Set stack, nipple up. Equipment work completed Rigged up Bottom ram Installed 2-3/8" pipe rams in lower cavity. Equipment work completed Test well control equipment Tested BOP stack R/U to test B OP's at report time. Tested BOP stack Tested BOP's. Tested pipe rams, blind rams, hydril, choke and kill lines, HCR valves, floor safety Facility Date/Time PB DS 05 06:00-10:30 06:00-10:30 Duration 4-1/2 hr 4-1/2 hr 10:30 10:30-12:30 10:30-11:00 11:00 11:00-12:30 12:30 12:30-20:30 12:30-14:00 2hr 1/2 hr 1-1/2 hr 8hr 1-1/2 hr 14:00 14:00-15:00 lhr 15:00 15:00-19:30 4-1/2 hr 19:30 19:30-20:30 20:30 20:30-22:30 20:30-22:30 lhr 2hr 2hr 22:30 22:30-04:30 22:30-04:00 6hr 5-1/2 hr 30 Oct 99 04:00 04:00-04:30 04:30 04:30-06:00 04:30-05:00 05:00 05:00-06:00 1-1/2 hr 1/2 hr lhr 06:00 06:00-06:00 06:00-09:00 09:00 24 hr 3hr Progress Report Well 05-16B Page Rig Nabors 7ES Date 2 30 November 99 Activity Witness of test waived by C. Sheive AOGCC. Test well control equipment (cont...) Tested BOP stack (cont...) Tested BOP's. Tested pipe rams, blind rams, hydril, choke and kill lines, HCR valves, floor safety valves to 250/3500 psi. Performed accumulator test. Witness of test waived by C. Sheive AOGCC. Pressure test completed successfully - 3500.000 psi Wellhead work Removed BOP test plug assembly Equipment work completed Retrieved Hanger plug R/U DSM and pulled BPV with lubricator. Equipment work completed Pull Tubing, 4-1/2in O.D. Pulled Tubing on retrieval string to 25.0 ft P/U double spear packoff assembly and engauged in 4-1/2" tubing. BOLDS. Pulled tubing hanger to rig floor. Stopped: To circulate Circulated at 2190.0 ft Circulate annulus plus tubing volume thru tubing cut below SSSV. Hole displaced with Seawater- 150.00 % displaced Laid down 2190.0 ft of Tubing L/D tubing and spool control lines. Recovered 51 jts tbg, SSSV, cutjt, 28 SS bands. TOF @ 2185.5'. 51 joints laid out Tbg in good condition for work string. Removed Tubing handling equipment L/D control line spooling unit and clear rig floor. Stopped: To pick up/lay out tubulars Run Drillpipe, 4in O.D. Singled in drill pipe to 93.0 ft PFL148 jts drill pipe and stand back in derrick. (Pocket for 2-3/8" drill pipe.) 48 joints picked up Run Tubing, 4-1/2in O.D. Ran Tubing to 2196.0 ft (4-1/2in OD) P/U guide, overshot, ext, top sub, xo and RIH on 4-1/2" tubing. Spaced out and landed work string on tubing hanger. RILDS. Hanger landed Removed Tubing handling equipment Equipment work completed BHA run no. 1 Rigged up Drillstring handling equipment Equipment work completed Made up BHA no. 1 Coiled tubing fishing BHA. GS spear, bumper jars, oil jars, xo, (6) 3-1/8" DC, xo = 195.70 BHA no. 1 made up BHA run no. 1 (cont...) Singled in drill pipe to 3522.0 ft At Top of fish: 3522.0 ft Facility Date/Time 31 Oct 99 PB DS 05 Progress Report Well 05-16B Page 3 Rig Nabors 7ES Date 30November 99 09:00-11:30 11:30 11:30-12:00 12:00 12:00-18:30 18:30 18:30-19:30 19:30 19:30-06:00 19:30-06:00 06:00-19:30 06:00-18:30 18:30 18:30-19:30 19:30 19:30-02:30 19:30-20:00 20:00 20:00-23:00 23:00 23:00-02:00 01 Nov 99 02:00 02:00-02:30 02:30 02:30-06:00 02:30-03:30 03:30 03:30-06:00 Duration 2-1/2 hr 1/2 hr 6-1/2 hr lhr 10-1/2 hr 10-1/2 hr 13-1/2 hr 12-1/2 hr 1 hr 7hr 1/2 hr 3hr 3hr 1/2 hr 3-1/2 hr lhr 2-1/2 hr Activity Fished at 3522.0 ft PFU wt 54K. Latch fish. P/U to 65K. Hold for 45 min. P/U to 85K, pkr came free. Work stretch out of tubing. Tubing hung up. Work pipe to 95K, pipe came free. Fish came free Flow check Monitor hole. Observed well static Laid down 3317.0 ft of 2-3/8in OD drill pipe POH L/D drill pipe. Pipe dragging to 85K. Pull slow. At BHA Pulled BHA BHA Laid out Laid down fish L/D 19' sections of 2-3/8" coiled tubing. 2000' laid out at report time Laid down fish Finish POH L/D 2-3/8" coiled tubing. Approx 6631' laid out, 10,150' chemical cut depth. BHA run no. 1 (cont...) Laid down fish (cont...) Finish POH L/D 2-3/8" coiled tubing. Approx 6631' laid out, 10,150' chemical cut depth. Complete fish recovered Rigged down Handling equipment Cleared floor of coiled tubing handling equipment. Work completed, equipment laid out Electric wireline work Held safety meeting Completed operations Rigged up Logging/braided cable equipment M/U landing jt and BOLDS. Set landing jt in slips, 10 over calculated string wt. R/U Schlumberger jet cutter. Equipment work completed Conducted electric cable operations RIH w/jet cutter. Tie in and cut tubing at 10,094' in bottom of first full joint above packer. Completed run with Explosive cutter from 0.0 ft to 10094.0 ft Rigged down Logging/braided cable equipment R/D Schlumberger. Equipment work completed Pull Tubing, 4-1/2in O.D. Worked stuck pipe at 10094.0 fl Attempt to work pipe free to 180K. No-Go. Back out tubing landing jt and installed drill pipe landing jt. Worked pipe to 260K, No-Go. Bring pumps on, 160 spm, 325 psi. Worked pipe to 260K, pulled free. P/U wt 135K. Pipe came free Circulated at 10094.0 ft Finish circulate 2.5 annular volumes, 200 spm, 425 Facility Date/Time 02 Nov 99 PB DS 05 Progress Report Well 05-16B Page Rig Nabors 7ES Date 4 30 November 99 03:30-06:00 06:00-18:30 06:00-08:00 08:00 08:00-17:30 17:30 17:30-18:30 18:30 18:30-19:00 18:30-19:00 19:00 19:00-02:00 19:00-21:30 21:30 21:30-22:00 22:00 22:00-23:00 23:00 23:00-02:00 02:00 02:00-06:00 02:00-06:00 06:00 06:00-15:30 06:00-09:00 09:00 09:00-10:30 10:30 10:30-14:30 14:30 14:30-15:30 15:30 15:30-19:30 15:30-17:00 Duration 2-1/2 hr 12-1/2 hr 2hr 9-1/2 hr lhr 1/2 hr 1/2 hr 7hr 2-1/2 hr 1/2 hr lhr 3hr 4hr 4hr 9-1/2 hr 3hr 1-1/2 hr 4hr lhr 4hr 1-1/2 hr Activity Circulated at 10094.0 ft CBU. 190 spm, 400 psi. Gas cut brine, SI and circ thru choke. 83 spm, 300 psi. Opened choke at bottoms up, circ at 113 spm, 200 psi. Circ at report time. Pull Tubing, 4-1/2in O.D. (cont...) Circulated at 10094.0 ft (cont...) CBU. 190 spm, 400 psi. Gas cut brine, SI and circ thru choke. 83 spm, 300 psi. Opened choke at bottoms up, circ at 113 spm, 200 psi. Circ at report time. Obtained clean returns - 250.00 % hole volume Laid down 10094.0 ft of Tubing L/D 245 jts + 28.15' cutjt. Tubing corroded on couplings, internal pitting. Tubing cut jagged and flared. 246 joints laid out Rigged down Tubing handling equipment Equipment work completed Wellhead work Installed Wear bushing Eqpt. work completed, running tool retrieved BHA run no. 2 Made up BHA no. 2 BHA no. 2 made up R.I.H. to 2362.0 ft Began precautionary measures Serviced Block line Line slipped and cut Singled in drill pipe to 6650.0 ft Draw works failed - Abort operation Repair Repaired Draw works Sperry Sun depth recorder failed, causing damage to the draworks clutch air lines, quick releases, spear rotating seal. Equipment work completed BHA run no. 2 Singled in drill pipe to 10082.0 ft Cont'd to RIH picking up drill pipe. Tagged bottom at 10,082'. Stopped: To circulate Circulated at 10082.0 ft Circ at 550 gpm, 2350 psi. Obtained some scale and asphaltene in returns. Obtained clean returns - 125.00 % hole volume Pulled out of hole to 872.0 ft At BHA Pulled BHA Stand back HWDP and DC's. L/D jars, scraper, bit. BHA Stood back Electric wireline work Rigged up Logging/braided cable equipment Facility Date/Time PB DS 05 Progress Report Well 05-16B Page 5 Rig Nabors 7ES Date 30 November 99 17:00 17:00-19:00 19:00 19:00-19:30 19:30 19:30-20:00 19:30-20:00 20:00 20:00-21:30 20:00-21:30 21:30 21:30-06:00 21:30-00:30 03 Nov 99 00:30 00:30-05:00 05:00 05:00-06:00 06:00 06:00-02:30 06:00-09:00 09:00 09:00-18:30 18:30 18:30-20:00 20:00 20:00-00:00 04Nov 99 00:00 00:00-02:30 02:30 02:30-04:00 02:30-03:00 03:00 03:00-03:30 Duration 2hr 1-1/2 hr 1-1/2 hr 8-1/2 hr 3hr 4-1/2 hr lhr 20-1/2 hr 3hr 9-1/2 hr 1-1/2 hr 4hr 2-1/2 hr 1-1/2 hr 1/2 hr Activity M/U tools. Equipment work completed R.I.H. to 10081.0 ft RIH and tagged up at 10081' WLM. P/U and set top EZSV bridge plug at 10,071', 5' above casing collar. POH. At Surface: 0.0 ft Rigged down Wireline units Equipment work completed Perform integrity test Tested Casing - Via string Performed 30 min casing test to 3000 psi, held OK. Pressure test completed successfully - 3000.000 psi Nipple up Bottom ram Rigged up Bottom ram Pulled wear ring. Installed test plug. Changed lower pipe rams to 2-7/8" X 5" VBR. Tested doors to 3500 psi. Installed wear ring. Equipment work completed BHA run no. 3 Made up BHA no. 3 P/U Whipstock and milling BHA. BHA no. 3 made up R.I.H. to 10070.0 ft RIH w/whipstock. Filled DP and tested MWD at 5300'. Cont'd RIH. At Setting depth: 10070.0 ft Set tool face Orient and set whipstock tool face 73 deg left high side. Set whipstock. Sheared off. Stopped: To circulate BHA run no. 3 (cont...) Circulated at 10039.0 ft Pump 50 bbls H20, 45 bbls Hi Visc H20, and displace to 10.5 ppg drilling mud. 9.5 bbl/min, 2150 psi. Hole displaced with Water based mud - 100.00 % dis, placed Milled Casing at 10067.0 ft Milled casing window from 10,039' to 10,055'. Continue to dress window to 10,067'. Work mills thru window. Completed operations Circulated at 10067.0 ft Pump weighted hi visc sweep. Circ sweep around. Obtained clean returns - 150.00 % hole volume Pulled out of hole to 910.0 ft At BHA Pulled BHA Stand back HWDP. L/D steel DC's, MWD, mills. Top mill in gauge. BHA Stood back Planned maintenance Serviced Wear bushing Pulled wear bushing. Equipment work completed Serviced BOP stack l_,C~utatcu julnt aHu waan~u stack. Facility PB DS 05 Progress Report Well 05-16B Page Rig Nabors 7ES Date 6 30 November 99 Date/Time 03:30 03:30-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-17:00 06:00-10:30 10:30 10:30-12:00 12:00 12:00-16:00 16:00 16:00-17:00 17:00 17:00-06:00 17:00-17:30 17:30 17:30-19:00 19:00 19:00-20:00 20:00 20:00-22:30 22:30 22:30-23:00 23:00 23:00-06:00 23:00-06:00 05 Nov 99 06:00-06:00 06:00-18:30 18:30 18:30-20:30 20:30 20:30-21:00 21:00 21:00-21:30 Duration 1/2 hr 2hr 2hr llhr 4-1/2 hr 1-1/2 hr 4hr lhr 13hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 1/2 hr 7hr 7hr 24 hr 12-1/2 hr 2 hr 1/2 hr 1/2 hr Activity Equipment work completed Serviced Wear bushing Installed wear bushing. Equipment work completed BHA run no. 4 Made up BHA no. 4 BHA no. 4 made up BHA run no. 4 (cont...) R.I.H. to 9975.0 ft RIH. P/U 24 jts drill pipe. Flow test MWD @ 5000', OK. Finish RIH to 9975'. Attempt to orient motor to pass thru whipstock. Stopped · To take survey Took MWD survey at 9975.0 ft Attempt to survey to tool face. No signal from MWD. Trouble shoot system, no signal. MWD failed - End BHA run Pulled out of hole to 733.0 ft At BHA Pulled BHA Pulled BHA. Changed out MWD. BHA Stood back Laid out MWD. BHA run no. 5 Made up BHA no. 5 BHA no. 5 made up R.I.H. to 3060.0 ft Began precautionary measures Serviced Block line Shallow test MWD while cut and slip drilling line. Line slipped and cut R.I.H. to 10010.0 ft Stopped · To take survey Set tool face Orient and go thru window. No problems. Completed operations Drilled to 10257.0 ft Drill ahead sliding as per directional plan. Drilled to 10257.0 ft Drilled ahead f/10,257' - 10,615'. AST=l.25 hrs ART=9 hrs BHA run no. 5 (cont...) Drilled to 10615.0 ft (cont...) Drilled ahead f/10,257' - 10,615'. AST=l.25 hrs ART=9 hrs Reached planned end of run - Section / well T.D. Circulated at 10615.0 ft Pump sweep. CBU. Obtained clean returns - 250.00 % hole volume Pulled out of hole to 9975.0 ft POH to 9995'. At top of check trip interval R.I.H. to 10615.0 ft Progress Report Facility PB DS 05 Well 05-16B Rig Nabors 7ES Page 7 Date 30 November 99 Date/Time Duration Activity 21:30 21:30-23:00 23:00 23:00-23:30 23:30 23:30-00:00 06 Nov 99 00:00 00:00-00:30 00:30 00:30-04:30 04:30 06:00-07:00 06:00-07:00 07:00 07:00-20:00 07:00-08:30 08:30 08:30-09:00 09:00 09:00-13:00 13:00 13:00-19:00 19:00 19:00-20:00 20:00 20:00-23:30 20:00-21:30 21:30 21:30-22:00 22:00 22:00-23:30 23:30 23:30-03:30 1-1/2 hr 1/2 hr 4hr lhr lhr 13hr 1-1/2 hr 1/2 hr 4 hr 6hr lhr 3-1/2 hr 1-1/2 hr 1-1/2 hr 4hr On bottom Circulated at 10615.0 ft Circ B/U. Spot 5% lubetex pill on bottom. Obtained clean returns - 150.00 % hole volume Took Wireline multishot survey at 10313.0 ft Dropped multishot and took survey at 10,313' Acceptable survey obtained at 10313.0 ft Pulled out of hole to 9975.0 ft POH to shoe. Stopped: To flowcheck well Flow check Checked for flow. Dropped rabbit. Pump dry job. Observed well static Pulled out of hole to 733.0 ft AtBHA BHA run no. 5 (cont...) Pulled BHA BHA Laid out Run Liner, 7in O.D. Rigged up Casing handling equipment Equipment work completed Held safety meeting Completed operations Ran Liner to 1946.0 ft (7in OD) Ran (47)jts 7", 26/4, L-80, BTC-M casing and liner hanger packer. Stopped: To change handling equipment Ran Liner on landing string to 10615.0 ft Ran liner to casing shoe. Broke circ. Finish RIH w/liner. No hole problems. Stopped: To circulate Circulated at 10615.0 ft Held PJSM while circ prior to cementing. Obtained bottoms up (100% annulus volume) Cement: Liner cement Mixed and pumped slurry - 70.000 bbl Pmp 5 bbls spacer at 11.0 ppg. Test lines to 4500 psi. Pmp 25 bbls spacer. Mix and pump 70 bbls class g cmt + additives at 15.8 ppg. Dropped plug. Displaced with 160 bbls mud. CIP 2130 hrs. Full returns thru job. Cement pumped Functioned Liner hanger Pressure to 3000 psi to set hanger. Press to 4200 psi to set packer. Bled off pressure, switched to rig pumps. Rotate and release from hanger with 1000 psi. Circ. Set down 60K to check packer. Equipment work completed Circulated at 8669.0 ft Circ at max rate to clear cement from annulus. 13.7 bbl/min, 3050 psi. Got 10 bbls cmt returns. Obtained clean returns - 150.00 % hole volume Pull Drillpipe, 4in O.D. Facility PB DS 05 Progress Report Well 05-16B Page 8 Rig Nabors 7ES Date 30November 99 Date/Time 23:30-03:30 07 Nov 99 03:30 03:30-04:00 03:30-04:00 04:00 04:00-05:30 04:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-06:00 07:00-10:00 10:00 10:00-13:30 13:30 13:30-14:00 14:00 14:00-16:00 16:00 16:00-20:00 20:00 20:00-23:00 23:00 23:00-06:00 23:00-06:00 08 Nov 99 06:00-06:00 06:00-06:00 Duration 4hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 23 hr 3hr 3-1/2 hr 1/2 hr 2hr 4hr 3hr 7hr 7hr 24 hr 24 hr Activity Pulled Drillpipe in stands to 0.0 ft POH and L/D running tool. At Surface · 0.0 ft Wellhead work Removed Wear bushing Equipment work completed Test well control equipment Tested BOP stack Tested choke on trip out of hole. Tested pipe rams, blind rams, hydril, choke and kill line valves, floor safety valves to 250/3500 psi. Tested accumulator, OK. Witness of test approved by J. Crisp, AOGCC. Pressure test completed successfully - 3500.000 psi Wellhead work Installed Wear bushing Eqpt. work completed, running tool retrieved Perform integrity test Tested Casing Test 7" x 9-5/8" casing to 3000 psi. (Changed top drive XO while pressure testing.) Pressure test completed successfully - 3000.000 psi BHA run no. 6 Made up BHA no. 6 Made up BHA. Shallow tested MWD. BHA no. 6 made up Singled in drill pipe to 5430.0 ft P/U 4" drill pipe required to TD hole. 123 joints picked up Took MWD survey at 5430.0 ft Check MWD. Acceptable survey obtained at 5400.0 ft R.I.H. to 10475.0 ft Began precautionary measures Drilled cement to 10620.0 ft Washed down and tagged cmt @ 10,510'. Drilled float equip and cement + 5' new hole with 10.5 ppg for FIT. Stopped · To circulate Circulated at 10620.0 ft Circulated 45 bbl hi visc sweep and changed mud system over to 8.4 ppg Quickdrill. Hole displaced with Water based mud - 125.00 % displaced Drilled to 10900.0 ft Drilled ahead from 10,900' - 11,800'. ART=10.5 hrs AST= 10 hrs Drilled to 10900.0 ft Drilled ahead f/10,620' -10, 900 sliding and rotating for angle and direction. ART= 5 hrs AST = 1 hr Drilling ahead at report time. BHA run no. 6 (cont...) Drilled to 11800.0 ft (cont...) Drilled ahead f/10,620' -10, 900 sliding and rotating for angle and direction. ART= 5 hrs AST = 1 t, ~,,,,,,g a,vau at report timc. Facility PB DS 05 Duration 24 hr 24 hr Date/Time 09 Nov 99 06:00-06:00 06:00-06:00 17hr 6hr 10 Nov 99 06:00-23:00 06:00-12:00 12:00 1 hr 12:00-13:00 13:00 13:00-13:15 13:15 13:15-14:15 14:15 14:15-14:30 14:30 14:30-15:00 15:00 15:00-16:30 16:30 1/2 hr 1-1/2 hr 3-1/2 hr 3hr 16:30-20:00 20:00 20:00-23:00 23:00 7hr 3hr 23:00-06:00 23:00-02:00 11 Nov 99 02:00 02:00-06:00 4hr 24 hr 1/2 hr 06:00-06:00 06:00-06:30 06:30 Progress Report Well 05-16B Page Rig Nabors 7ES Date Activity BHA run no. 6 (cont...) Drilled to 12110.0 ft Drill ahead 6.1/8" hole from 11,800' to 12,061'. 9 30 November 99 No Drag, No Losses. Drilling Parameters steady. BHA run no. 6 (cont...) Drilled to 12246.0 ft Reached planned end of run - Maximum hours on bit Directionally Drill 6.1/8" hole f/12,061' to 12,246'. No drag, no losses. Sweep hole clean. Bit Hours= 53 Krevs= 295,000 Circulated at 12246.0 ft Obtained clean returns - 80.00 % hole volume Observe sweep clear shakers and circulate until shakers clean ( x 3 OH volumes) Flow check Observed well static Pulled out of hole to 10615.0 ft At 7in casing shoe POOH. Hole in good shape. Good hole fill. Circulated at 10615.0 ft Heavy slug spotted downhole Pump Dry Job Pulled out of hole to 8668.0 ft Stopped: To service drilling equipment Serviced Block line Line slipped and cut Slip and cut 95' of line. Inspect TopDrive. Pulled out of hole to 800.0 ft At BHA Pulled BHA BHA Laid out Pull BHA. L/O Bit, motor, MWD and download. Clear rigfloor. Bit graded 4/5 1/6" u gage. Seals effective. Wear pattern a combination of lost teeth, chipped teeth and erosion. BHA run no. 7 Made up BHA no. 7 BHA no. 7 made up M/U new bit, new mtor w/1.5 bend, no offset pad and LWD tools. Surface test same. R.I.H. to 8700.0 ft RIH to 8700' on 4" dp. BHA run no. 7 (cont...) R.I.H. to 11600.0 ft Began precautionary measures Drill thru shale interval ( 14 N ) looking for sand below. Progress slow. Found sand @ 8,787'TVD, +/- 11,965' MD. Facility PB DS 05 Datefrime Duration 06:30-11:00 4-1/2 hr 11:00 11:00-12:00 1 hr 12:00 12:00-06:00 18 hr 12 Nov 99 06:00-06:00 24 hr 06:00-06:00 24 hr 13 Nov 99 06:00-06:00 24 hr 06:00-04:30 22-1/2 hr 14 Nov 99 04:30 04:30-06:00 1-1/2 hr 06:00-04:30 22-1/2 hr 06:00-07:00 1 hr 07:00 07:00-07:15 1/4 hr 07:15 07:15-09:30 2-1/4 hr 09:30 09:30-11:30 2 hr 11:30 11:30-13:30 2hr 13:30 13:30-17:00 3-1/2 hr 17:00 Progress Report Well 05-16B Page 10 Rig Nabors 7ES Date 30 November 99 Activity Logged hole with LWD: DIR/FE from 11600.0 ft to 11235.0 ft Completed operations Make MADD pass. Logging speed @ 75 fph. Unable to speed process without compromising data quality. Provisional GOC @ 11,315' MD, 8660' TVD SS. R.I.H. to 12246.0 fl On bottom RIH. No problems. 5 ft of fill. Hole in good shape. Drilled to 12626.0 ft Directionally drill 6.1/8" hole f/12,246 to 12,626 sliding for azimuth. Occaisonal overpulls after sliding. Sweep hole on every rotation. Sweeps bringing significant increase in cuttings. ECD raises 0.2 ppg when sweep in hole & rot. Background 9.2 ppg. BHA run no. 7 (cont...) Drilled to 13326.0 ft Directionally drill 6.1/8" hole periodically sweeping hole.No drag, no losses. Bit Hours @ 34 Krevs @ 191,400 BHA run no. 7 (cont...) Drilled to 14135.0 ft Reached planned end of run - Section / well T.D. Directionally Drill 6.1/8" f/13,326' to 14,135'. No drag. No losses. Reach planned TD. Bit Hours @ 53 Total Krevs= 311,460 ( Sliding 101700, rotating 209760) Circulated at 14135.0 ft Pump sweep and circulate hole clean @ 255 GPM/2100 psi. Background ECD @ 9.5 ppg. BHA run no. 7 (cont...) Circulated at 14135.0 ft Obtained bottoms up (100% annulus volume) Sweep hole clean and CBU @ 255 GPM/2000 psi. ECD steady @ 9.5 ppg. Flow check Observed well static Pulled out of hole to 10615.0 ft At 7in casing shoe POOH. Hole in good shape. Good hole fill. No overpulls. Serviced Block line Line slipped and cut Slip and cut 80 fl drilline. Service top drive and adjust brakes. R.I.H. to 14135.0 fl On bottom RIH. Hole in good shape. No fill. Circulated at 14135.0 ft Obtained bottoms up (100% annulus volume) IJJ uuI ~UllkU1111 Facility PB DS 05 Progress Report Well 05-16B Page 11 Rig Nabors 7ES Date 30 November 99 Date/Time 17:00-19:30 19:30 19:30-19:45 19:45 19:45-20:30 20:30 20:30-02:00 15 Nov 99 02:00 02:00-04:30 04:30 04:30-06:00 04:30-05:15 05:15 05:15-06:00 06:00-19:00 06:00-09:00 09:00 09:00-09:30 09:30 09:30-10:00 10:00 10:00-15:30 15:30 15:30-16:30 16:30 16:30-19:00 19:00 19:00-04:00 19:00-22:30 22:30 Duration 2-1/2 hr 1/4 hr 3/4 hr 5-1/2 hr 2-1/2 hr 1-1/2 hr 3/4 hr 3/4 hr 13hr 3hr 5-1/2 hr lhr 2-1/2 hr 9hr 3-1/2 hr Activity liner pill. Pulled out of hole to 10615.0 ft At 7in casing shoe Hole in good shape. SLM. Flow check Observed well static Circulated at 10615.0 ft Heavy slug spotted downhole Drop 2.3/8" hollow rabbit. Pump dry job while troubleshooting SCR problem- resolve same. Pulled out of hole to 800.0 ft At BHA POOH. SLM- 5 ft difference on strap. Pulled BHA BHA Laid out L/D BHA. UNload sources and download data. Inspect bit. Bearing life still good. ( Note TBR for ALL circulating was 414,000 krevs) Run Liner, 4-1/2in O.D. Rigged up Casing handling equipment Equipment work completed Hold PJSM. R/U to run tubulars. Ran Liner to 400.0 ft (4-1/2in OD) MFLI Shoetrack. Bakerlok same and check floats. RIH 4.1/2" liner, 12.6 lb/ft, IBT M Run Liner, 4-1/2in O.D. (cont...) Ran Liner to 3690.0 ft (4-1/2in OD) Stopped: At sub-assembly Run 89 joints of 12.6 lb/ft, IBT-M, L-80. Installed Liner hanger Equipment work completed M/U 5 x 7" HMC hanger and ZXP packer. Inspect same. Up/down weight= 72 klbs. Circulated at 3691.0 ft String displaced with Water based mud - 100.00 % displaced Circulate liner contents @ 4 BPM/230 psi. Ran Liner on landing string to 10615.0 ft At 7in casing shoe RIH 4.1/2" liner on 4" drillpipe to 7" casing shoe @ 10,615'. No problems entering TOL @ 8,668'. Circulated at 10615.0 ft String displaced with Water based mud - 100.00 % displaced Circulate liner/drillstring volume @ 3 BPM/700 psi. Up weight= 160 klbs, down = 140 klbs. P/U cement head and put on skate. Ran Liner on landing string to 14135.0 ft On bottom RIH liner to bottom. Some resistance going thru shale @ 11,800'. Cement: Liner cement Circulated at 14135.0 ft Obtained clean returns - 120.00 % hole volume Stage pumps up slowly to 5 BPM/1100 psi. Reciprocation stopped after some overpulls. Pressures steady. Facility PB DS 05 Date/Time Progress Report Well 05-16B Page Rig Nabors 7ES Date 12 30 November 99 22:30-23:00 23:00 23:00-23:30 23:30 23:30-23:45 23:45 23:45-00:15 16 Nov 99 00:15 00:15-00:45 00:45 00:45-04:00 04:00 04:00-06:00 04:00-06:00 06:00-10:30 06:00-07:45 07:45 07:45-10:30 10:30 10:30-11:30 10:30-11:30 11:30 11:30-15'15 11:30-15:15 15:15 15:15-16:30 15:15-15:45 15:45 15:45-16:30 Duration 1/2 hr 1/2 hr 1/4 hr 1/2 hr 1/2 hr 3-1/4 hr 2hr 2hr 4-1/2 hr 1-3/4 hr 2-3/4 hr 1 hr 1 hr 3-3/4 hr 3-3/4 hr 1-1/4 hr 1/2 hr 3/4 hr Activity Pumped Water based mud spacers - volume 30.000 bbl Required volume of spacer pumped Pump 5 bbls 9 ppg viscosified spacer. Test lines to 4500 psi. Pump remainder of spacer @ 2 BPM/750 psi. Mixed and pumped slurry - 97.000 bbl Cement pumped Pump 15.8 ppg slurry @ 5 BPM/1600 psi. Pump 97 bbls, 465 sx. Slurry batch mixed ( started @ 2100 hrs) Cleared Circulating head Equipment work completed Clear lines of cement w/5 bbls perforation pill. Displaced slurry - 156.000 bbl Plug bumped Displ;ace slurry w/80 bbls perforation pill and 76 bbls seawater. Observe wiper plug shear. Bump plug and pressure to 3000 psi. Displace @ 5 BPM/1800 psi. Functioned Liner hanger Equipment work completed Raise pressure to 4200 psi. Bleed off and check floats- good. Switch to rig pumps. Check hanger/ packer set. Rotate off, holding 1000 psi pick up and circulate @ 7 BPM/1400 psi/10 mins. Check packer. Circulated at 10450.0 ft Obtained clean returns - 300.00 % hole volume Circulate @ maximum rate at top of 4.1/2" liner. Observe aprroximatley 15 bbls contaminated cement. Pull one stand and circulate well to clean seawater @ 40 NTU. Pull Drillpipe, 4in O.D. Laid down 3700.0 ft of 4in OD drill pipe POOH laying down 120 joints of 4" drillpipe. Pull Drillpipe, 4in O.D. (cont...) Laid down 3700.0 ft of 4in OD drill pipe 115 joints laid out Pulled Drillpipe in stands to 0.0 ft At Surface: 0.0 ft POOH, inspect liner running tool- all good. Perform integrity test Tested Liner Pressure test completed successfully - 3000.000 psi Test wellbore to 3000 psi/30 minutes. 8.25 bbls pumped/returned. BOP/riser operations - BOP stack Tested BOP stack Pressure test completed successfully - 3000.000 psi Pull wear ring. Test BOPE to 3500 psi. Witness waived by John Spalding- AOGCC. Install wear ring. 2-7/8in. Perforation assembly workstring run Held safety meeting Completed operations Ran Tubing to 80.0 ft (2-7/8in OD) Facility PB DS 05 Date/Time Progress Report Well 05-16B Page Rig Nabors 7ES Date 13 30 November 99 16:30 16:30-06:00 16:30-06:00 17 Nov 99 06:00-12:00 06:00-12:00 12:00 12:00-06:00 12:00-12:30 12:30 12:30-17:30 17:30 17:30-18:30 18:30 18:30-01:00 18 Nov 99 01:00 01:00-01:45 01:45 01:45-03:30 03:30 03:30-06:00 06:00-23:00 06:00-07:00 07:00 07:00-08:00 08:00 08:00-13:30 13:30 13:30-14:00 14:00 14:00-16:00 16:00 Duration 13-1/2 hr 13-1/2 hr 6hr 6hr 18hr 1/2 hr 5hr lhr 6-1/2 hr 3/4 hr 1-3/4 hr 2-1/2 hr 17 hr lhr 1 hr 5-1/2 hr 1/2 hr 2hr Activity Stopped due to weather: Whiteout / Phase 3 Make up first two set of guns. Phase 3 declared in EOA. Suspend operations Rig waited: Whiteout / Phase 3 Whiteout- no vehicle movement. Forecast to improve during morning. Suspend operations (cont...) Rig waited: Whiteout / Phase 3 Resumed operations Unable to operate- Phase 3. Phase 3 conditions lifted @ 1100 hrs. Inspect rig and make crew change. 2-7/8in. Perforation assembly workstring run Held safety meeting Completed operations Hold safety meeting with new crew. Ran Tubing to 3700.0 ft (2-7/8in OD) Stopped: At sub-assembly MFU 2.7/8" guns. 4 SPF, mixture of 34J and PJ2906 charges. Total length = 1856 ft, blank = 175 ft. Run 53 jt of 2.7/8" FOX. Installed Retrievable packer Equipment work completed Ran Drillpipe to 13999.0 ft (4in OD) At Setting depth: 13999.0 ft RIH Perforation assembly on 4" drillpipe. No problems entering 7" liner @ 8,668' and 4.1/2" liner @ 10,450'. Tag Landing collar on depth- space out. Perforated from 11987.0 ft to 13998.0 ft Interval perforated Set Champ Packer. Shoot Fluid level @ 1700'. Pressure upto 2700 psi and bleed off. Fire guns- good surface indication. Reverse circulated at 10280.0 ft Obtained clean returns - 100.00 % hole volume Reverse circulate x 3 tubing volume thru choke. Minor losses ( 5 bbls over 1 hour). Circulate until clean returns. Laid down 3000.0 ft of 4in OD drill pipe Unseat Packer. No Losses. POOH L/D 4" drillpipe. 2-7/8in. Perforation assembly workstring run (cont...) Laid down 2000.0 ft of 4in OD drill pipe Stopped: To service drilling equipment Serviced Block line Line slipped and cut Laid down 5800.0 ft of 4in OD drill pipe 334 joints laid out Rigged down sub-surface equipment - Retrievable packer Equipment work completed Lay down Halliburton Packer Assembly. Static losses @ 2.5 BPH. Laid down 1600.0 ft of Tubing 53 joints laid out ..1 .....~'"~ ' ' ~.C'~I '-//OH Lay ..... .~.2 joints ....... Fox tubing. Facility PB DS 05 Progress Report Well 05-16B Page 14 Rig Nabors 7ES Date 30November 99 Date/Time 16:00-16:15 16:15 16:15-23:00 23:00 23:00-04:00 23:00-04:00 19 Nov 99 04:00 04:00-06:00 04:00-04:30 04:30 04:30-05:00 05:00 05:00-06:00 06:00-01:00 06:00-12:00 12:00 12:00-12:30 12:30 12:30-16:30 16:30 16:30-18:00 18:00 18:00-21:00 21:00 21:00-22:00 22:00 22:00-23:45 23:45 Duration 1/4 hr 6-3/4 hr 5hr 5hr 2hr 1/2 hr 1/2 hr lhr 19hr 6hr 1/2 hr 4hr 1-1/2 hr 3hr lhr 1-3/4 hr Activity Held safety meeting Completed operations Hold Safety Meeting to discuss laying down Perforation guns. Laid down 2000.0 ft of Tubing Completed operations L/D guns in 20 ft lengths checking for trapped gas. All shots fired. Clear rigfloor. Slickline wireline work Conducted slickline operations on Slickline equipment - Tool run Completed run with Junk basket/gauge ring from 0.0 ft to 10465.0 ft R/U and run 6.00" gauge ring down to 10,465'- slickline depth- Top of 4.1/2" liner. R/D Slickline. Run Gas lift completion, 4-1/2in O.D. Removed Wear bushing Equipment work completed Rigged up Completion string handling equipment Equipment work completed Hold PJSM and R/U to run 4.1/2" completion. Ran Tubing to 500.0 ft (4-1/2in OD) Run Completion. Static loss rate @ 2-3 BPH. Run Gas lift completion, 4-1/2in O.D. (cont...) Ran Tubing to 8300.0 ft (4-1/2in OD) Rig equipment failed - Change operation RIH with 4.1/2" completion. Power outage. Shut down. Serviced SCR Equipment work completed Trouble shoot power problem. Main CPU failure. Run on manual modes and hold Safety Meeting w/crew to discuss emergency shut down systems Ran Tubing to 10457.0 ft (4-1/2in OD) At Top of liner: 10457.0 ft Run 4.1/2" completion. Tag Tieback sleeve on depth- no resistance top of 7" liner. Space out tubulars Completed operations Space out tubulars and MFLI tubing hanger. Reverse circulated at 10437.0 ft Hole displaced with Inhibited brine - 100.00 % displaced Reverse circulate inhibited brine @ 3 BPM/150 psi. Ran Tubing on landing string to 10457.0 ft Hanger landed Drop ball and rod. Run and land Hanger. 250 joints of 4.1/2" tubing, 12.6 lb/ft, IBT-M, L-80.5 pup joints. Up weight 135 klbs, down weight 105 klbs. Tested Tubing Pressure test completed successfully - 4800.000 psi R/U surface lines and test same to 4800 psi. Pressure up tubing string setting packer and taking pressure to 4,800 psi/30 n-,inutcs. Facility PB DS 05 Progress Report Well 05-16B Page Rig Nabors 7ES Date 15 30 November 99 Date/Time 23:45-00:30 20 Nov 99 00:30 00:30-01:00 01:00 01:00-02:30 01:00-02:30 02:30 02:30-05:00 02:30-05:00 05:00 05:00-06:00 05:00-06:00 06:00-08:00 06:00-08:00 08:00 08:00-10:30 08:00-10:30 10:30 Duration 3/4 hr 1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr lhr lhr 2hr 2 hr 2-1/2 hr 2-1/2 hr Activity Tested Permanent packer - Via annulus Pressure test completed successfully - 3000.000 psi Bleed tubing to 2000 psi. Test annulus and packer to 3000 psi. 7 bbls pumped- Good Test for 30 minutes. Rigged down Completion string handling equipment Equipment work completed Shear RP valve. L/D landing joint and clear rigfloor. Set BPV and test to 500 psi from below. BOP/riser operations - BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Install Adaptor Flange and tree. Test same to 5000 psi- good. R/U DSM and pull BPV. Fluid system Freeze protect well - 155.000 bbl of Diesel Fluid system (cont...) Freeze protect well - 150.000 bbl of Diesel Completed operations Freeze Protect well down to 2200 ft. Allow to U-tube. Install BPV and test from below to 500 psi. Move rig Rigged down Fluid system Equipment work completed Remove secondary valve while offloading last of fluids from pits. ( Some trucking dealys due to field wide power disruption- injection fluids going to Kuparuk. Rig Released @ 1030 hrs 11/20/1999 North Slope Alaska Alaska State Plane 4 PBU, EOA DS 05 05-16B Surveyed: 14 November, 1999 SURVEY REPORT ORIGINAL 27 December, 1999 Your Ref: AP1-500292026202 Surface Coordinates: 5949530.13 N, 697091.68 E (70° 15' 58.6470" N, 148° 24' 22.4616" W) Kelly Bushing: 65.0Oft above Mean Sea Level O,,Iq i L'I.. i N Gl RECEIVED ~.~ 04 ~000 An~oracj~ Survey Ref: sv¥9525 Sperry-Sun Drilling Services Survey Report for 05-16B Your Ref: API-500292026202 Surveyed: 14 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9996,00 50.830 357,598 7722.10 7787.10 10039.00 50.830 357.550 7749.26 7814.26 10096.20 49.720 356.100 7785.82 7850.82 10124,10 48.220 355.340 7804.13 7869.13 10158.00 45.870 354.360 7827.23 7892.23 10191.50 43.360 353.330 7851.08 7916.08 10221,90 40,920 352,330 7873,62 7938.62 10253.70 39.100 351.220 7897,97 7962.97 10285.10 38.820 351.290 7922.39 7987.39 10313.60 38.810 351.070 7944,60 8009.60 10408.00 37.930 352.410 8018,61 8083.61 10504.20 36,940 355.380 8095.00 8160.00 10579.10 35.780 358.110 8155.32 8220.32 10650.90 36.320 358.250 8213.37 8278.37 10697.00 38.600 356.500 8249.96 8314.96 10791.60 37.660 354.700 8324.38 8389.38 10886.10 37.820 352.280 8399.11 8464,11 10979,00 43.640 349.900 8469.49 8534.49 11043,20 44,410 349.200 8515,65 8580,65 11072.60 44.120 349.070 8536.70 8601.70 11101.60 45.810 350.260 8557.22 8622.22 11129.90 49.690 353.080 8576.25 8641.25 11164.20 56,130 355.370 8596.92 8661.92 11197.90 61,930 358.120 8614.26 8679.26 11227.50 65.370 358,720 8627.40 8692.40 4723.69 N 1130.78W 5954222.60 N 695837,62 E 4757,00 N 1132.19W 5954255.86 N 695835.34 E 4800.92 N 1134.62W 5954299.70 N 695831.75 E 4821.91 N 1136.19W 5954320.64 N 695829.64 E 4846.62 N 1138.42W 5954345.28 N 695826.77 E 4870.01 N 1140.93W 5954368.60 N 695823.64 E 4890,25 N 1143.47W 5954388.76 N 695820,57 E 4910.48 N 1146.40W 5954408.91N 695817.12 E 4929.99 N 1149.40W 5954428.34 N 695813.61 E 4947.65 N 1152.14W 5954445.92 N 695810.41 E 5005.63 N 1160.56W 5954503.66 N 695800.47 E' 5063.76 N 1166.80W 5954561.61 N 695792.71 E 5108.08 N 1169.33W 5954605.85 N 695789,02 E 5150.31N 1170.67W 5954648.03 N 695786.57 E 5178.32 N 1171,97W 5954675.99 N 695784.54 E 5236.55 N 1176,44W 5954734.09 N 695778.55 E 5294.01 N 1183,00W 5954791.35 N 695770.49 E 5353.85 N 1192,45W 5954850.92 N 695759.47 E 5397.72 N 1200.55W 5954894.57 N 695750.23 E 5417.88 N 1204.42W 5954914.62 N 695745.83 E 5438.04 N 1208.09W 5954934.67 N 695741.63 E 5458.76 N 1211.11W 5954955.31 N 695738.07 E 5485.96 N 1213.84W 5954982.44 N 695734.63 E 5514.80 N 1215.45W 5955011.22 N 695732.26 E 5541.31N 1216.18W 5955037,70 N 695730.84 E Alaska State Plane 4 PBU_EOA DS 05 Dogleg Vertical Rate Section (°llOOft) (ft) 4728,42 0.086 4758.81 2.751 4799.15 5.756 4818.60 7.248 4841.68 7.797 4863.71 8.324 4882.93 6.147 4902,32 0.903 4921,11 0.485 4938,11 1.283 4993.70 2.140 5048.44 2.658 5089.18 0.761 5127.52 5.458 5153.12 1.539 5207.16 1.576 5261.44 6.483 5319.16 1,419 5361.99 1.034 5381.74 6.509 5401.40 15.566 5421.27 19.514 5446.80 18.576 5473.29 11.763 5497.31 Comment Tie-on Survey Widow Point 27 December, 1999- 18:34 -2- RECEIVED Continued.., DrlllQuest 1.05.04e Alaka Oil & Gas Coas. Commission Sperry-Sun Drilling Services Survey Report for 05-16B Your Ref: API-500292026202 Surveyed: 14 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 11258.00 67.620 358,420 8639.56 8704.56 11291.70 71.190 359.250 8651.41 8716.41 11324.20 76.620 0.480 8660.42 8725.42 11352.00 82,650 0,110 8665.42 8730.42 11384.60 84.580 359.250 8669.04 8734.04 11445.90 85.290 359.890 8674.46 8739.46 11478.20 85.110 359.950 8677.16 8742.16 11537.90 83.930 358.480 8682.86 8747.86 11570.50 81.940 358.010 8686.87 8751.87 11631.50 82,620 357.290 8695.06 8760.06 11724,60 83,560 355,920 8706.26 8771.26 11756.10 83.930 353.210 8709.70 8774.70 11787.00 83,260 348.850 8713.15 8778.15 11814,80 85.010 343.940 8715.99 8780.99 11848.20 89,520 342.150 8717.58 8782.58 11876.80 89,050 339,530 8717,94 8782.94 11906.90 88.150 339,700 8718.67 8783.67 11939.60 85,630 337,510 8720.45 8785,45 11971.20 83,960 335.100 8723.32 8788,32 12001.30 84.240 333.170 8726.41 8791,41 12032.20 86.370 327,740 8728.94 8793.94 12064.20 87,490 324.360 8730.66 8795.66 12095.40 87.880 321.800 8731.92 8796.92 12125.70 88.020 317.310 8733.00 8798.00 12158.90 88,250 313.150 8734.08 8799.08 Alaska State Plane 4 PBU_EOA DS 05 27 December, 1999 - 18:34 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) ..... (°/lOOft) (ft) Comment 5569.27 N 1216,88W 5600.80 N 1217.52W 5632.02 N 1217.59W 5659.35 N 1217.45W 5691.74 N 1217.63W 5752.80 N 1218.09W 5784.99 N 1218.13W 5844,41N 1218.95W 5876.74 N 1219.94W 5937.14 N 1222.42W 6029,40 N 1227.89W 6060.57 N 1230.86W 6090.89 N 1235,64W 6117.76 N 1242,15W 6149.66 N 1251.87W 6176,67 N 1261,26W 6204.88 N 1271.74W 6235.28 N 1283.65W 6264.09 N 1296.29W 6291.03 N 1309.36W 6317.81N 1324,54W 6344.31 N 1342.38W 6369.23 N 1361.10W 6392.27 N 1380.74W 6415.82 N 1404.11W 5955065.63 N 695729.41 E 7.432 5522.60 5955097,14 N ,695727.94 E 10.841 5551.07 5955128.34 N 695727.06 E 17,098 5578.99 5955155.67 N 695726.48 E 21.730 5603.35 5955188.04 N 695725.45 E 6.475 5632.37 5955249,07 N 695723.40 E 1.557 5687.13 5955281.24 N 695722.51 E 0.587 5715.91 5955340.62 N 695720.14 E 3.149 5769.37 5955372.92 N 695718.30 E 6.270 5798.71 5955433.23 N 695714.24 E 1.616 5853.78 5955525.31 N 695706.36 E 1.776 5938.67 5955556.39 N 695702.58 E 8.632 5967.86 5955586,58 N 695697.00 E 14.188 5997.10 5955613.27 N 695689.79 E 18.662 6024.03 5955644.91 N 695679.23 E 14.525 6056.90 5955671.66 N 695669.14 E 9.306 6085,25 5955699.59 N 695657.93 E 3.043 6115.16 5955729.66 N 695645.23 E 10.203 6147.67 5955758.13 N 695631,83 E 9.253 6179.09 5955784.72 N 695618.07 E 6.445 6209.03 5955811.10 N 695602.19 E 18.821 6239.77 5955837.12 N 695583.66 E 11.113 6271.46 5955861.54 N 695564.29 E 8.293 6302.14 5955884,06 N 695544.06 E 14.816 6331.54 5955906.99 N 695520,08 E 12,543 6363.08 RECEIVED 04 ?.000 -3- Continued.., C s. Co bn r ttO ,o, ~or'~ Sperry-Sun Drilling Services Survey Report for 05-16B Your Ref: API-500292026202 Surveyed: 14 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 12188.00 91.660 310.950 8734.10 12214.00 92.800 309,820 8733.09 12248.90 93.130 309,550 8731.29 12278.20 93.570 308,670 8729.57 12307,30 92.210 304,830 8728.11 12338.50 89.960 302,680 8727.52 12372,60 89.600 301,100 8727.65 12401.00 90.000 298.240 8727.75 12432.80 90.480 295.280 8727.61 12461.90 89.070 292.990 8727.73 12495.00 90.340 289,200 8727.90 12527.90 92.690 287.000 8727.03 12561,90 92.780 285.940 8725,41 12587.80 91.480 282.320 8724.44 12621,80 90.130 279.250 8723,96 12653.50 89.320 275.440 8724.12 12681~30 88.680 273.360 8724,60 12712,70 88,280 272.900 8725,44 12743,30 87.780 272.050 8726.49 12775,70 87,450 268.720 8727.84 12811,20 86,640 265.830 8729,67 12841,60 87.480 265,080 8731,23 12869,30 88.000 264.420 8732,32 12904,50 91.200 264.760 8732.56 12933,70 92.520 265.360 8731.62 27 December, 1999 - 18:34 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8799,10 6435.31N 1425.71W 5955925,91N 695497.98 E 8798.09 6452.14 N 1445.50W 5955942.22 N 695477.76 E 8796.29 6474,40 N 1472.32W 5955963.76 N 695450,36 E 8794.57 6492.85 N 1495.02W 5955981.61 N 695427.19 E 8793.11 6510.23 N 1518.30W 5955998.38 N 695403.46 E 8792.52 6527.56 N 1544.23W 5956015.03 N 695377,08 E 8792.65 6545.58 N 1573.18W 5956032.28 N 695347.67 E 8792.75 6559.63 N 1597.86W 5956045,68 N 695322.63 E 8792.61 6573.95 N 1626.25W 5956059.25 N 695293.88 E 8792.73 6585.85 N 1652.80W 5956070.45 N 695267.02 E 8792.90 6597.76 N 1683.68W 5956081.55 N 695235.85 E 8792.03 6607.98 N 1714.93W 5956090.94 N 695204,3,3 E 8790.41 6617.60 N 1747,50W 5956099.72 N 695171.53 E 8789.44 6623.92 N 1772.60W 5956105.37 N 695146.27 E 8788.96 6630.28 N 1805.99W 5956110.86 N 695112.73 E 8789.12 6634.33 N 1837.42W 5956114.08 N 695081,20 E 8789.60 6636.47 N 1865.13W 5956115.49 N 695053.44 E 8790.44 6638.18 N 1896.47W 5956116.38 N 695022,06 E 8791,49 6639.50 N 1927.03W 5956116.90 N 694991.49 E 8792.84 6639.72 N 1959.39W 5956116.27 N 694959.13 E 8794.67 6638.03 N 1994.80W 5956113.66 N 694923,77 E 8796.23 6635.63 N 2025.07W 5956110.47 N 694893.58 E 8797.32 6633.09 N 2052.63W 5956107.21 N 694866.10 E 8797.56 6629.78 N 2087.67W 5956102.98 N 694831,16 E 8796.62 6627.26 N 2116.74W 5956099,70 N 694802.16 E Alaska State Plane 4 PBU_EOA DS 05 Dogleg Vertical Rate Section (°/lOOft) (fi) 13,945 6390.19 6,171 6414,12 1.221 6446.05 3.353 6472.72 13.983 6498.71 9.973 6525.84 4.752 6554.94 10.168 6578.58 9.430 6604.12 9.241 6626.68 12.076 6651.18 9.783 6674.35 3.125 6697.57 14.841 6714.49 9.863 6735.17 12,287 6752.90 7,827 6767.25 1,941 6782,86 3,221 6797.76 10,319 6812.49 8,444 6826.88 3,702 6838.32 3,032 6848.44 9,142 6861.20 4.965 6872.02 Comment RECEIVED -4- Sperry-Sun Drilling Services Survey Report for 05-16B Your Ref: AP1-500292026202 Surveyed: 14 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 12965.20 92.710 265.830 8730.18 8795.18 12997.00 90.490 266.230 8729.29 8794.29 13031.70 89.940 266.640 8729.16 8794.16 13057.80 90.030 266.460 8729.17 8794,17 13088.80 90.490 267.960 8729.03 8794.03 13120,50 90.800 267.030 8728.67 8793.67 13151,10 90.920 266.860 8728.21 8793.21 13182.60 91.010 267.100 8727.68 8792.68 13213.70 90.520 266.050 8727.26 8792.26 13244.30 91.350 265,390 8726.77 8791.77 13275.20 90,920 265.640 8726.15 8791.15 13306,30 91.480 266.830 8725.50 8790.50 13337.70 90.250 267.470 8725.03 8790.03 13368.90 90.180 268.150 8724.91 8789,91 13400.30 90.400 269.070 8724.75 8789.75 13431.80 88.460 269.550 8725,07 8790.07 13462.30 87.880 269.950 8726.04 8791.04 13497.50 89.350 269.880 8726.89 8791.89 13524.90 90.180 271.000 8727.00 8792.00 13556.10 89.570 272.530 8727.07 8792.07 13588.40 88.630 271.670 8727.58 8792.58 13617.80 87.720 271.360 8728,51 8793.51 13650,60 86,520 268.850 8730.16 8795.16 13684.70 87.690 269.070 8731,88 8796.88 13713.20 88.800 269.700 8732.76 8797.76 Alaska State Plane 4 PBU_EOA DS 05 27 December, 1999- 18:34 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Vertical Rate Section (°ll00ft) (ft) Comment 6624.85 N 2148.12W 5956096.47 N 694770.86 E 6622.65 N 2179.83W 5956093.44 N 694739.22 E 6620.49 N 2214.46W 5956090.37 N 694704.65 E 6618.92 N 2240.51W 5956088.12 N 694678.65 E 6617.41 N 2271.47W 5956085.80 N 694647.74 E 6616.02 N 2303.14W 5956083.59 N 694616.12 E 6614.39 N 2333.69W 5956081.16 N 694585.62 E 6612.73 N 2365.14W 5956078.68 N 694554.22 E 6610.88 N 2396.19W 5956076.01N 694523.24 E 6608.59 N 2426.70W 5956072.92 N 694492,80 E 6606.18 N 2457.50W 5956069.70 N 694462,07 E 6604.13 N 2488.52W 5956066.85 N 694431,11E 6602.57 N 2519.88W 5956064.47 N 694399.81 E 6601,38 N 2551.05W 5956062.46 N 694368.67 E 6600.62 N 2582.44W 5956060,88 N 694337.31 E 6600.24 N 2613,94W 5956059.67 N 694305.84 E 6600.11 N 2644.42W 5956058.74 N 694275.37 E 6600,05 N 2679.61W 5956057.77 N 694240.19 E 6600.27 N 2707.01W 5956057.26 N 694212.80 E 6601.23 N 2738.19W 5956057.41 N 694181.60 E 6602,41N 2770.47W 5956057.74 N 694149.31E 6603.19 N 2799.84W 5956057.75 N 694119.92 E 6603,25 N 2832.60W 5956056,95 N 694087.18 E 6602.63 N 2866,65W 5956055.45 N 694053.15 E 6602.32 N 2895,13W 5956054.39 N 694024.69 E 1.608 6883.94 7.093 6896.22 1.977 6909.84 0.771 6920.14 5.061 6932.69 3,092 6945.68 0.680 6957.94 0,814 6970.58 3,725 6982.86 3.465 6994.52 1.610 7006.19 4.228 7018.30 4.416 7030.99 2.191 7043.92 3.013 7057.34 6.344 7071,14 2.310 7084.71 4.181 7100.47 5.088 7112.96 5.279 7127.82 3.944 7143,37 3.270 7157.26 8.473 7172.02 3.491 7186.76 4.478 7199.27 RECEIVED ~,-.,.! 04 20~ Continued,.. -5- Sperry-Sun Drilling Services Survey Report for 05-16B Your Ref'. API-500292026202 Surveyed: 14 November, 1999 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl, Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 13743.10 89.320 269.910 8733.25 8798.25 6602.22 N 2925.03 W 13774.70 89.690 269,730 8733.52 8798.52 6602.12 N 2956.63 W 13807.90 89.780 271.040 8733.67 8798.67 6602.35 N 2989.82 W 13855.20 91,480 268,880 8733.15 8798.15 6602.31 N 3037.12 W 13899.70 91.510 271,010 8731.99 8796.99 6602.27 N 3081.60 W 13944.60 90.710 269.300 8731.12 8796.12 6602.39 N 3126.49 W 13993.80 90.920 269.330 8730.42 8795.42 6601.80 N 3175,68 W 14074.80 90.060 269.030 8729.73 8794.73 6600.64 N 3256.67 W 14135.00 90.060 269.030 8729.67 8794.67 6599.62 N 3316.86 W 5956053.51N 693994.80 E 5956052.58 N 693963,22 E 5956051.94 N 693930,03 E 5956050.67 N 693882.75 E 5956049.46 N 693838.29 E 5956048.40 N 693793.41 E 5956046.53 N 693744.25 E 5956043.25 N 693663.32 E 5956040.66 N 693603.18 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference, Magnetic Declination at Surface is 27.439° (01-Nov-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 333.317° (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 14135.00ft., The Bottom Hole Displacement is 7386,24ft., in the Direction of 333.317° (True). Dogleg Rate (°/100ft) 1.876 1.302 3.955 5.811 4.785 4.204 0.431 1.124 0.000 Alaska State Plane 4 PBU_EOA DS 05 Vertical Section (ft) Comment 7212,61 7226.71 7241.82 7263.02 7282.96 7303,23 7324,79 7360.13 7386.24 Projected Survey 27 December, 1999 - 18:34 - 6 - RECEIVED ~0tl&G~ C~s.~miss'~n Continued... DrillQuest 1.05.04e TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: f907) 279-1433 FAX: 907) 276-7542 October 13. 1999 Anthony Bunch Drilling Superintendent ARCO Alaska. Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 05-16B Permit No: 99-100 ARCO Alaska. Inc.: Sur Loc: 3367'NSL. 38'EWL. Sec. 32. T1 IN. R15E. UM Btmhole Loc. 4645'NSL 3260'WEL. Sec. 30, T11N, R15E. UM Dear Mr. Bunch: Enclosed is the approved application for permit to redrill 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 max' be given by contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosurcs CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o enci. ...... STATE OF ALASKA ALASKA ,_ .,_ AND GAS CONSERVATION COM PERMIT TO DRILL 20 AAC 25.005 .tSSION t~h,-%% la. Type of work l--I Drill [~Redrill Ilb. Typeofwell F-IExploratory I-'lStratigraphicTest [~ Development Oil [] Re-Entn/ [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 15. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 63' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation . Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028326 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3367' NSL, 38' EWL, SEC. 32, T11N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 4477' nsl, 1281' wel, SEC. 30, T11N, R15E, UM 05-16B At total depth 9. Approximate spud date Amount $200,000.00 4645' NSL, 3260' WEL, SEC. 30, T11 N, R15E, UM 10/15/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD~ TVD).¢ ADL 028321, 634' MDI No Close Approach 2560 14020' MD/.8,7"5~' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} '~ ~" Kick Off Depth 10075' MD Maximum Hole Angle 92° Maximum surface 2670 psig, At total depth (TVD) 8800' / 3550 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 1085' 9925' 7677' 11010' 8263' 242 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3170' 10860' 8245' 14020' 8735' 409 sx Class 'G' 19. To be completed for Reddll, Re-entry, an0 Deepen Operations. " ' Present well condition summary Total 0epth: measured 12234 feet Plugs (measured) '~ ~ :!~i~ ~', ~: true vertical 8807 feet Effective depth: measured 12131 feet Junk (measured) ~ , , r,.i~ " ' . &!as.~a ~ii & ~as C0~,s. true vertical 8808 feet Anchorage Casing Length Size Cemented MD TVD Structural Conductor 116' 20" 248 sx PF 116' 116' Surface 2723' 13-3/8" 5950 sx PF II 2723' 2723' Intermediate 10480' 9-5/8" 700 sx Class 'G', 300 sx PF 10480' 8096' Production 1334' 7" 400 sx Class 'G' 10180' - 11514' 7905' - 8765' Liner 2030' 2-7/8" 184 sx Class 'G' 10195' - 12225' 7914' - 8786' ,erforationdepth: measured 11645'-11821', 11903'-12080' ORIGINAL true vertical 8801' - 8790', 8786' - 8785' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: lames Smith, 564-5026 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify t~orrect to the be, s~.of_my k. now~.,,dge ,.. ~. Signed Dan Stone "~ 'f % N I~~ i4t~Olla Title Scnlor Dr?,;;,-~9 E,'~inccr- Date \ Commission Use Only 7~ [ APl Number I ApprovalDate I See cover letter Permit Num -'/~) 50-029-20262-02 z/ ~)'"'/'¢'~ "~' for other requirements Conditions of Approval: Samples Required []_Yes ~'"~o Mud Log Required []Yes ,~o Hydrogen Sulfide Measures l~Yes []No Directional Survey Required ~'Yes []No Required Working Pressure for DOPE I-I2K; ~[3K; 1--14K; 1--15K; [-I 10K; I-'115K Other: ORIGINAL SIGNED BY by order of Approved By Robert N Christen$0n Commissioner the commission Date/'¢ Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IDs 5-16B Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: 3367'FSL, 38'FWL, Sec. 32, TI IN, R15E Target Start: 4477'FSL, 1281'FEL Sec. 30, T11N, R15E X=695583 Y=5955883 Z=8750'TVDss Total Depth 4645'FSL, 3260'FEL, Sec. 30, T1 IN, R15E X=693600 Y=5956000 Z= 8735' TVDss I AFE Number: 14J0426 I IEstimated Start Date: [ 10/15/99 ]Rig: I Nabors 9ES Operating days to complete: I MD I 14020' I TVDss: 18735' I 29 [KBE: 163' I Well Design (conv., slim hole, etc.): I Horizontal USH Sidetrack w/drlg liner Objective: Rig will sidetrack out of existing 9-5/8 in Kingak formation, directionally drill 8-1/2" hole to top Sag River, run and cement 7" drlg liner, drill out in 6-1/8" hole and thru (1) Z1 target, TD at 14020' MD. Run, cmt and test 4 1/2" L80 solid liner, perf, and complete with 4 ½", L80 tbg, (3) GLM's and EOA tail assy. Formation Markers Formation Tops MD TVD(ss) K-5 7634 KOP 10075 7773 LCU 10740 8111 Kingak JB Fault in Kingak Sag River 10997 8255 7" drilling liner 11010 8263 Set 7" just in top of Sag River Shublik 11065 8295 Top Sad 11159 8350 Zone 4A 11227 8390 Zone 3 11312 8440 Zone 2 11397 8490 Zone 1 11714 8675 Target 1 12258 8745 Geological Target #1 TD 14020 8735 Run and cmt 4-1/2 prod liner at TD Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MDfrVD MDfrVD O.D. 8-1/2" 7" 26# L-80 BTCM 1085' 9925'/7677' 11010'/8263' 6-1/8" 4 1/2" 12.6# L-80 IBT 3170' 10860'/8245' 14020'/8735' liner Mod Tubing 4-½" 12.6# L-80 IBT 10830' 30'/30' 10860'/8245' Mod Logging Program: I Open Hole Logs: [Cased Hole Logs 9ES Drilling section: MWD/GR from KOP 10075') to 8-1/2" hole TD at 11010'. MWD/GR/PWD in 6-1/8" hole from 7" liner to first bit trip, add CNL on to TD at 14030'MD MADD pass as per Geologist request. Sample catchers and rig site geologist on site before TD of 8-1/2" hole. Open Hole: DPC Log only if LWD logs of poor quality. Post Rig CBL on production liner Mud Program: Special design considerations Drill from KOP to TD of 8-1/2" with Baroid LSND mud. Drill 6-1/8" hole with QuikdrilN Lite Polymer system. Density LSRV PV YP Ca++ pH (ppg) (cps) 10.6 LSND 10 15 -. 10.8 LSND 12 15 8.3 < 12000 5- 8 20-25 < 100 9.0- 9.5 to to to ... 8.5+ < 12000 5-8 20-25 < 100 9.0-9.5 Directional: KOP: 1) 10075' MD, drill out of 9-5/8 "casing via whipstock window, drop and turn to 55° angle and 356° azimuth, hold to 8-1/2" TD at Sag River ('MD) 2) In 6-1/8" interval build and turn angle at °/100' through targets, TD of interval is at 14020'MD, 8735'TVDss Maximum Hole 92°after reaching low point and inverting Angle: Surface Shut-in No wells will need to be shut-in and de-pressurized before rig moves on and off of the well. Close Approach There no close approach wells to this wellbore identified. Well: Point to point separation Cement Data: '~asing/Liner Lead: Tail: Sxs/Wt~ield Comments Sxs/Wt/Yield P&A Cmt 55/15.8/1.16 cement to cover from 50' below bottom perf to approx. 1300' above top perf in 2-7/8" liner 7", 2655, L-80 Liner 242/15.8/1.16 All Tail w/50% excess, TOC at liner top 4-1/2", 12.6#, L-80 409/15.8/1.16 Class "G",50% excess liner Shoe at 14020' OH + 200' above liner MD Liner top top w/DP in hole @ 10860'MD Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter and B OPE system schematics on file with AOGCC. Bottom hole pressure is 3550 psi at 8,800' TVDss, Is 7.7 ppg EMW Maximum shut-in casing pressure is 2670 psi (assumes 0.1 psi/ft gas gradient to surface). Planned BOPE test pressure is 3,000 psi on the DS 5-16B sidetrack NO ANNULAR INJECTION IN THIS WELL. DS 5-16B Class II drilling wastes will be disposed at DS4 grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. Name Jim Smith Tony Bunch Dick Owens Scot Rohleder Drilling Eng. Drilling Supt. Geologist Pad Engr Contacts Office Home Pager 564 5026 345 8660 275-4015 564 5219 348 6683 275-3703 263-4982 345 7781 263-4338 245-5051 275-4752 Drilling Discussion Well Objective The proposed horizontal sidetrack will target a 2000' horizontal section in Zone 1. DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There are no adjacent wells which will require shut in for rig move in or move out. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move per ASH procedures. DRILLING CLOSE APPROACH WELL SHUT-INS No shut-ins identified on directional well plan Wp #7 due to close approach requirements. PORE PRESSURE: The pore pressure in Colville/Kingak interval of the 8-1/2" hole section is expected to be near 9.9 ppg, a 10.6 ppg system will be used to drill the interval to combat shale instability. The pore pressure in Zone 1 (in 6-1/8" interval) is expected to be near 7.7 ppg EMW. 8.4 - 8.6 ppg mud will be used drilling Zone 1. The overlying Sag River and Shublik formations should be at similar pressure, the 8.4-8.6 ppg mud will provide sufficient overbalance to the reservoir pressure. HOLE PROBLEMS No major hole problems are expected. Shale drilling practices will be employed due to the 8-1/2" hole section at high angle (about 60 degrees) through shales. H_2_.S' DS 5 is not an H2S Pad The highest reported level of H2S on DS 5 is 22ppm or lower based on data through 1996. There have been incidents of H2S on other pads which involved circulation of annular fluids from the wellbore. H2S precautions will be in effect at all times. These include (but are not limited to): · Regular H2S drills (minimum of two per week) · Proper training of all permanent onsite personnel, unescorted visitors and temporary onsite personnel; · H2S monitors with both audible and visual alarms; · Access to 5-minute emergency escape air packs; · Personal H2S monitors; · Functional wind indicator; · Posted evacuation routes (minimum of two); · Muster points in designated safe areas;H_H_a_S; · Functional communications between rig camp and rig floor. Casing Shoe Kick Tolerance The smallest kick tolerance for the 8-1/2" hole interval below 9-5/8" casing (at the KOP of is calculated as 13.2 bbl assuming a swabbed gas influx from the Sag River at a depth of 11010'MD with 10.8 ppg mud in the hole and 10.1ppg pore pressure in the Sag River. Expected pore pressure in the Sag is much lower. The smallest kick tolerance for the 6-1/8" interval drilled below 7" casing at is calculated as infinite influx assuming a swabbed gas influx from Z1 along the planned directional path. Based on 8.4 ppg MW (8.0 ppg reservoir pore pressure), and min. frac at 7" shoe of 12.0 ppg. Well Overview and Program: The sidetrack (5-16B) is intended to access additional reserves utilizing a horizontal well path in the Ivishak Zone 1. Nabors 9ES is expected to move to 5-16B on/about October 15, 1999 after completing the 2-27A sidetrack. The drilling objective of 5-16B is to pull the existing 2-3/8" scab coil tubing and 4 1/2" tubing, place a bridge plug below the anticipated kick off depth of 10075'MD in the 9-5/8" casing, set a whipstock and mill through 9-5/8" casing, then directionally drill to the top of the Sag River where a 7" drilling liner will be set and cemented to TOL. The well will be extended in 6-1/8" hole size to access the Zone 1 Ivishak target. At TD a 4- 1/2" L-80 production liner will be run and cemented and the well completed with 4-1/2" L80 IBT-Mod production tubing. The objective of the pre-rig work is to fish the POGLM from 3506', test wellhead packoff systems, P&A the CTD sidetrack and cut 2-3/8" coil liner and prepare the pad for rig arrival. Pre-Rig Operations: 1. Test the 9-5/8" and tubing hanger packoffs on the FMC Gen I wellhead to 5000 psi. Cycle Iockdown screws (one at a time) and identify any that are broken or damaged. 2. Fish and remove the 4-1/2" POGLM that is located at 3506'-3516'. There are perforations in the 4-1/2" tubing behind the POGLM. 3. RIH with coil to P&A the existing CTD sidetrack completion. Place an IBP at 10200', sting in and P&A perfs. Plan to pump 11.2 bbl (63 ft3) of class A cement at 15.8 ppg to P&A the perfs from 11,535' to 12,080'. Bottom of the plug should be at 12,130'MD and top of plug at 10,200' at the conclusion of placement. Tag and test P&A per AOGCC requirements. 4. Cut the 2-3/8" 6.5#, L-80 tubing at 10150' (below the 9-5/8" packer). 5. Circulate the well to seawater from the tubing cut point and freeze protect the well. Set BPV. Remove wellhouse, clear and level the pad. 6. Prepare final costs for delivery to the company representative on Nabors 9ES Rig Sidetrack Procedure ]. MIRU. ND tree, NU and test BOPE. Circulate well clean and recover freeze protection fluid. 2. PU 2-3/8" HT drillpipe and fishing tools to fish and remove the 2-3/8" coil tubing scab from 3519' to 10150' at the pre-rig cut. 3. LD 2-3/8" DP after recovery of scab coil tubing. 4. RU wireline and cut the 4-1/2" tubing at 10110' (just above the Baker PBR assembly) 5. Pull and LD 4-1/2" tubing. The tubing is expected to be junk. 6. RIH and set EZSV on wireline at approx. 10110'. Test casing to 3000 psi for 30 minutes (9-5/8" has passed a casing test to 2500 psi in August 1998). ?. PU whipstock, bottom trip on EZSV and mill window for KOP at +/- 10090'MD. 8. Drill approx. 750' in 8-1/2" hole to the top of the Sag River (+/-10823'MD) 9. Run and cement 7" 26#, L80 drilling liner to TD, TOL at 150' above KOP. TOC at TOL. 10. PU 6-1/8" directional assy, RIH, test casing to 3000 psi, drill out, obtain FIT, displace to drill in fluid. l l. Build angle and turn well along directional path. Drill to TD at +/-14026'MD/8798'TVD. 12. Run and cement 4-1/2" 12.6#, L80 production liner. TOL to be 150' above 7" shoe. 13. DPC perorate approx. 1000' of the production liner. 14. Run 4-1/2", 12.6#, L80 production tubing, stab WLEG into production liner top. 15. Set packer and pressure test completion to 3000 psi. 16. ND BOPs/NU and test tree. Freeze protect to 2000'. l?. Release Rig. Prepared by: Jim Smith, ODE FMC ELLHEAD: FMC Gen I 13 3/8", 72 #/ft, 12723' I~ N-80, BTRS IKOP: 2700' MAX ANGLE: 53.5° @ 6900' 4 1/2/",12.6#/FT, L-80. IBT Mod TUBING Orig KB. ELEV = 69' 41/2" LANDING N~PPLE I 2200'] GAS LIFT MANDRELS N° MD/BKB/ TVDss 3 2 1 7" X 9-5/8" liner hanger at 9925' 9-5/8" Whipstock at 10075', bottom trip on bridge plug @ 10100' 9-5/8 X 4-1/2" packer @ 10126' 2-3/8" scab tieback cut at 10150', to be removed above top OF I 10180' 7" LINER 95/8", 47#/ft, I 10480' L-80, BTRS CTD liner 2-7/8" 6.5# from 10195-12131'. PBTD for CTD I 12131' sidetrack CTD TD at 12234' 7" 26# L80 BTCM. TOL at 9925', shoe 11010' in top Sag River 7" X 4-1/2" Baker SB3 prod. packer at 10,810' 4 1/2" XN NIPPLE @ 10840' WLEG stabbed into 4-1/2" liner at 10860' 4 1/2" 12.6# L80 IBTMod production liner, solid cemented. TOL at 10,860', shoe at 14,020' Original 4-1/2" tubing tail at 10235' P&A of 05-16A by Coil with 11 bbl (63 ft3) of class G cmt at 15.8 ppg below IBP placed at 10200'MD. TOC at 10200', bottom at 12,130' CTD sidetrack KOP at 11483'MD, top perf at 11,535', bottom perf at 12,080'MD DATE REV. BY COMMENTS 9/20/99 JES Proposed P&A and sidetrack PRUDHOE BAY UNIT WELL: DS 5-16B APl NO: 50-029-20262-xx SEC 32; TN 11N; RGE 15E BP Exploration (Alaska) I DrillQuest Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 05 05-16B Current Well Properties we,: -- ~.~T-- Horizontal Coordinates: Re[. Global Coordinates: 5949530.13 N, 897091.68 E Ret. Structure Reference: 2334.25 N, 278.71 W Ret Geographical Coordinates: 70" 15' 58.6470' N, 148" 24' 22.4~16' W RKB Elevation: 83.1011 above Mean Sea Level 63.1 Oft above Structure Reference North Reference; Tn.la North Un ts: Fee Proposal Data for 05-16B Wp7 Vertical Origin: Well Horizontal Odgfn: Well Measurement Unite: ft North Referenee: True North Dogleg leVlrity: Degrees per lOOft Vertical Section Azimuth: 301,310" Vertical Section Deecrlptlon: Wall Vertical Section Origin: 0.00 N,O.O0 E Measuredlncl. Aztm. VerticalNorthlnga Eaetlnga Vertical Dogleg Depth Depth SectionRate I(X175.1X) 50.830 357.5177836.30 4786,35 N t 133.46 W 3455.711 10176.~X) 61.1X81 356.7511 7893.33 4870.52 N I 137.70 W 3503.08IO.(XX) ]0426.~) 61,(XX) 356,7508014.53 5¢188.~3 N11 .~0.10 w 3627.1 I 10793.43 57.065 355.73282113.1115402.37 N 1170.64 W 3~07.60 IA(X) 109~.~.~ I ,~,4,062 355,0711 8318.10 5569.55 N1184.06 W 3905.951,5181 116~3.29 ~.062355.O788721,OO 6123.31 N1231,75 W 42.t4.46 119tX}.21 91.100 323.(X)O 8813.50 6384.84 N1341.1 ] W 4463.80 12257.tiO gl.121 2K3.6548~O8.10 652~.06 N1560.28 W 4725,9514.7OI 12.150.96 ~)<).31)3 270.637#806.O4 6540.52 N1652.51 W 4810,7514.(~8) 14019.67 90,303 270.6378791L11} 6559.(}7 N 3321.10 W 6245.t)8 O.(}<X) 8000 - 8400 - II · . 8800 - -- ........................... o. .... ! ...... ' ................................................................................. . ........ ' ........ ~ ................................................ K.5. 7697.10 TV/) N~:°~s\\°° ~ .500°1~00~ ~ ~0~93'~3~ ¢0' B~03'~0~0 ............................................... , .................................................................................................................................. LCU-8I~4./O~D ..... '~ · · · ' ....... · = · · ........................... TEAG. 8~/&/O ~D · Top Sadleroch it. 8413. I 0 ~D ................................................... ~,o~. ..................... :. ........... :a~ ............................................. ~' .8~03.10 ~D ........................ ~ ......... N ....................................... ~, ~" .......................... ~ ¢~E . ..~ .,~0~?) .................................................. ~2 SSSX. ~0 m~ ................................ .,esSO ~ ~&.7 .. oeC~e~%%~50.96% ~¢~ 05-tO~ ~o~ ~ ~ ¢~,~ 05-16B Wp¢~ Total Depth: 14019.67ft MD, 8798.10ff TVD I I I I I I I 3600 4000 4400 4800 5200 5600 6000 6400 Scale: linch = 40Oft Vertical Section Section Azimuth: 301.310° (True North) Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 05 05-16B Scale: linch = 400ft 6400 - 6000 - Z 5600 - 5200 - 4800- DrillQuest' Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ret. Structure Reference: Ref. Geographical Coordinates: RKB Eleva~on: North Reference: Units: 05-188 5949530,13 N, 897091,O8 E 2334,25 N, 278.71 W 70" 15' 58.6470" N, 14~" 24' 22.4~1a" W a3,1Oft above Mean Sea Level 83,10ft above Structure Relerence True North Feet -3200 -2800 -2400 Eastings -2000 -1600 :: : Proposal Data for 05-16B Wp7 Hoflzontel Origin: Measurement Unlt~: Norlh ReferenCe; Tree No.h D~I~ seved~: O~rees per l~ff Ve~oal S~ ~lmu~: 301.310" Ve~oal S~fl~ DeacHptl~: Well Ve~oal S~t~n Odgln: 0.~ N,O.~ E Mealumd Incl. A~ Vedlcll ~hlngl Eaatlngl Vertical Dogleg Depth Dep~ SectionRate 05.16B TD 19-7.991. Point 8798.10 TVD 6559.07 N, 3321.10 W I I -3200 -2800 Scale: linch = 40Oft , ia6o2.97 I -2400 5.16B Mtd Pt. POint ssos:~O:rvo 6528.96 N,:1~0.28 W 05.1 6B polygon. Start Dir @ 15~500°/100ft: 11683.29ft MD, 8721.00ft TVD End Dir: 10996.81ft MD, 8318.10ft TVD BHNFormation Trend @ 1.500°/100ft: 10793.43ft MD, 8203.1~ft WD BHNFormation Trend ~ 1.100°/100ff: 1~26.90ft MD, 8014.53ff WD ~ End Dir: 10176.90ft MD, 7893.33ft TVD ~ Tie-on, Start Dir @ 10,000°/100ft: 10075.00ft MD, 7836.30ft TVD ~ I I I -2000 -1600 -1200 Eastings t(X)75.(X) 50330357.5177836.30 4786,35 N 1133.46 W 3455,70 10176J~) 61,O(X) 356.7507893.33 4870.52 N 1137.70 W 3503.O8IO.OlX) I(N26JX} 61,0{X) 356.7508014,53 51)g~.~3 N1150.10W3627.11O.O(X) 10793.43 57,065 355.7328203,10 5402.37 N 1170,64 W 38O7.6O1.100 10996,81 54.062 355,117~ 8318.10 5569,55 N 11114,06 W 3005,~J5 11683.29 54.062 355,(}78 R721.(~1 6123,31 N 1231.75 W 4234,46().(EX) 11990,21 91.l(X) 323,(X}O 8813.50 6384.~4 N 1341.11 W 4463.8O15.500 12257.80 91.121 283,654l180g,lO 6528,96 N 1560.28 W 4725.9514.701 1235(},~ 90,303 270.6378806.94 6,~10.52 N1652.51 W 481(},75 14.000 14019.67 90.303 270,637879fL10 6559.07 N .1321.10 W 6245.98 -1200 -800 't. Point O5.16b fault cntrl#2 05-16b fault cntrl#1 - 6400 -- 6000 - 5600 I -800 Reference is True North 1::: o Z - 5200 = O II -- 4800 ~ Sperry-Sun Drifting Services Proposal Report for 05-16B Wp 7 Revised: 27 September, 1999 Prudhoe Bay Unit Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 10075.00 '50.830 357.517 7773.20 10100.00 53.325 357.311 7788.56 10176.90 61.000 356.750 7830.23 10200.00 61.000 356.750 7841.43 10300.00 61.000 356.750 7889.91 10400.00 61.000 356.750 7938.39 10426.90 61.000 356.750 7951.43 10500.00 60.214 356.553 7987.31 10600.00 59.140 356.280 8037.80 10700.00 58.067 355.999 8089.89 10739.67 57.641 355.887 8111.00 10793.43 57.065 355.732 8140.00 10800.00 56.967 355.711 8143.58 10900.00 55.491 355.395 8199.16 10996.81 54.062 355.078 8255.00 11000.00 54.062 355.078 8256.87 11010.00 54.062 355.078 8262.74 11064.96 54.062 355.078 8295.00 11100.00 54.062 355.078 8315.56 11158.67 54.062 355.078 8350.00 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 7836.30 4786.35 N 1133.46 W 7851.66 4806.05 N 1134.35W 7893.33 4870.52 N 1137.70W 7904.53 4890.70 N 1138.85W 7953.01 4978.02 N 1143.81W 8001.49 5065.34 N 1148.77W 8014,53 5088.83 N 1i50.10W 8050.41 5152.41N 1153.82W 8100.90 5238.56 N 1159.21W 8152.99 5323.72 N 1164.96W 8174.10 5357123N 1167.34W 8203.10 5402.37 N 1170.64W 8206.68 5407.87 N 1171.06W 8262.26 5490.74 N 1177.50W 8318.10 5569.55 N 1184.06W Global Coordinates Northings :';i: Ea~tings (ft) '(ft) 5954285.17N 695833.30 E 5954304.83N 695831.90E 5954369120 N 695826.85 E 5954389.33 N 695825.18 E 5954476.50 N 695817.94 E · 5954563.66 N 695810.69 E 5954587.10 N 695808.74 E 5954650.57 N 695803.36 E 5954736.55 N 695795.71 E 5954821.53 N 695787.74 E 5954854.96 N 695784.49 E 5954900.00 N 695780.00 E 5954905.49 N 695779.44 E 5954988.16 N 695770.83 E 5955066.77 N 695762.21E 8319.97 5572.13 N 1184.29W 5955069.34 N 695761.92 E 8325.84 5580.19 N 1184.98W 5955077.39 N 695761.01 E 8358.10 5624.53 N 1188.80W 5955121.61 N 695756.04 E 8378.66 5652.79 N 1191.23W 5955149.80 N 695752.86 E 8413.10 5700.12 N 1195.31W 5955197.00 N 695747.55 E Alaska State Plane Zone 4 PBU_EOA DS O5 Dogleg Rate (°/lOOft) 10.000 10.000 0.000 0.000 0.000 0.000 1.100 1.100 1.100 1.100 1.100 1.500 1.500 1.500 0.000 0,000 0.000 0.000 0.000 Vertical Section (ft) 3455.70 3466.70 3503.08 3514.54 3564.15 3613.77 3627.11 3663.33 3712.71 3761.87 3781.32 3807.60 3810.81 3859.38 3905.95 3907.47 3912.26 3938.56 3955.33 3983.41 Comment Tie-on. Start Dir @ 10.000°/100ft: 10075.00ft MD, 7836.30ftTVD End Dir: 10176.90ft MD, 7893.33ft TVD BHA/Formation Trend @ 1.100°/100ft: 10426.90ft MD, 8014.53ft TVD LCU BHA/Formation Trend @ 1.500°/100ft: 10793.43ft MD, 8203.10ft TVD End Dir: 10996.81ft MD, 8318.10ft TVD TSAG 7" Casing Shublik Top Sadlerochit Continued... 27 September, 1999- 16:23 - I - DrillQuest Sperry-Sun Drilling Services Proposal Report for 05-16B Wp 7 Revised: 27 September, 1999 Prudhoe Bay Unit Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 11200.00 54.062 355.078 8374.25 11226.83 54.062 355.078 8390.00 11300.00 54.062 355.078 8432.95 11312.02 54.062 355.078 8440.00 11397.21 54.062 355.078 8490.00 11400.00 54.062 355.078 8491.64 11500.00 54.062 355.078 8550.33 11600.00 54.062 355.078 8609.02 11683.29 54.062 355.078 8657.90 11700.00 55.883 352.827 8667.49 11713.65 57.399 351.060 8675.00 11800.00 67.465 341.083 8714.99 11900.00 79.762 331.223 8743.21 11990.21 91.100 323.000 8750.40 12000.00 91.110 321.560 8750.21 12100.00 91.175 306.857 8748.20 12200.00 91.163 292.153 8746.15 12257.80 91.121 283.654 8745.00 12300.00 90.755 277.757 8744.31 12350.96 90.303 270.637 8743.84 Vertical Depth Northings (ft) (ft) 8437.35 5733.46 N 8453.10 5755.10 N 8496.05 5814.12 N 8503.10 5823.82 N 8553.10 5892.54 N 8554.74 5894.79 N 8613.43 5975.46 N 8672.12 6.056.12 N 8721.00 6123.31 N 8730.59 6136.92 N · 8738.10 6148.20 Ni; 8778.09 6222.20 N 8806.31 6309.54 N 8813.50 6384.84 N 8813.31 6392.58 N 8811.30 6462.10 N 8809.25 6511.21 N 8808.10 6528.96 N Local Coordinates Eastings (ft) 1198.18W 1200.04W 1205.13W 1205.96W 1211.88W 1212.07W 1219,02 W.:: 1225:97W: 1231.75W 1233.20W 1234.80W 1253.46W 1292.36W 1341.11W 1347.10W 1418.57W 1505.34W 1560.28W 8807.41 6536.79 N 1601.72W 8806.94 6540.52 N 1652.51W Global Coordinates Dogleg Northings ':::!" ?, %Ea~tings Rate (ft) (ft) (°/100ft) 5955230.25:N ~ 695743.81E 0.000 595'52~i184N~ 695741.38 E 0.000 5955310.71N 695734.75 E 0.000 5955320;38 N 695733.66 E 0.000 5955388.92 N 695725.95 E 0.000 5955391.17 N 695725.69 E 0.000 ..5955471.63 N 695716.64 E 0.000 5955552.08 N 695707.58 E 0.000 5955619.09 N 695700.04 E 0.000 5955632.66 N 695698.24 E 15.500 5955643.90 N 695696.34 E 15.500 5955717.38 N 695675.75 E 15.500 5955803.68 N 695634.58 E 15.500 5955877.67 N 695583.87 E 15.500 5955885.25 N 695577.68 E 14.701 5955952.88 N 695504.42 E 14.701 5955999.70 N 695416.39 E 14.701 5956016.00 N ~ 695361.00 E 14.701 5956022.75 N 695319.37 E 14.000 5956025.14 N 695268.50 E 14.000 Alaska State Plane Zone 4 PBU_EOA DS 05 Ve~lcal Section (ft) 4003.18 4016.02 4051.04 4056.79 4097.56 4098.89 4146.75 4194.60 4234.46 4242.77 4250.00 4304.40 4383.02 4463.80 4472.94 4570.13 4669.79 4725.95 4765.42 4810.75 Comment - TZ4A - TZ3 - TZ2 Start Dir @ 15.500°/100ft' 11683.29ft MD, 8721.00ft TVD - TZ1 Dir Rate Decrease @ 14.701°/100ft: 11990.21ft MD, 8813.50ft TVD Dir Rate Decrease @ 14.000°/100ft: 12257.80ft MD, 8808.10ftTVD Taraet - 5-16B Mid Pt. Geo'logical End Dir: 12350.96ft MD, 8806.94ft TVD Continued... 27 September, 1999 - 16:23 - 2 - DrillQuest Sperry-Sun Drilling Services Proposal Report for 05-16B Wp 7 Revised: 27 September, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12400.00 90.303 270.637 8743,58 8806,68 12500,00 90.303 270,637 8743.05 8806,15 12600,00 90,303 270,637 8742.52 8805.62 12700,00 90,303 270.637 8741,99 8805,09 12800,00 90.303 270.637 8741.46 8804,56 12900.00 90.303 270.637 8740.93 8804,03 13000.00 90.303 270.637 8740,40 8803.50 13100,00 90,303 270.637 8739.87 8802.97 13200,00 90,303 270,637 8739,34 8802.44 13300,00 90,303 270.637 8738,81 8801,91 13400,00 90.303 270.637 8738,28 8801,38 13500.00 90.303 270,637 8737,75 8800.85 13600.00 90,303 270.637 8737,22 8800.32 13700.00 90,303 270.637 8736.69 8799,79 13800,00 90.303 270.637 8736,16 8799.26 13900.00 90,303 270.637 8735.63 8798,73 14000,00 90,303 270.637 8735,10 8798,20 14019.67 90.303 270.637 8735.00 8798,10 Local Coordinates Global Coordinates Northings Eastings Northings = EaStlngs (ft) (ft) (ft) (ft) 6541.06 N 1701.55 W 5956024.40 N ' 695219.47 E 6542.17 N 1801.54 W 5956022;90 N 695119.48 E 6543.29 N 1901.53 W 5956021.39 N 695019.49 E 6544.40 N 2001.53 W 595601:9.88 N 694919.50 E 6545.51 N 2101.52 W 5956018.38 N 694819.52 E 6546.62 N 2201,5! :' 7 5956016.87 N' 694719,53 E 6547,73 N 2301,50 W '5956015.36 N 694619,54 E 6548,84 N 2401~50 W: 5956013.86 N 694519,55 E :. : 6549.96 N .2501i49 W 5956012,35 N 694419.57 E 6551,07 N 2601,48 W 5956010.84 N 694319,58 E 6552,18 :N 2701,47 W 5956009,34 N 694219.59 E 6553,29 N 2801,47 W 5956007,83 N 694119,61 E 6554,40 N 2901,46 W 5956006,32 N 694019,62 E 6555.51 N 3001.45 W 5956004.82 N 693919.63 E 6556.62 N 3101,44 W 5956003.31 N 693819,64 E 6557,74 N 3201,44 W 5956001,80 N 693719,66 E 6558.85 N 3301,43 W 5956000,30 N 693619,67 E 6559,07 N 3321,10 W 5956000,00 N 693600.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 PBU_EOA DS 05 Dogleg Rate (°/100ft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section (ft) 4852,93 4938,94 5024.95 5110,96 5196,96 5282,97 5368,98 5454,99 5541,00 5627,00 5713,01 5799,02 5885,03 5971,04 6057,04 6143,05 6229,06 6245,98 Comment Total Depth: 14019.67ft MD, 8798.1 Oft TVD 4 1/2" Liner Target - 05-16B TD (9-7-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 301.310° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14019.67ft., 27 September, 1999 - 16:23 - 3 - DrillQuest -I 1 55827 VENDOR ALASKAST 14 O0 DATE INVOK;E / CREDrr MEMO DESCRIPTION GROSS DISCOUNT NET )827c2c2 CKO827c2C2D 100. O0 100. O0 HANDL:rN~ INST- S/H TERRI HUBBLE X4628 A'rrAcHED CHECK P~ ~ PAYMENT FOR ITEMS DESCRIBED A~:)V'E. ml[o]ll~ill~ m 1 OO. CO 1 OO. CO -BP..EXPLORATION (ALASKA).,.:.INC. : ":: -::::: ' i:: :-: - ; -i- .'::' .::: - ' :': ' ANCHOR^GE; ALAS~; 99519-6612: ':' No.:'H 1 55827 CONSOLIDATED COMMERCIAL AccoUNT · ,~2 ' O0155827 ~AY DATE O8/30/c2c2 FO":'T-he:: ::::ALASKA STATE::.:DEpT .:::OF REVENUE ]RDER ':: ':.3OO1 ':.;iPORCUP I NE/i~DR- i :: . ,,'... ::. ANCHORAGE AK 9~501-3120 .AMOUNT NOT!:VALID AFTER 120 DAYS· ,' ~. 5 5,°, ~ ?,' '-'O h ;1, ~ 0 3,,°, q 5'-' WELL PERMIT CHECKLIST COMPANY FIELD & POOL'""~7~UZ:~,~/~E. '~,-~,~'~ INIT CLASS '~,~ V' /-. 43//_.. · -Z..~_~f/~j~=t-/ ~' - 2. Lease number appropriate ................... DATE__ / WELL NAME: _7~/..,J' ~:~),..~-/~ PROGRAM: exp dev redrll ,'¢/' serv wellbore seg GEOL AREA ~,_/~) UNIT# 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. if deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designS adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to -~__,('3~,.~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Permit can be issued w/o hydrogen sulfide measures ..... Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. N N N N ,/ Y~)N ~N N N Y, N )N N ann. disposal para req ON/OFF SHORE t~/Y ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. L?ppR' DATE 26. ~/~, ',:,~ 27. 28. 29. GEOLOGY 30. 31. 32. A/~.R DATE 33. , /~(~ -~ 34. Y N/v/~ ANNULAR DISPOSAL 35. APPR With proper cementing records, this plan .... (A) will contain waste in a suitable receiving zone; . . / . . DATE ~inate freshwater; or cause drilling/y~ste... Y N / /" (C) ~mpairme~aii_ntegrityofthewjetfusedfordisposal; Y N / (D) ~pair recovery from a Y N pool; and ? (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Contact name/phone for weekly progress reports [exploratory only] Y N Y N GEOI_OGY: ENGINEERING: UIC/Annular c:\msoffice\wordian\diana\checklist (rev. 09127199) COMMISSION: CO ' ............ Comments/Instructions: O z O .--I ITl Z > Well Histo.ry 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. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Apr 26 11:29:31 2000 Reel Header Service name ............. LISTPE Date ..................... 00/04/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/04/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: mwd RUN 3 AK-MM-90178 MARK HANIK JOHN RALL DS 5-16B 500292026202 Arco Alaska, INC. Sperry Sun 25-APR-00 mwd RUN 4 AK-MM-90178 MARK HANIK JOHN RALL mwd RUN 5 AK-MM-90178 RANDY KRELL GAVIN KIDD RECEIVED Alaska Oil & Gas Cons. Commission Anchorage JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: M~D RUN 5 AK-MM-90178 RANDY KRELL GAVIN KIDD 32 liN 15E 3367 38 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 65.00 65.00 36.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9~625 10039.0 6.125 7.000 10615.0 6.125 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 2-3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTLIZING GEIGER- MUELLER TUBE DETECTORS. MWD RUN 2 IS NOT PRESENTED DUE TO TOOL FAILURE. 4. MWD RUN 4 IS DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. MWD RUN 5 IS DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 6. LOG DATA IN THE INTERVAL llll2'MD, 8646'TVD TO ll600'MD, 8764'TVD WAS OBTAINED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE TRIPPING OUT OF THE HOLE PRIOR TO MWD RUN 5. THE TOOL STRING WAS NOT ROTATED FOR THIS MAD PASS DUE TO HIGH DOG LEGS IN THE INTERVAL. 7. BOTH DIGITAL AND LOG DATA ARE DEPTH CORRECTED TO THE PDC GR LOG (SWS OH GR 9/24/77) WITH ORIGINAL KBE OF 69' A.M.S.L. KICKOFF POINT OF THIS WELLBORE FROM PARENT WELL 5-16A IS AT 10039'MD, 8056'TVD. ALL LOG HEADER DATA RETAIN THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1-5 REPRESENT WELL 5-16B WITH API#: 50-029-20262-02. THIS WELL REACHED A TOTAL DEPTH OF 14135'MD, 8795'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH A "M" SUFFIX DENOTE MAD PASS DATA. PARAMETERS USED IN POROSITY LOG CALCULATIONS: HOLE SIZE: 6.125" MUD WEIGHT: 8.5 PPG MUD FILTRATE SALINITY: 1000 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET NPHI FCNT NCNT PEF DRHO RHOB $ .5000 START DEPTH 10020.0 10045.5 10611.5 10611.5 10611 5 10611 5 10611 5 12163 5 12163 5 12163 5 12178 5 12178 5 12178 5 STOP DEPTH 14099.0 14141.5 14106.0 14106.0 14106.0 14106.0 14106.0 14051.5 14052.0 14051.5 14067.0 14067.0 14067.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH -- BASELINE DEPTH 10020.0 10022.0 10026.0 10038.0 10041.0 10043.5 14141.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: GR 10017 0 10019 0 10023 5 10033 0 10035 0 10037 0 14135 0 BIT RUN NO MERGE TOP MERGE BASE 3 10039.0 10615.0 4 10615.0 12245.0 5 12245.0 14135.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth'Units ........... Feet Data Reference Point .............. Undefined Frame SPacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT .FT 10020 14141.5 12080.8 8244 ROP MWD FT/H 0 190.75 52.4806 8193 GR MWD API 12.33 533.31 70.1977 8159 RPX MWD OHMM 0.42 2000 511.688 6990 RPS MWD OHMM 0.53 2000 297.621 6990 First Reading 10020 10045.5 10020 10611.5 10611.5 Last Reading 14141.5 14141.5 14099 14106 14106 RPM MWD OHMM 0.54 2000 299.939 RPD MWD OHMM 0.36 2000 266.922 FET MWD HOUR 0.35 52.93 1.67388 NPHI MWD PU-S 17.05 29.74 23.8809 FCNT MWD CNTS 411.2 890 605.604 NCNT MWD CNTS 23723.7 34465.9 28121.5 RHOB MWD G/CM 2.163 2.918 2.35031 DRHO MWD G/CM -0.175 0.808 0.0541826 PEF MWD BARN 1.024 6.558 1.9924 6990 6990 6990 3777 3778 3777 3778 3778 3778 10611.5 10611.5 10611.5 12163.5 12163.5 12163.5 12178.5 12178.5 12178.5 14106 14106 14106 14051.5 14052 14051.5 14067 14067 14067 First Reading For Entire File .......... 10020 Last Reading For Entire File ........... 14141.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE NCNT FCNT NPHI DRHO RHOB GR FET RPD RPM RPS RPX RAT $ MERGED DATA SOURCE .5000 START DEPTH 11112.0 11112 0 11112 5 11127 5 11127 5 11160 0 11167 0 11167.0 11167.0 11167.0 11167.0 11203.0 STOP DEPTH 11519.0 11519.0 11518.5 11534 0 11534 0 11570 0 11576 5 11576 5 11576 5 11576 5 11576 5 11609 5 PBU TOOL CODE MWD $ REMARKS: MAD RUN NO. MAD PASS NO. 5 0 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 11112.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 NPHI MAD PU-S 4 1 68 FCNT MAD CNTS 4 1 68 NCNT MAD CNTS 4 1 68 RHOB MAD G/CM 4 1 68 DRHO MAD G/CM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 MERGE BASE 11600.0 Name Service Unit DEPT FT RAT MAD FT/H GR MAD API RPX MAD OHMM RPS MAD OHMM RPM MAD OHMM RPD MAD OHMM FET MAD HOUR NPHI MAD PU-S FCNT MAD CNTS NCNT MAD CNTS RHOB MAD G/CM DRHO MAD G/CM Min 11112 0.02 9.35 33 58 51 39 75 66 85 16 53 85 18 25 251.02 18612.9 2.03 -0.27 Max 11609.5 455.68 121.22 2000 2000 2000 2000 69.02 44.2 776.37 30113.2 3.77 1.45 Mean Nsam 11360.8 996 152.263 814 32.9007 821 746.841 820 326.245 820 432.158 '820 522.35 820 61.1199 820 25.3779 813 514.836 815 25419.3 815 2.27138 814 0.022457 814 First Reading 11112 11203 11160 11167 11167 11167 11167 11167 11112.5 11112 11112 11127.5 11127.5 Last Reading 11609.5 11609.5 11570 11576.5 11576.5 11576.5 11576.5 11576.5 11518.5 11519 11519 11534 11534 First Reading For Entire File .......... 11112 Last Reading For Entire File ........... 11609.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10017.0 ROP 10039.0 $ # 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): STOP DEPTH 10591.5 10615.0 05-NOV-99 Insite 630.91 MEMORY 10615.0 35.8 50.8 TOOL NUMBER P1375HG6 8.500 10039.0 LSND-HT 10.50 45.0 9.2 1500 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): . MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 4.0 .000 .000 .000 ..000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 . 3 .0 134.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10017 10615 10316 1197 ROP MWD030 FT/H 0.05 190.75 37.4936 1153 GR MWD030 API 57.67 398.39 169.772 1150 First Reading 10017 10039 10017 Last Reading 10615 10615 10591.5 First Reading For Entire File .......... 10017 Last Reading For Entire File ........... 10615 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPM RPD RPS RPX FET ROP # LOG HEADER DATA DATE LOGGED: SOFTWARE 10592.0 10605 0 10605 0 10605 0 10605 0 10605 0 10615 5 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 12203.5 12210.5 12210.5 12210.5 12210.5 12210.5 12245.5 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): 10-NOV-99 Insite 0.41 MEMORY 12246.0 35.7 91.7 TOOL NUMBER P1335GRV4 P1335GRV4 6.125 10615.0 QUICKDRILN 8.40 41.0 9.4 8OO 10.1 1.900 68.0 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY {HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block TYPe ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 1.120 1.700 2.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 120.0 68.0 68.0 Name Service Unit Min Max DEPT FT 10592 12245.5 ROP MWD040 FT/H 0 138.66 GR MWD040 API 12.33 533.31 RPX MWD040 OHMM 0.42 2000 RPS MWD040 OHMM 0.53 2000 RPM MWD040 OHMM 0.54 2000 RPD MWD040 OHMM 0.36 2000 FET MWD040 HOUR 0.35 52.93 Mean Nsam 11418.8 3308 55.4651 3261 54.9481 3224 967.137 3212 534.584 3212 534.131 3212 440.532 3212 1.70124 3212 First Reading 10592 10615.5 10592 10605 10605 10605 10605 10605 Last Reading 12245.5 12245.5 12203.5 12210.5 12210.5 12210.5 12210.5 12210.5 First Reading For Entire File .......... 10592 Last Reading For Entire File ........... 12245.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 12157.0 14045.0 NPHI 12157.0 14045.0 FCNT 12157.0 14045.0 PEF 12172.0 14060.5 DRHO 12172.0 14060.5 RHOB 12172.0 14060.5 GR 12204.5 14092.5 FET 12211.0 14099.5 RPD 12211.0 14099.5 RPM 12211.0 14099.5 RPS 12211.0 14099.5 RPX 12211.0 14099.5 ROP 12248.0 14135.0 $ # 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. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN 14-NOV~99 Insite 0.41 MEMORY 14135.0 89.6 93.6 TOOL NUMBER P1335GRV4 P1335GRV4 P1380NL4 P1380NL4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 6.125 QUICKDRILN 8.50 44.0 9.2 8OO 6.9 2.000 .880 1.800 2.200 Name Service Order Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU-S 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 BARN 4 1 68 44 12 BARN 4 1 68 48 13 BARN 4 1 68 52 14 DEPT ROP MWD050 GR MWD050 RPX MWD050 RPS MWD050 RPM MWD050 RPD MWD050 FET MWD050 NPHI MWD050 FCNT MWD050 NCNT MWD050 RHOB MWD050 DRHO MWD050 PEF MWD050 70.0 168.0 70.0 70.0 First Last Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HOUR NPHI MWD050 PU-S FCNT MWD050 CNTS NCNT MWD050 CNTS RHOB MWD050 BARN DRHO MWD050 BARN PEF MWD050 BARN Min Max 12157 14135 9.19 169.1 36.02 98.75 29.21 310.44 32.07 158.98 47.56 1609.02 66.33 2000 0.51 25.91 17.05 29.74 411.2 890 23723.7 34465.9 2.163 2.918 -0.175 0.808 1.024 6.558 Mean Nsam 13146 3957 54.4827 3775 52.8755 3777 124.471 3778 96.1592 3778 100.832 3778 119.321 3778 1.65063 3778 23.8809 3777 605.604 3777 28121.5 3777 2.35031 3778 0.0541826 3778 1.9924 3778 Reading 12157 12248 12204.5 12211 12211 12211 12211 12211 12157 12157 12157 12172 12172 12172 Reading 14135 14135 14092.5 14099.5 14099.5 14099.5 14099.5 14099.5 14045 14045 14045 14060.5 14060.5 14060.5 First Reading For Entire File .......... 12157 Last Reading For Entire File ........... 14135 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: 0 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT FCNT NPHI DRHO RHOB GR RPX 11112.0 11112 0 11112 5 11127 5 11127 5 11160 0 11167 0 STOP DEPTH 11519.0 11519.0 11518.5 11534.0 11534.0 11570.0 11576.5 RPS 11167.0 RPM 11167.0 RPD 11167.0 FET 11167.0 RAT 11203.0 $ 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. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 11576.5 11576.5 11576.5 11576.5 11609.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 14-NOV-99 Insite 0.41 MEMORY 14135.0 89.6 93.6 TOOL NUMBER P1335GRV4 P1335GRV4 P1380NL4 P1380NL4 6.125 QUICKDRILN 8.50 44.0 9.2 8OO 6.9 2.000 .880 1.800 2.200 70.0 168.0 70.0 70.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT RAT GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO Service Order Units Size Nsam Rep FT 4 1 68 MAD050 FT/H 4 1 68 MAD050 API 4 1 68 MAD050 OHMM 4 1 68 MAD050 OHMM 4 1 68 MAD050 OHMM 4 1 68 MAD050 OHMM 4 1 68 MAD050 HOUR 4 1 68 MAD050 PU-S 4 1 68 MAD050 CNTS 4 1 68 MAD050 CNTS 4 1 68 MAD050 G/CM 4 1 68 MAD050 G/CM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 Name Service Unit Min Max DEPT FT 11112 11609.5 RAT MAD050 FT/H 0.02 455.68 GR MAD050 API 9.35 121.22 RPX MAD050 OHMM 33.58 2000 RPS MAD050 OHMM 51.39 2000 RPM MAD050 OHMM 75.66 2000 RPD MAD050 OHMM 85.16 2000 FET MAD050 HOUR 53.85 69.02 NPHI MAD050 PU-S 18.25 44.2 FCNT MAD050 CNTS 251.02 776.37 NCNT MAD050 CNTS 18612.9 30113.2 RHOB MAD050 G/CM 2.03 3.77 DRHO MAD050 G/CM -0.27 1.45 Mean Nsam 11360.8 996 152.263 814 32.9007 821 746.841 820 326.245 820 432.158 820 522.35 820 61.1199 820 25.3779 813 514.836 815 25419.3 815 2.27138 814 0.022457 814 First Reading 11112 11203 11160 11167 11167 11167 11167 11167 11112.5 11112 11112 11127.5 11127.5 Last Reading 11609.5 11609.5 11570 11576.5 11576.5 11576.5 11576.5 11576.5 11518.5 11519 11519 11534 11534 First Reading For Entire File .......... 11112 Last Reading For Entire File ........... 11609.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/04/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/04/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
