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203-181
e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d 03 - 1 ~ 1 Well History File Identifier Organizing (done) o Two-sided 11111111111 "' II III RESCAN DIGITAL DATA ~skettes No. , o Other, NolType: o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: BY: ~ Date fa/? /06 Project Proofing oatefohjób c2 x 30 = (06 Date fo /7/D(, BY: ~ Scanning Preparation BY: c: Maria ) Production Scanning o Rescan Needed III II 11111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: VVlf 151 1111/111111111 "III 151 wP + if = TOTAL PAGES b if (Count does not include cover sheet) ~^ A () ~I 'rv~l- 11111111111111 "'II Stage 1 Page Count from Scanned File: ~ ~ (Count does include cover sheet) ~ES BY: Page Count Matches Number in Scanning Preparation: . Date: 1017 j00 ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: NO 151 Vt1P YES NO 151 11111111111I111111I 11111111111111 "III 151 Quality Checked 1111111111111111111 1 0/6/2005 Well History File Cover Page. doc • RECEIVED STATE OF ALASKA DEC 2 0 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND L OGCC la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other ®Abandoned 0 Suspended 1b. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions Zero 0 Development ®Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 12/01/2013 ! 203-181 313-489 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 12/7/2003 50-029-23183-00-00 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/13/2003 PBU S-116 4271' FSL,4502'FEL, SEC.35, T12N, R12E, UM 8. KB(ft above MSL): 64.4' 15. Field/Pool(s) Top of Productive Horizon: 1327' FSL, 1404' FEL, SEC. 34, T12N, R12E, UM GL(ft above MSL): 35.5' Prudhoe Bay Field/Aurora Oil Total Depth: 9. Plug Back Depth(MD+TVD) Pool 1247' FSL, 1468' FEL, SEC. 34, T12N, R12E, UM 7990' 6988' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 618930 y- 5980475 Zone- ASP4 8291'. 7075' ADL 028257&028258 TPI: x- 616799 y- 5977497 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 616736 y- 5977416 Zone- ASP4 (Nipple) 18. Directional Surve 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): y: ❑Yes ® No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD/GR, MWD/RES/GR, PEX/c, MDT, USIT N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 42" 260 sx Arctic Set(Approx.) 9-5/8" 40# L-80 28' 3450' 28' 2939' 12-1/4" 571 sx AS Lite PF, 312 sx Class'G' 7" 26# L-80 26' 8279' 26' 7063' 8-3/4" 293 sx LiteCrete, 159 sx Class'G' 24. Open to production or injection? ❑Yes ®No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD (MD+TVD of Top&Bottom;Perforation Size and Number): ) 4-1/2", 12.6#, L-80 7821' 7761'/6574' 26. ACID, FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No WE� AV 2014 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED tvl7990' Set Whipstock 7995' 20 Bbls Class'G' 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Injection N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBL`'M(Z MAR 2 1 ' Form 10-407 Revised 10/2012 COUEVERSE Submit Original Only/ vi-r- Q 4/23114- 7✓ V�9 29. GEOLOGIC MARKERS(List all formations an cers encounter 30. FORMATION TESTS • NAME MD TVD Well Tested? 0 Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 4359' 3592' Ugnu M Sands 5669' 4719' Schrader Bluff N 5942' 4954' Schrader Bluff 0 6079' 5072' Base Schrader/Top Colville 6412' 5362' HRZ 7762' 6575' Kalubik 7961' 6762' Kuparuk C 7971' 6771' Kuparuk B 8032' 6829' Kuparuk A 8088' 6882' Miluveach 8154' 6945' Formation at Total Depth: 31.List of Attachment! Summary of Pre-Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: Trevor.Hyatt@bp.com Trevor Hyatt,564-4627 Title: Drilling Technologist Printed Name: Joe Lastu Signature: I ( Phone 564 4091 Date: 2. / LO�I j INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only S-116, Well History (Pre Rig Sidetrack) Date Summary 09/22/13 INTIAL T/I/0=340/0/160 PSI. RIH W/BAKER 4.5"x7"THRU TBG WHIPSTOCK, OAL OF WHIPSTOCK=16.41'. CCL STOP DEPTH=7976.2', CCL TO TOP OF WHIPSTOCK=13.8'. SET TOP OF WHIPSTOCK AT 7990', ORIENTED AT 0°. 2 RA TAGS LOCATED 10' FROM TOP OF WHIPSTOCK. DEPTH CORRECTED TO SLB USIT LOG DATED 15-APR-04. LEFT WELL SHUT-IN, HAND OVER WITH DSO PRIOR TO DEPARTURE. FINAL T/I/O =300/0/160 PSI. 10/04/13 RIH w/BTT LH milling assy w/3.80" DSM and mill out XN nipple at 7809'. POH. Mill gauged 3.79". RIH w/2.25" BDN and tag WS at 7999' CTM. PUH 10'and paint flag. Displace coil with non-slick KCI. Establish injectivity: 1220 psi @ 1.0 bpm. SLB Cementers pump 5 bbl fresh water spacer, 20 bbl 15.8 ppg Class G cement, and 28 bbl fresh water coil displacement. Closed choke when cement reached nozzle and squeezed 8 bbl of cement into perforations, then opened choke and layed in 12 bbl cement 1:1. Estimated TOC =7530'. PUH to safety at 6400' (500'above WCTOC)while pumping at 0.5 bpm, maintaining 1500-1600 psi WHP with choke. Down on cement pump; cementers begin washing up. Line up CTU to launch 3/4" ball with slick KCI. 10/05/13 Launch 3/4" ball with slick KCI, then swap to PowerVis for cement contamination. Once PowerVis at nozzle, made 3 passes (down, up, down)from 7400'to top of whipstock at 7997' (estimated TOC prior to contamination =7430'). POOH at 80%,washing jewelry. Maintained 1000 psi WHP throughout contamination and POOH. Wash BOP stack. RIH and FP wellbore to 2500'w/38 bbl 60/40 McOH. 10/10/13 T/I/O=335/16/160 Temp=SI MIT-T(post CTD) MIT-T**FAILED**2 attempts to 2400 psi in the 1st 15 min. Pumped a total of 5.41 bbls MEOH for test. 1st 15 min TBGP lost 1034 psi failing both attempts at MIT-T in 1st 15 min. Pumped 15 bbls MEOH to establish a LLR of 1.3 BPM @ 2330 PSI. FWHP's=312/14/160 DSO notified on departure of SWV,SSV=S/I IAV,OAV=OTG. 10/18/13 T/I/0=5/0/220 SI Assist SL with MITs(CTD) MIT T 2000 psi***PASSED***Pumped 1.9 bbls meth down TBG to achieve test pressure of 2000 psi. 15 min loss of 80 psi, 30 min loss of 27 psi,for total loss of 107 psi in 30 mins. Bleed TBG pressure to 200 psi. 10/18/13 RAN 4-1/2" BRUSH, 3.805"G-RING TO 2,250'SLM, BRUSH SSSV NIPPLE. SET 4-1/2"XX PLUG BODY(cal-22",4x 3/16"ports) @ 2,174'SLM/2,195' MD. LRS PERFORMS MIT-T TO 2000psi (pass). 10/19/13 MIT IA 2000 psi***PASSED***Pumped 2.7 bbls meth down IA to achieve test pressure of 2000 psi. 15 min loss of 24 psi, 30 min loss of 7 psi, for total loss of 31 psi in 30 mins. Bleed IAP to 0 psi. Pad Op/PE notified Valve positions=SV WV SSV closed MV open CVs OTG FWHP=300/0/220. 10/22/13 PPPOT-T: Stung into test port(0+ psi), bled void to 0 psi. Functioned LDS (ET), all moved freely 1". Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 10/23/13 T/I/0=500/0/0; Set 4-1/16"CIW"H"TWC#287 thru tree for tree replacement for Nordic 2,tagged at 120"; Bled TP to 270 prior to set. Final T/I/O=TWC/0/0. 11/08/13 T/I/O=TWC/O/O. C/O 4"tree, torque MV x THA, PT& Pull CIW 4"TWC#287. Final WHP=280/0/0. 11/12/13 EQUALIZE XX-PLUG @ 2,196' MD. 11/13/13 PULLED XX-PLUG FROM 2,175' SLM (2,196' MD). Page 1 of 2 S-116, Well History (Pre Rig Sidetrack) Date Summary 11/13/13 T/I/O=500/0/0. Remove ASV#3. Set 4"CIW TWC#260.Torqued all flanges to API specs. Shell tested tree. Pulled 4" CIW TWC#260. Set 4"CIW BPV#138. Final T/I/O=BPV/0/0. Page 2 of 2 North America-ALASKA-BP Page 1 of 15 Operation Summary Report Common Well Name:S-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 End Date: X3-013RN-C:(3,802.503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/7/2003 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292318300 Active datum:ORIG KELLY BUSHING @64.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/23/2013 10:30 - 12:00 1.50 MOB P PRE HOLD PJSM WITH ENTIRE CREW. DISCUSS COMMS,SPOTTER ROLES,PATH OF TRAVEL. BACK RIG OFF WELL. SPOT ON PAD FOR MPD RU AND PREP. 12:00 - 18:00 6.00 RIGU P PRE !STAGE ON SIDE OF PAD. I BREAK DOWN TOT BOPS. RE-CONFIGURE BOP STACK FOR MPD I,REQUIREMENTS. INSTALL REPLACEMENT FINGERS IN DERRICK. 18:00 - 00:00 6.00 RIGU P PRE CONTINUE TO MAKE UP BOP STACK FOR MPD REQUIREMENTS. 11/24/2013 00:00 - 06:00 6.00 BOPSUR P PRE CONTINUE TO RECONFIGURE BOP STACK FOR MPD. DIRT WORK IS ONGOING ON S-116. 06:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE DISCUSS CURRENT OPS 1 AND RU PROGRESS FOR MPD EQUIPMENT. 06:30 - 17:30 11.00 BOPSUR P PRE COMPLETE DIRT WORK AND REMOVAL FROM S-116 LOCATION. SPOT 2ND FLOW BACK TANK. CONTINUE TO NU MPD BOP STACK CONTINUE TO BUILD UP MPD BOP STACK RECONFIGURE CHOKE AND KILL LINES.ADD GRAY LOCK SWIVEL TO IMPROVE KILL LINE POSITION. ADD 3RD DOUBLE GATE RAMS. LIFT BOPS IN CELLAR AND HANG OFF BLOCKS.. MU 4"LUBRICATOR. STAND BACK IN DERRICK.CLAMP HYDRAULIC SPOOLER AND FOOTAGE WHEEL ASSEMBLIES TO LUBRICATOR. SPOOL NEW CERTIFIED 0.125'WIRE ON TO SPOOLING UNIT.RU SLICKLINE TOOLS. GET 3RD PARTY SLICKLINERS TO MU ROPE SOCKET. 17:30 - 22:00 4.50 MOB P PRE MOVE SATTELITE OFFICE TO NEW LOCATION. CONTINUE PREP WORK TO MOVE RIG TO S-116. 22:00 - 23:30 1.50 ( MOB P PRE PJSM.MOVE RIG FROM S-12 TO S-116. 23:30 - 00:00 0.50 MOB P PRE PJSM. POSITION RIG AND SET DOWN ON S-116 WELL. 11/25/2013 00:00 - 01:00 1.00 MOB P PRE POSITION RIG AND SET DOWN ON S-116 WELL. ACCEPT RIG AT 01:00 ON 11/25/2013. 01:00 - 06:00 5.00 RIGU P PRE CONTINUE RIGGING UP ON S-116. SPOT CUTTINGS BOX AND WELDING SHOP. INSTALL ESD ON WING VALVE. BEGIN NIPPLE UP BOPE. 06:00 - 06:30 0.50 RIGU P PRE CREW CHANGE. DISCUSS STATUS OF RIG UP PROCESS. MAKE EQUIPMENT CHECKS AND RIG ROUNDS. I CONTINUE TO RU MPD AND LOCATION EQUIPMENT. Printed 12/9/2013 2:16:26PM • • North America-ALASKA-BP Page 2 of 15 Operation Summary Report Common Well Name:5-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 End Date: 'X3-013RN-C:(3,802,503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/7/2003 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292318300 Active datum:ORIG KELLY BUSHING @64.40usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) L -- (usft) 06:30 - 18:00 11.50 RIGU P PRE MAKE CABLE RUN ACROSS WITH WITH NEW CABLE TRAY. CONTINUE TO RIG UP MPD LOOP AND ESD EQUIPMENT IN CELLAR. SPOT AND RU FLOW BACK TANK AND HARD LINE. PRESS TEST SAME. MEASURE AND RECORD BOP COMPONENT ELEVATION FROM FLOOR. 18:00 - 21:30 3.50 BOPSUB P PRE CREW CHANGE.PJSM FILL STACK WITH H2O. GREASE MUD CROSS AND BOP VALVES #17,18,19 AND 20. VERIFY RKB. 21:30 - 00:00 2.50 BOPSUR P PRE BEGIN TESTING BOPE. SHELL TEST TO 250/4500 PSI TEST ALL BOPE TO 250/3500 PSI. SWAB VALVES LEAKING. CALLED OUT GREASE CREW TO GREASE ALL TREE VALVES. CONTINUE TESTING. 11/26/2013 00:00 - 06:00 6.00 BOPSUR P PRE CONTINUE BOPE TEST 250/3500PSI. TEST ALL BOPE,CHOKE MANIFOLD AND MPD LOOP VALVES AND IRON. __- 06:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE. DISCUSS STATUS OF BOP TEST. MAKE RIG ROUNDS AND EQUIPMENT CHECKS. 06:30 - 14:00 7.50 BOPSUR P PRE CONTINUE TO TEST BOP EQUIPMENT AS PER WELL PLAN,PERMIT TO DRILL,AOGCC REGS,AND NORDIC TEST PROCEDURE. REBUILD 1 VALVE IN CHOKE MANIFOLD. I CHART ALL TESTS. PASSED. TEST WITNESS WAIVED BY J.CRISP,AOGCC. 14:00 - 18:00 4.00 BOPSUR P PRE -INSPECT MPD EQUIPMENT RIG UP WITH NORDIC SUPERINTENDENT. FOUND TO BE AS PER FLOW DIAGRAMS DETAILED IN APPROVED WELLPLAN. HOLD PJSM. INSTALL GRAPPLE AND NIGHT CAP. PULL COIL ACROSS AND STAB INTO INJECTOR. FILL COIL WITH 11.8 PPG BRINE. PREP TO TEST 4"LUBRICATOR. PULL TEST SLICKLINE. PARTED INSIDE LUBRICATOR. DISASSEMBLE SAME. CALL WELLS GROUP FOR SUPERVISOR/SUPORT. _ TAKE ON 11.8 PPG BRINE IN PITS. 18:00 - 19:00 1.00 BOPSUR P PRE CREW CHANGE.PJSM,PICK UP AND PRESSURE TEST LUBICATOR. 19:00 - 22:00 3.00 BOPSUR P PRE PICKUP LUBRICATOR AND MAKE UP TO WELL. TEST INNER REEL VALVE,PACKOFF AND VALVE#13 250/3500 PSI(PASSED). 22:00 - 23:00 1.00 BOPSUR P PRE DISPLACE COIL WITH FRESH WATER. 23:00 - 00:00 1.00 BOPSUR P PRE 1REHEAD MANAGE PRESSURE DRILLING LUBRICATOR. RIG UP TO PRESSURE TEST MPD CIRCULATING LOOP. Printed 12/9/2013 216:26PM • North America-ALASKA-BP Page 3 of 15 Operation Summary Report Common Well Name:S-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 I End Date: X3-013RN-C:(3,802,503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/7/2003 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292318300 Active datum:ORIG KELLY BUSHING©64.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/27/2013 00:00 - 04:00 4.00 BOPSUR P PRE PRESSURE TESTING CIRCULATING LOOP. DISABLE/ENABLE CHECK VALVES IN CIRCULATING PATH. 04:00 - 05:00 1.00 BOPSUR P PRE PRESSURE TEST SQUEEZE MANIFOLD. 05:00 - 05:30 0.50 BOPSUR P PRE PERFORM RIG EVACUATION/H2S DRILLS W/ AAR. 05:30 - 06:00 0.50 BOPSUR P PRE BLOW DOWN MPD CIRCULATION LOOP. 06:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE. DISCUSS EQUIPMENT STATUS. REVIEW RU AND TESTING STATUS. MAKE EQUIPMENT CHECKS AND RIG ROUNDS. CONTINUE TO RU SLICKLINE PRESS DEPLOY UNIT. 06:30 - 09:00 2.50 RIGU P PRE CONTINUE TO RU SLICKLINE EQUIPMENT ON 4"LUBRICATOR. REMOVE ONE LOOP AROUND COUNTER WHEEL.RE-ROUTE SLICKLINE THROUGH COUNTER WHEEL ASSEMBLY. PULL TEST WIRE AND ROPE SOCKET ASSEMBLY TO 1800 LBS. VERIFY WITH INTEQ STRAIN GAUGE. VERIFY WINCH IS LIMITED TO PREVENT PARTING 0.125"WIRE. I � HOLD TABLE TOP DISCUSSION WITH CREWS. REVIEW WELL KILL DOWN CT ANN AND SECURING WELL PROCEDURES. 09:00 - 10:00 1.00 BOPSUR P PRE HOLD PJSM WITH CREW TO DISCUSS TESTING LUBRICATOR. FILL LUBRICATOR WITH CHARGE PUMP. PRESSURE UP WITH TEST PUMP. 250 PSI AND 3500 PSI. PASSED. CHART SAME. 10:00 - 11:00 1.00 BOPSUR P PRE HOLD RIG EVACUATION DRILL. NOTIFY PAD OPERATOR. MUSTER IN SATELLITE TRAILER. TIMELY RESPONSE. ALL HANDS INCLUDING VAC TRUCK OPERATOR RESPONDED. ALARM AUDIBLE TO ALL ASSOCIATED WITH N2 OPERATION. AAR:NO ISSUES IDENTIFIED. 11 00 - 1530 4.50 BOPSUR P PRE CUT 275'OF COIL. TRIM E-LINE. CONTINUITY TEST WIRE. LOW ISOLATION READINGS. RE-CUT AND MEG WIRE SEVERAL TIMES. CHECK CABLING FROM J-BOX TO SAT TRAILER. STOP AND CIRCULATE SEVERAL TIMES TO WARM COIL. MEG ISOLATION>2000. 56 OHMS CONTINUITY TEST. BOTH READINGS ARE GOOD. 15:30 - 17:30 2.00 BOPSUR P PRE MU E-COIL HEAD. PRESSURE AND PULL k — TEST SAME. 17:30 - 20:30 3.00 BOPSUR P PRE I TEST FLOATS AND BHI BALL VALVES. 20:30 - 21:00 0.50 BOPSUR P PRE PRESSURE TEST COIL CONNECTION TO 4000 PSI. 21:00 - 21:30 0.50 BOPSUR P PRE PRESSURE TEST BAKER CHECKS TO 3500 PSI. Printed 12/9/2013 2:16.26PM • North America-ALASKA-BP Page 4 of 15 Operation Summary Report Common Well Name:S-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 End Date: X3-013RN-C:(3,802,503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/7/2003 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292318300 Active datum:ORIG KELLY BUSHING @64.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 22:00 0.50 BOPSUR P PRE PJSM FOR SURFACE DRILLS USING MPD EQUIPMENT CLOSED BOTH SWABS AND CIRC THROUGH COIL AND TAKE RETURNS THROUGH MPD CIRC LOOP PRACTICE CLOSING MPD CHOKE AND TRAPPING PRESSURE ON WELL MPD CHOKE MAINTAINS CONSTANT PRESSURE ON WELLHEAD WHILE VARYING PUMP RATES WHEN ATTEMPTING TO SHUT CHOKE AND TRAP PRESSURE,PRESSURE BLEEDS OFF, RETURNS SEEN IN PITS SIMOPS:WEIGHT UP 11.6 PPG BRINE TO 11.8 BRINE AND DISPLACE COIL. 22.00 - 00:00 2.00 BOPSUR N SFAL PRE TROUBLESHOOT MPD CHOKE -VARIED THE SET PRESSURE IN ATTEMPT TO FORCE CHOKE TO FULLY CLOSE -SHUT IN CHOKE AND BLED COIL TO BAKER CHOKE TO ENSURE CHECKS CLOSED -COULD NOT GET WELLHEAD PRESSURE TO MAINTAIN -CALLED MI-SWACO TECHS TO LOCATION 11/28/2013 00:00 - 01:30 1.50 BOPSUR N SFAL PRE CONTINUE TROUBLESHOOT MPD CHOKE -VARIED THE SET PRESSURE IN ATTEMPT TO FORCE CHOKE TO FULLY CLOSE •-SHUT IN CHOKE AND BLED COIL TO BAKER CHOKE TO ENSURE CHECKS CLOSED -COULD NOT GET WELLHEAD PRESSURE TO MAINTAIN -CALLED MI-SWACO TECHS TO LOCATION, TECHS COULD NOT IDENTIFY PROBLEM -LOCATE SPARE MPD CHOKE ON LOCATION, SWAP OUT CHOKES 01:30 06:00 4.50 BOPSUR N SFAL PRE HELD PJSM WITH CREW TO CHANGE OUT AUTOMATIC SUPERCHOKE. COMPLETED EMRC(EQUIPMENT MAINTANENCE REPAIR CHECKLIST) REMOVED AUTOMATIC SUPERCHOKE/ INSTALL NEW SUPERCHOKE. 08:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE. DISCUSS STATUS OF RIG AND MPD CHOKE. MAKE EQUIPMENT CHECKS AND RIG ROUNDS. CONTINUE MPD CHOKE REPLACEMENT. 06:30 - 07:30 1.00 BOPSUR P ' PRE GET OFF WELL. MU NOZZLE BHA WITH DFCV. GET ON WELL,PRESS TEST QTS TO 250 AND 3500 PSI. PASSED. CHART SAME. 07:30 - 10:00 2.50 BOPSUR P PRE CONDUCT MPD CHOKE OPERATION TRAINING WITH DAY CREW. •PRACTICE ROUTINE OPERATIONS. TEST NON-ROUTINE PROCEDURES(AIR SYSTEM FAILURE,ETC) CHECK OUT SEVERAL CREW MEMBERS. -PRACTICE SWITCHING PUMPS TO SIMULATE WELL KILL/LOST CIRCULATION CONDITIONS. -PRACTICE SHUTING IN WELL AS PER STANDING ORDERS DATED 10-31-13. Printed 12/9/2013 2:16:26PM • • North America-ALASKA-BP Page 5 of 15 Operation Summary Report Common Well Name:S-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 End Date: X3-013RN-C:(3,802,503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/7/2003 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292318300 Active datum:ORIG KELLY BUSHING @64.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 15:00 5.00 BOPSUR P PRE BRING DSM BPV LUBRICATOR TO RIG FLOOR. RU SAME. PRESSURE TEST AS PER CRT-AK-10-45.250 AND 3500 PSI.CHART TEST. PASSED. PJSM TO REVIEW NORDIC,BP,AND DSM PROCEDURES. ENGAGE AND PULL BPV. INITIALLY 400 PSI ON WELL. LEAK TIGHT TEST TO VERIFY TWO BARRIERS. RIG DOWN DSM LUBRICATOR. REMOVE FROM RIG. 15:00 - 16:00 1.00 DRILL P PRE PJSM. MU NOZZLE BHA WITH DFCV AND STINGER. GET ON WELL. PRESSURE TEST QTS TO 250 AND 3500 PSI. PASSED. CHART TEST. WHP:80 PSI. 16:00 - 17:30 1.50 BOPSUR P PRE RUN IN HOLE. MAINTAIN 100 PSI WHP. TAKE RETURNS TO DIRTY FLOW BACK TANK. STRAP TANK EVERY 30 MINUTES. 17:30 - 20:00 2.50 BOPSUR P PRE -TAG WHIPSTOCK AT 8015'UNCORRECTED. -PU TO 7990'. -DISPLACE WELL TO 11.8 NABR BRINE. -FLOW CHECK BEFORE POOH,NO FLOW 20:00 - 22:00 2.00 BOPSUR P PRE -POOH FROM 7990'TO SURFACE.TOTAL LOSSES=2 BBLS DURING TRIP -FLOW CHECK ON SURFACE,NO FLOW, WELL STATIC,NO LOSSES -STAND INJECTOR BACK ON LEGS. -CHECK CROWN-O-MATIC. -L/D NOZZLE BHA. 22:00 - 00:00 2.00 BOPSUR P PRE DEPLOYMENT/UNDEPLOYMENT DRILLING -PJSM FOR DEPLOYMENT/UNDEPLOYMENT DRILLS -P/U LUBRICATOR,BROKE SLICKLINE TOOL CONNECTION AND LOCTITE THREADS -RUN THROUGH DEPLOYMENT PROCEDURE VALVE ALIGNMENTS SIMULATING OPERATING VALVE IN PROPER SEQUENCE 11/29/2013 00:00 - 02:00 2.00 BOPSUR P PRE P/U BUILD BHA WITH 3.6 DEG AKO AND ATTEMPT TO DRIFT THROUGH STACK -RUN THROUGH STACK ON TUGGER,NO-GO RIH ABOVE BIT -P/U LUBRICATOR AND M/U SLICK LINE TOOLS TO BHA,NO-GO LANDS PROPERLY IN LOWER LUBRICATOR CONNECTION -ATTEMPT TO P/U BUILD BHA WITH LUBRICATOR,1800 LB WINCH WAS UNABLE TO LIFT -L/D BUILD BHA Printed 12/9/2013 2:16:26PM • North America-ALASKA-BP Page 6 of 15 Operation Summary Report Common Well Name:S-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 End Date: X3-013RN-C:(3,802,503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/7/2003 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292318300 Active datum:ORIG KELLY BUSHING @64.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:00 2.00 BOPSUR P PRE DEPLOYMENT/UNDEPLOYMENT DRILLS -PJSM FOR LIVE DEPLOYMENT/ UNDEPLOYMENT DRILL WITH 150 PSI ON WELLHEAD -R/U EQUIPMENT AND HOSES FOR CIRCULATING PATHS -WORK THROUGH DEPLOYMENT CHECKLIST WITH RIG CREW,TRACING CIRULATING PATHS -ESTABLISH FLOW LOOP THROUGH PUMP IN MANIFOLD AND HOLD 150 PSI USING MPD CHOKE -PERFORM SURFACE DRILLS ALLOWING CHOKE HAND AND FLOORHAND TO PRACTICE USING MPD CHOKE 04:00 - 06:00 2.00 BOPSUR P PRE CONTINUE DEPLOYMENT/UNDEPLOYMENT DRILLS -PRACTICE DEPLOYING LATERAL BHA WITH STRAIGHT MOTOR 06:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE.DISCUSS DEPLOYMENT PROGRESS. DISCUSS RIG AND EQUIPMENT CONDITION. MAKE ROUNDS AND CHECKS. HOLD PJSM TO DISCUSS PRACTICE DEPLOYMENT PROCEDURE. 06:30 - 11:30 5.00 BOPSUR P PRE PRACTICE DEPLOYMENT FROM WHERE NIGHT CREW LEFT OFF. WORK WITH ODE AND WSLTO VERIFY AND MODIFY PROCEDURE AS REQUIRED. DEPLOY LATERAL BHA WITH 150 PSI ON WELL HEAD. UPDATE PROCEDURE. 11:30 - 12:30 1.00 BOPSUR P PRE REVIEW DEPLOY PROCEDURE WITH RIG TEAM. 12:30 - 17:00 4.50 BOPSUR P PRE PRACTICE UNDEPLOY PROCEDURE WITH CREW. MAKE NOTES TO DISCUSS MODIFICATION OF PROCEDURE. NEED FOR ADDITIONAL QUICK TEST SUB LUBRICATOR HARDWARE INDENTIFIED. WELL REMAINS STABLE USING 11.8 BRINE AND MPD LOOP WITH 150 PSI WHP. 17:00 - 18:00 1.00 BOPSUR P PRE REVIEW UNDEPLOY PROCEDURE WITH RIG TEAM. 18:00 - 19:00 1.00 BOPSUR P PRE CREW CHANGE.DISCUSS DEPLOYMENT PROGRESS. DISCUSS RIG AND EQUIPMENT CONDITION. MAKE ROUNDS AND CHECKS. HOLD PJSM TO DISCUSS PRACTICE DEPLOYMENT PROCEDURE. 19:00 - 00:00 5.00 BOPSUR P PRE PRACTICE DEPLOYMENT PROCEDURE P/U BHA FROM PIPE SKATE. WORK WITH ODE AND WSL TO VERIFY AND MODIFY PROCEDURE AS REQUIRED. ADD LUBRICATOR PUP WITH UPPER AND LOWER QTS CONNECTIONS DEPLOY LATERAL BHA WITH 150 PSI ON WELL HEAD. UPDATE PROCEDURE.. 11/30/2013 00:00 - 02:30 2.50 BOPSUR P PRE REVIEW DEPLOY PROCEDURE WITH RIG TEAM PJSM FOR UNDEPLOYMENT PROCEDURE Printed 12/9/2013 2:16:26PM • North America-ALASKA-BP Page 7 of 15 Operation Summary Report Common Well Name:S-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 End Date: X3-013RN-C:(3,802,503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud DateTme:12/7/2003 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292318300 — --- --- - --------------- --- Active datum:ORIG KELLY BUSHING @64.40usft(above Mean Sea Level) Date j From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 102:30 - 06:00 3.50 BOPSUR P PRE PRACTICE UNDEPLOY PROCEDURE WITH CREW.PJSM WITH CREW. MAKE NOTES TO DISCUSS MODIFICATION OF PROCEDURE. WELL REMAINS STABLE USING 11.8 BRINE I AND MPD LOOP WITH 150 PSI WHP. 06:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE. DISCUSS WELL AND RIG STATUS. MAKE EQUIPMENT CHECKS AND ROUNDS. 06:30 - 10:00 3.50 BOPSUR N WAIT PRE DISCUSS QUICK TEST SUB EQUIPMENT NEEDS FOR INJECTOR AND SLICKLINE LUBRICATORS. •WAIT ON CROSSOVER FROM SLB IN DEADHORSE. 10:00 - 13:00 3.00 BOPSUR P PRE DISSASSEMBLE LUBRICATOR COMPONENTS. REBUILD SLICKLINE AND INJECTOR LUBRICATOR ASSEMBLIES. 13:00 - 17:00 4.00 BOPSUR P PRE PRESSURE TEST SLICKLINE LUBRICATOR AGAINST SWAB VALVES. 250 AND 3500 PSI. PASSED. CHART SAME. PRESSURE TEST CT INJECTOR LUBRICATOR AGAINST SWAB VALVES. 250 AND 3500 PSI. PASSED. CHART SAME. 17:00 - 18:00 1.00 BOPSUR P PRE ,PRACTICE UNDEPLOY PROCEDURE\NTH CREW.PJSM WITH CREW. MAKE NOTES TO DISCUSS MODIFICATION OF PROCEDURE. WELL REMAINS STABLE USING 11.8 BRINE j AND MPD LOOP WITH 150 PSI WHP. 18:00 - 18:30 0.50 BOPSUR P PRE !CREW CHANGE. DISCUSS WELL AND RIG STATUS. MAKE EQUIPMENT CHECKS AND 'ROUNDS. 18:30 - 22:30 4.00 BOPSUR P PRE I PJSM FOR DRY STAB LUBRICATOR PUP ASSEMBLY P/U LUBRICATOR PUP ASSEMBLY WITH TUGGER AND M/U LOWER QTS TO WELL STAB INJECTOR AND M/U UPPER QTS TAKE MEASUREMENTS TO VERIFY BHA AND TOOL LOCATION INSIDE THE LUBRICATOR 22:30 - 23:30 1.00 BOPSUR P PRE PJSM AND BEGIN PRACTICE DEPLOY PROCEDURE WITH CREW WELL REMAINS STABLE USING 11.8 BRINE AND MPD LOOP WITH 150 PSI WHP. MAKE NOTES TO DISCUSS MODIFICATION OF PROCEDURE. 23:30 - 00:00 0.50 BOPSUR N WAIT PRE WITH BHA SUCKED UP INSIDE SLICKLINE LUBRICATOR,TRY TO MAKE SLICKLINE LUBRICATOR UP TO WELL QTS ON SLICKLINE LUBRICATOR STACKED OUT ON THE NO-GO RING REMOVE QTS AND ADD 3'PUP WITH OTIS CONNECTION TO BOTTOM OF LUBRICATOR 12/1/2013 00:00 - 00:30 0.50 BOPSUR P PRE CONTINUE REMOVE QTS AND ADD 3'PUP WITH OTIS CONNECTION TO BOTTOM OF LUBRICATOR 00:30 - 03:00 2.50 BOPSUR P PRE CONTINUE PRACTICE DEPLOY PROCEDURE WITH CREW.PJSM WITH CREW. MAKE NOTES TO DISCUSS MODIFICATION OF PROCEDURE. WELL REMAINS STABLE USING 11.8 BRINE AND MPD LOOP WITH 150 PSI WHP. Printed 12/9/2013 2:16:26PM • • North America-ALASKA-BP Page 8 of 15 Operation Summary Report Common Well Name:S-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 End Date: X3-013RN-C:(3,802,503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/7/2003 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292318300 Active datum:ORIG KELLY BUSHING @64.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 03:30 0.50 BOPSUR P PRE REVIEW DEPLOY PROCEDURE WITH RIG TEAM. 03:30 - 06:00 2.50 BOPSUR P PRE PRACTICE UNDEPLOY PROCEDURE WITH CREW.PJSM WITH CREW. MAKE NOTES TO DISCUSS MODIFICATION OF PROCEDURE. WELL REMAINS STABLE USING 11.8 BRINE AND MPD LOOP WITH 150 PSI WHP. 06:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE. DISCUSS DEPLOYMENT AND EQUIPMENT ISSUES. MAKE RIG EQUIPMENT CHECKS AND ROUNDS. 06:30 - 12:00 5.50 BOPSUR P PRE CONTINUE PRESSURE UNDEPLOY FROM NIGHT CREW PRACTICE. -DISCUSS NO-GO/QTS LUBRICATOR COMPATIBILITY ISSUE DISCOVER NO-GO PLATE WILL FIT IN LARGE QTS LUBRICATOR. GET WITH TOWN TEAM AND RE-DESIGN NO-GO PLATE. RE-CONFIGURE CT INJECTOR LUBRICATOR. PRESSURE TEST SAME TO 250/3500 PSI. PASSED. CHART SAME. 12:00 - 13:00 1.00 STWHIP P WEXIT MU WINDOW MILLING BHA(BHA#2). STAB COIL. TEST TOOLS. GET ON WELL. RUN IN HOLE. CIRC AT MIN RATE. 0.45 BPM AT 121 PSI. 13:00 - 14:30 1.50 STWHIP P WEXIT RUN IN HOLE. CIRC AT MIN RATE WITH EDC OPEN. 14:30 - 15:30 1.00 STWHIP P WEXIT LOG GR TIE IN FROM 7800'TO 7966'. SUBTRACT 22'CORRECTION. TIE IN TO PDC LOG FROM GEO/TOWN. CORRELATION IS GOOD. TAG WHIPSTOCK AT 7996' CORRECTED. 40K#UP WT. 15:30 - 19:30 4.00 STWHIP P WEXIT PJSM TO DISCUSS DISPLACEMENT FROM 11.8 BRINE TO 9.6 PPG MUD. CIRC MUD DOWN COIL AT 1.0 BPM. COIL VOL:58.7 BBLS. BHP:4180 PSI. ECD:12.20 WHILE CIRC WITH BRINE AT 1.0 BPM. CONTINUE DISPLACEMENT WITH MUD UP CT ANN. MAINTAIN 4200 PSI BHP WITH SUPER CHOKE. SLOWL.Y INCREASE WHP TO TARGET PRESSURE OF 777 PSI. 19:30 - 20:30 1.00 STWHIP P WEXIT CREW TRAINING ON SUPER CHOKE. 20:30 - 00:00 3.50 STWHIP P WEXIT TIME MILL WINDOW AT 7995'MD TO 7997'MD \ A ,c1rAttir PUMP IN AT 2.62-OUT AT 2.64,PRESSURE `^"n` \v S-1(� ON 2540 PSI � WOB-2K,ECD-10.82, MW IN-9.7,OUT-9.62. 1 \� PVT-352 ROP-.7 FPH,IA-320,OA-403 PSI,UP WT-40K, DN WT-17K METAL CUTTINGS IN RETURNS NOTE:BLED DOWN IA FROM 850 PSI TO 250 PSI. ESTIMATED FLUID RETURN 5 GALLONS. Printed 12/9/2013 2:16:26PM • North America-ALASKA-BP Page 9 of 15 Operation Summary Report Common Well Name:S-116 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/23/2013 End Date. X3-013RN-C:(3,802,503.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/7/2003 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292318300 Active datum:ORIG KELLY BUSHING @64.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/2/2013 00:00 - 06:00 6.00 STWHIP P WEXIT TIME MILL WINDOW AT 7997'MD TO 8001'MD PUMP IN AT 2.62-OUT AT 2.64,PRESSURE ON- 2540 PSI WOB-2K,ECD-10.82, MW IN-9.7,OUT-9.62. PVT-352 ROP-.7 FPH,IA-454,OA-460 PSI,UP WT-40K, DN WT-17K METAL CUTTINGS IN RETURNS 06:00 - 06:30 0.50 STWHIP P WEXIT CREW CHANGE. DISCUSS FUILDS, EQUIPMENT,AND OPERATIONS. MAKE RIG CHECKS AND ROUNDS. CONFIRM FLUID LOCATION AND VOLUMES. CONTINUE TO MILL WINDOW. 06:30 - 07:00 0.50 STWHIP P WEXIT REAM WINDOW UP AND DOWN WITH THREE PASSES. DRY DRIFT with pumps off. smooth. 2644 PSI FS AT 2.61 BPM IN/OUT. WHP/BHP/ECD:381 PSI/3986 PSI/11.55 PPG 07:00 - 08:00 1.00 STWHIP P WEXIT MILL WINDOW TO 8008. 2644 PSI FS AT 2.61 BPM IN/OUT. WHP/BHP/ECD:381 PSI/3986 PSI/11.55 PPG 08:00 - 11:00 3.00 STWHIP P WEXIT PJSM TO DISCUSS DISPLACEMENT TO 11.8 PPG BRINE. CIRCULATE OUT OF HOLE AT 1:1. LAY IN BRINE. MAINTAIN BHP OF 4150 PSI OR 11.8 PPG EQUIVALENT USING TRIP SCHEDULE. 11:00 - 12:30 1.50 STWHIP P WEXIT HOLD PJSM. FLOW CHECK. GET OFF WELL. UNSTAB COIL. LD MILLING BHA. MILL GAUGE 3.79". STRING REAMER 3.80". CHECK TREE BOLTS. ALL SNUG. 12:30 - 14:00 1.50 DRILL P WEXIT HOLD PJSM. MU BUILD BHA(#3) 3.6 AKO 2-7/8"INTEQ LOW SPEED MTR W/HTC 4-1/8" REBUILD BICENTER BIT. STAB COIL. TEST TOOLS.GET ON WELL. 14:00 - 16:00 2.00 DRILL P WEXIT RUN IN HOLE. STOP AT 2714'TO BRING ADDITIONAL MUD IN PITS. CONTINUE TO RUN IN HOLE. 16:00 - 16:30 0.50 DRILL P WEXIT LOG GR TIE IN FROM 7850'. SUBTRACT 26'CORRECTION. 16:30 - 17:30 1.00 DRILL P WEXIT CLOSE EDC. DISPLACE WELL TO 9.6 PPG FLO VIS. 17:30 - 23:00 5.50 DRILL P PROD1 DRILL AHEAD FROM 8008'TO 8129'MD WOB 2-4 K-LBS CIRC RATE 2.85 BPM,CIRC PRESSSURE: 3350PSI MW IN/OUT 9.76/9.68 PPG ECD 12.01 PPG IA/OA/PVT:650PSI/515PSI/331 BBLS ROP 20 FPH. 23:00 - 00:00 1.00 DRILL N WAIT 8,129.00 PROD1 WAIT ON ORDERS.VERIFY DIRECTIONAL PLAN WITH TOWN GEOLOGIST, CONFIRM WITH ODE BEFORE DRILLING AHEAD.NO CHANGE TO PLAN CONTINUE DRILLING TO DIRECTIONAL PLAN #3. Printed 12/9/2013 2:16:26PM TREE= 4-1/16"CNV SAF, .TOTES:H 2S READINGS AVERAGE 125 ppm • WELLHEAD= FMC S-116 MEN ON MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR= — LEO • INITIAL KB.Ell 66.4'' BF.ELEV= 36.2'' Ili I KOP= 500' 1017' —9-5/8"TAM PORT COLLAR Max Angle= 51°@ 3046' Datum MD= 7963' Datum TV D= 6700' ' 2195' —4-1/2"HES X NIP,ID=3.813" 9-5/8"CSG,40#,L-80,ID=8.835" —I 3450' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 4550 3751 31 KBG-2 DMY BK 0 07/12/04 Minimum ID = 3.79" @ 7809' l' 1 7630 6451 21 KBG-2 DMY BK 0 12/19/03 4-1/2" HES "MILLED" XN NIP 1 I 7699' H4-1/2"HES X NIP,D=3.813" XI X 7761' —7"X 4-1/2"BKR PREM R(R,D=3.875" ' ' 7788' —14-1/2"HES X NIP,D=3.813" I I 7809' J4-1/2"HES XN NIP, MILLED TO 3.79"(10/04/13) 4-1/2"TBG,12.6#,L-80,.0152 bpf, ID=3.958" H 7820' / \ 7,821' H4-1/2"WLEG,ID=3.958" 0 7927' —I7"MARKER JT W/RA TAG v 4-1/2"X 7"BKR GEN II WHIPSTOCK(9/22/13) —I 7990' IA' �� i`i 7995' HTOC(10/04/13) PERFORATION SUMMARY 111111111111111 111111111111111111111 REF LOG: FEX 12/14/03 1111111111 ANGLE AT TOP PERF: 19°©7982' 111111111111111111111 11111111111111111111 Note: Refer to Production DB for historical perf data (111111 1111 SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 111111111111111111111 3-3/8" ® 5 7982-7994 S 04/29/04 10/04/13 11111111111111111111 3-3/8" r 5 8001 -8014 S 04/29/04 10/04/13 111111111111111111111 111111111111111111111 810T 7"MARKER JT W/RA TAG 3-3/8" ' 6 8100-8112 S 04/29/04 10/04/13 111111111111111111111 111111111111111111111 11111111111111111111 1111111111111111111111 1 PBTD — 8199' 1�1�1�1�1�1�1�111�1 7"CSG,29#,L-80,.0371 bpf,ID=6.184" 8279' •1111111111 111111 11111 11111111111 DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 12/19/03 TM N/KK ORIGINAL COMPLETION 05/25/13 WEC/PJC PULL IBP/LEFT UP HOLE(5/22/13) WELL: S-116 02/15/11 MB/JMD ADDED SSSV SAFETY NOTE 06/04/13 SWC/JMD PULLED IBP(05/29/13) PERMIT-No:'2031810 01/19/12 TMN/JMD ADDED H2S SAFETY NOTE 10/03/13 SET/JI)/EI SETTHRU WHIPSTOCK(9/22/13) API No: 50-029-23183-00 05/13/13 KS/JMD DATUM CORRECTION 11/24/13 AM/PJC'MILL XN/CMT SQZ(10/04/13) SEC 35,T12N,R12E, 1009'FNL&778'FWL 05/14/13 RM/PJC SET DP(05/13/13) 05/14/13 RM/PJC ACTUATOR CORRECTION BP Exploration(Alaska) OF Tt.t� • • yw\-I//j, s. THE STATE Alaska Oil and Gas ' 0 fALl lsKA Conservation Commission - GOVERNOR SEAN PARNELL 333 West Seventh Avenue A'ALAS �. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 3,0 3 IS 1 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-116 Sundry Number: 313-489 %WED ktIV 8 MS Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, Commissioner DATED this of September, 2013. Encl. • STATE OF ALASKA • Cg;0 RECEIVED • ALASPOIL AND GAS CONSERVATION COMMISSION CV' S E P 112013 APPLICATION FOR SUNDRY APPROVAL r0-rs °1Iz 20 AAC 25.280 AOGC0 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. ❑Exploratory ❑Stratigraphic 203-181 ' 3. Address: ❑Development ®Service • 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-23183-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? pBU S-116 ' Will planned perforations require a Spacing Exception? ❑Yes ®No 9. Property Designatior 10.Field/Pool(s): , �'( �z,� ADL 028257&028258• Prudhoe Bay Field/Aurora Pool /1,,,L,r3 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft) Effective Depth TVD (ft): Plugs(measured): Junk(measured): 8291' 7075' 8200' 6988' None None Casing Length Size MD ND Burst Collapse Structural _ Conductor 110' 20" 110' _ 110' 1490 470 Surface 3422' 9-5/8" 28'-3450' 28'-2939' 5750 3090 Intermediate Production 8253' 7" 26'-8279' 26'-7063' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7982'-8112' 6782'-6905' 4-1/2", 12.6# L-80 7821' Packers and SSSV Type: 7"x 4-1/2"Baker Premium Packer Packers and SSSV 7761'/6574' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal IN BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ❑Development ®Service• 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: September 10,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Suspended • Commission Representative: ❑WAG ❑SPLUG ,_ 17. I hereby certify that the foregoin• is true and correct to the best of my knowledge. Contact: Trevor Hyatt,564-4627 Printed Name: Joh%al. ri " Title: Engineering Team Leader E il: Trevor.Hyattebp.com Signature: 4 Phone: 564-4711 Date: q q /3 I" Commission Use Only _ Conditions of approval: Notify Commission so that a representative may witness ' 01... .. �� Sundry Number: ❑Plug Integrity 10/13/0P Test ❑Mechanical Integrity Test,❑Location Clearance Other: 50 p i_z S t r° 3 SD d p s i 4-He ila fc itv p MCI' rkJ f appra v rd per ao fl-,-G 25./1 ZC�,� p ` Spacing Exception Required? ❑Yes I3 No Subsequent Form Required: /U 407- RBDMS OCT 1 0 101 J ,f�(/ APPROVED BY Approved By: ✓ ��"� jj''�� COMMISSIONER THE COMMISSION Date: 9 — �� Form 10-403 evised 12012 Appr¢v Rpicei iiNIAo112 months from the date of approval Submit In Duplicate kyr g!/y-1/3 L '1 cv \-1, i • • To: Alaska Oil & Gas Conservation Commission From: Trevor Hatt by Y CTD Engineer Date: September 4, 2013 Re: S-116i Sundry Approval Sundry approval is requested to plug the S-116i perforations as part of drilling and completing the proposed S-116Ai coiled tubing sidetrack. History of S-116i: S-116i was drilled as part of an injection development plan for the Aurora "Crest" structure. The well was planned to support S-117, S-115, and S-118 producers. S-116 was drilled in December 2003, with first injection starting on 8/6/2004. The well had a brief (two week) period of pre-production to clean up the well and enhance injectivity. Over the life of the well, S-116 typically injected produced water; however, it had a period of MI injection from early 2007 to mid-2008. The well was SI from April 2009-June 2011 for pressure maintenance. S-116 was put on injection again from June 2011 until December 2012. Reason for sidetrack: The well is currently SI due to lack of offtake in the area. Its ready ✓ for a CTD sidetrack. The proposed sidetrack will access a target in Kuparuk C sands. Proposed plan for S-116Ai: Drill a through tubing sidetrack with a Coiled Tubing Drilling rig on or around November 108t, 2013 with Nordic 2 using the managed pressure drilling technique. The sidetrack, S-116Ai, will exit the existing 7" casing and kick off in Kuparuk C sands. This sidetrack will be completed with a 3-1/4" liner cemented in place and a 2-3/8" slotted liner in the production interval (if drilling conditions allow, the well will be completed with 3-1/4" to TD and cemented, no 2-3/8" slotted liner). This Sundry covers plugginq the existing S-116 perforations via the S-116Ai primary liner cement iob and a liner top packer if / the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. C/i�1 c?/JeCI 6,9 J'7 'ecbef�i %"- C o�Cu!• The well ,s fco`' cee ?creed ecit en 4',/.) 5.; 7.0'. 4k/i7 /Ael 7(3 i cothio /itovi&,c iNnete ye loc cfh ;cc , fro 1,14t / • • a` 1. S Drift for 4-1/2" x 7" TT whipstock to 8,100'. o No Mill XN at 7,809' to 3.80". 2. E Set 4-1/2" x 7" TT whipstock at 7,990'. o No Cement whipstock in place by pumping 20 bbls of 15.8 ppg 7 class G cement (attempt to down squeeze 12 bbls). ` ' Cement volume: ✓ N No i. Bottom to top open perfs: 8 bbls !� ii. Squeeze: 6 bbls M 3. C iii. Excess: 6 bbls 4. F MIT-T to 2,400psi. LLR if test fails. N No 5. V Torque tree & PT Tree/barriers - MV, SV, WV. N No Bleed wellhead, production, flow, and GL lines down to 6. 0 zero and blind flange. No No 7. 0 Remove wellhouse and level pad No No j S 8. V If MIT-T fails, set TWC & leave for the rig. No No dvnct r,1 • ,r i % r/ ;r! -/mil/ ar/rfF - 1. MIRU and test BOPE 250 psi low and 3,500 psi high. / o �Fes7 2. Mill 3.80" window at 7,990' and 10' of rathole. `- 3. Drill build section: 4.125" OH, 295' (40° deg/100 planned). o Yes t w Drill first lateral section: 4.125" OH, 561' (12° deg/100 planned) with resistivity. (If drilling conditions allow, the p-T-D 4.125"OH lateral section will be extended to TD, 10,515' MD. The well will then be completed with 3-1/4"to TD and 5. cemented/perforated, no 2-3/8"slotted liner) No Yes 6. Run 3-1/2" x 3-1/4" L-80 liner leaving TOL at 7,800' MD. No Yes Pump primary cement leaving TOC at 7,800' MD, 17 bbls of 7. 15.8 ppg liner cmt planned. Yes* Yes 8. Test liner lap to 2500 psi and swap to 2" coil tubing. No Yes 9. Mill out 3-1/4" shoe track. No Yes Drill second lateral section: 3" OH, 1,669' (12° deg/100 10. planned) with resistivity. No Yes Run 2-3/8" slotted liner leaving TOL at 8,800' (-50' inside 3- 11. 1/4" intermediate liner) No Yes 12. Freeze protect well to 2500' MD No Yes 13. Set BPV, 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 liner top packer, if needed, with slickline & test to 2,500psi. 3. Set generic GLV's, SBHPS, ASRC flow back, SIT. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 564-4627 TRH= 41!16"CIW • SA TES:H 2S READINGS AVERAGE 125 ppm . 'I LHEAD FMC WH N MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR= LE _ MI. NTIAL KB.ELT— _ 66.4' BF.6.EV= __— 362 I KOP___-..__.___.__.._.._ &lb. 2-1 1017' H9-5/8"TAM PORT COLLAR Max Angle= 51'@3046' -Datum MD= 7963' DatumTVD= 6700' I I I 2195 I-14-1/2"HES X NP,D=3.813" I 9-5/8"CSG,40#,1-80,ID=8.835" H 3450' _A ' Minimum ID = 3.726" @ 7809' GAS LFT MANDRELS 4-1 i2" HES XN NIPPLE ST MD TVO DEV TYPE VLV LATCH PORT DATE 2 4550 3751 31 KBG-2 DMY BK 0 07/12/04 1 7630 6451 21 KBG-2 DMY BK 0 12/19/03 ' 1 I 7699' H4-1/2"HES X NP,0=3.813" I El I 7761' Hr x 4-1/2"BKR PREM PKR,D=3.875" ' M I 7788' H4-1/2"HES X NP,D=3.813' I ' '� I 7809 J—$4-1/2"FE5 XN NP,D=3.725" I P 4-1/2"TBG,12.6#,L-80,.0152 bpf, D=3.958" —I 7820" —/ I 7,821' I—j41/2`W1EG,D=3.958" I I 7927' I-17"MARKER JT W/RA TAG PERFORATION SUMMARY ,, ' 2 FEE LOG: P X 12/14/03 . _ NI I o ANGIE AT TOP FEW:: 19°Q 7982' "---i--1.4 b II Note:Refer to Roduction DB for historical pert data / SIZE SW MBNAL Opn/Sqz SHOT SQZ I 3-3/8" R 5 7982-7994 0 04/29/04 3-3/8" ' 5 8001-8014 0 04/29/04 3-3/8" ' 6 8100-8112 0 04/29/04 I I 8102' H7"MARKER ST W/RA TAG / PBID --I 8199' W••W•W•vf !•t•44•4•4441 7"CSG,29#,L-80,.0371 bpf,0=6.184" --I 8279' ∎R♦M•M•M•M•M•M•M•M•M•1 [SATE REV BY, CONSAIENTS . DATE REV BY COMMITS I AURORA UNIT 12/19/03 TMI410( ORIGINAL COMPLETION 05/25/13 WEC/RIG PULL BPI LEFT UP HOLE(5122/13) WELL S-116 02/15/11 MB/JMD ADM)SSSV SAFETY NOTE 06/04/13 SWC`/JMD'PULLED BP(05/29/13) PRAT No: 2031810 01/19/12 718■fJt4/0 ADDED l-PS SAFETY NOTE API No: 50-029-23183-00 05/13/13 KS/JMD DWTUut CORRECTION SEC 35,T12N,R12E,1009'FNL&778'FWL 05/14/13 RM PJC SET BP(05/13/13) I 05/14/13 RIW PJC ACTUATOR CORRECTION BP Exploration(Alaska) j , TT1LL= 4-1/16"C3V1/ • SAE OTES:H 2S READINGS AVERAGE 125 ppm . A LI-EAD= FMC WH N MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR= LEO PROPOSED S-116A MI. ENETIAL KB.EiE 66.4' BF.E3EV= 362' KOP= 500' — = 1017' H9-518"TAM FORT COLLAR Max Angie= '@,--_____' Datum MD= Datum1VD= 6700' 2195' 4-1/2"HES X NT',D=3.813" 9-5/8"CSG,40#,L-80,ID=8.835" H 3450' A ' GAS LFT MANORB S Minimum ID = ° @ ST MD TVD DEV TYPE VLV LATCH FORT DATE L 2 4550 3751 31 KBG-2 DMY BK 0 07/12/04 1 7630 6451 21 KBG-2 DMY BK 0 12/19/03 ' 7699' —14-1/2"F ES X NV,D=3.813" 7761' f--7"X 4-1/2'BKR MBA PKR D=3.875' I 7788' H4-1/2"HEs x NP,D=3.813" 7800' I—TOL 7809' —14-1/2"HES XN NIP,D=3.725" L. H3-1/2"HE2SXMP,Dr 1 I3-1/2"LNR, #,_ , bpf,D= —{ ) i H3-12"X3-1/4"X0,D=___," I 4-1/2"TBG,12.6#,L-80,.0152 bpf, ID=3-958" H 7821' I \ - I 7,821' —1412"WLEG,D=3.958" 17"X 4-1/2'WF 'STOO((_/__i_) H 7990' r MILLOUT WINDOW (S-116A)-7990'- ' 17"CSG,29#,L-80,.0371 bpf,D=6.184" —1 --7990' .- HTCK 13-1l4"LN2, #,_ , bpf,D=�." — 8846' ` ' (, II PERFORATION SUMMARY REF LOG: ON /_/ ANGLE AT TOP PE RF: _"@ I I Note:Refer to Roduction DB for historical pert data I I SQE SPF INTERVAL Opn/Sgz SHOT SQZ SLID I I I I PBTD --I ' I I 12-318"LW, #, ____bpf,D=__" —1 10515' A L DATE REV BY COMN9NTS DATE REV BY COMMENTS AURORA UNIT 12/19/03 TMWKK ORIGINAL COMPLETION WELL: S-116A 08/16/13 AC BOLT PROPOSAL PERMIT No. 08/29/13 TWJMAD C HANGW 2-3/8"[IC TO SLOTTED AR No: 50-029-23183-01 08/30/13 TWJMO PROPOSAL REVISIONS SEC 35,T12N,R12E, 1009'FTt_&778'FWL BP Exploration(Alaska) NORDIC CTD UNIT# 2 CHOKE / REEL/ CIRCULATION MANIFOLD DIAGRAM /'-- - - _' Choke P/el Standpipe 2'Circulation Line � /,^ } BOP 26 •' Y •as•MM 11 1461 ter,. i j i -G.aliSta ' Driller Gauye�• - -. M 10 •-. Manual Choke O©.` i IP CIRCULATING MANIFOLD MM 8 MM 9 MM 16 MM 15 8 • a#4 - BOP 28\ I ', et I SLB Transducer — :`•MM6 ®= �\ i , I • - PVT Sensor \y I • I BOP 10 � I r MM • • Baker Choke , �.• I MM13 MM4 N MMI7 . c. ... 'S I I• Rev C r Line ` . BOP 1f-Btlnd/Shear -_Last Update 20-Aug-13 -, fAir Blow down MEO: . MM74 a- • Z.. ` / 01 Updated by Udo Cassee -. * ` BOP 12 R Pipe/Slip !i� • • • • BOP 24 BOP si BOP 19 VALVE MANURE KILL SIDE I I 4 CHECK VALVE L MAN LVE L BOP 13 BOP 20 el VALVE _ BOP 21 CHOKE SIDE OP Coiled Tubing !. MM 18 / BHAPp Pipe/Slip ,. ^,4 MANUAL VALVE 0 1 ! Be' r Choke / OP BHA Pipe/Slip /BOP 22 CHOKE HCR VALV 0/ n is f I MP ®o MP1 •e I T ti I � '.ar �4 ri-al �triMNl 1;1 MW) I •...0 Kill Line -. I / -. HP 11 HP 10 r_. TranduT.erU. COILED TUBING I / I !` III w Choke Line I / BOP 15 • Blind/Shear_.-- - - } .� CIRCULATING SYSTEM I I P f " ". Kill Line--e./ + IIIIIIIIIIIIIMI ® XP 18 �' �"`• --'r" CSM 1 CSM 2 .` BOP 16 R Pipe/Slip I BOP 18 HP 14 -k= To Inner Reel/ I ... _ ..._ F ` ._ \BOP 17 I I Valve/ I ' '� HP 15 HP 7 HP HP 4 HP3 / I CSM 3 CSM 4 0 HOP 4 f HP 13 HP HP• / I CSM7 � BOP3 BOPS i HP 12 CSM 6" @ 11 \ HP 18 / / (gall iI1 '- F It A irAr: // '♦ BOP 2 III � ` cement line N2 = SLB et' BOP1 s CHOKE MANIFOLD �!BOP 6 P17 N2TriFlow 14 CM85 FAGS • Gauge y� l I CM 29 1 ia. CHO.use OAS BUS _ BOP 30_ Test Pump Inletj� CM 30 / — ly"1' CM3 / Lr �. BOP 29 1 �J / Hr auge PB1 gg�1i / / _ _ NI X13 / Flow 9 HC / Not tl 4W"Block M14 CM1/ CM. ' CM24 --- PB2 iqui • I legs C C C..: C•. 1 m' - 10' I P Baker Choke Line _ _ -•: • high from wal O CM13 =MO 111=IMIZI MI=EIMINMI • 1 mil i/ CM15 CM2 make - ' J POSSUM BELLY /T Mo.. t :::CM2: p' CM4 ,���'-'-' 1 III III CM 25 CHOP F riue `_J—� r : : la k,,,CM26 �.• ., 'Iva moll net: ® CM18 CM19 ----- __ -1. CM27 CM27 TIGER TANK / Nordi Calista ConfiderkiP1 Tank Olt • • Ferguson, Victoria L (DOA) From: Hyatt,Trevor <Trevor.Hyatt@bp.com> Sent: Wednesday, September 18,2013 12:33 PM To: Ferguson,Victoria L(DOA); Lastufka,Joseph N;Johnston, David Subject: RE: PBU S-116 (PTD 203-181, Sundry 313-489) Victoria, See the below reservoir pressure information that you requested for S-116Ai. Reservoir Pressure: • The reservoir pressure on S-116Ai is expected to be 3,594 psi at 6,700' TVDSS. (10.31 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,924 psi. Let me know if you need anything else from me. Thanks Trevor Hyatt BP Exploration(Alaska), Inc. Coil Tubing Drilling Engineer Trevor.Hvatt@bp.com Office:907-564-4627 Cell: 907-223-3087 Fax: 907-564-5510 From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson @alaska.gov] Sent:Tuesday, September 17, 2013 10:07 AM To: Lastufka, Joseph N; Johnston, David; Hyatt,Trevor Subject: PBU S-116 (PTD 203-181, Sundry 313-489) Same issue. Please forward the MPSP. From: Ferguson, Victoria L(DOA) Sent:Tuesday, September 17, 2013 9:33 AM To: Lastufka,Joseph N (Joseph.Lastufka @ bp.com); david johnston2 @bp.com Subject: PBU A-24(PTD 182-070, Sundry 313-490) Joe,David, I just received this sundry which should be a plug for redrill. I notice in your table you note that a sundry(10-403)is not required to do the plug for redrill. This is not correct. An approved sundry is required for a plug for redrill. Also, please forward the MPSP. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 1 r • • Roby, David S (DOA) From: Schultz, Kirsten L <Kirsten.Schultz@bp.com> Sent: Friday, September 13, 2013 9:40 AM To: Roby, David S (DOA) Cc: Hyatt, Trevor Subject: RE: Sundry application to plug PBU 5-116 for redrill Dave, S-116 was originally drilled to support S-117, 115, and 118. We have seen baffled support from S-116 to S-117 and S- 115, but not very efficient sweep. An injector, S-134, is positioned between S-116 and the producers S-115 and 5-117. This creates a high pressure baffle.We have not seen evidence of support to S-118. S-116 will be sidetracked to the south to provide support to S-129,and S-117 and 5-115 will be supported by S-134 and more northern injectors. Thanks, Kirsty Schultz NWD PE-SaLMoN Team Office: 907-564-5105 Cell: 907-350-4310 S OOT • .� \8-jO4 \, - -1bOH �ti" -1Q5 �'� • $ -113 34g%* ,�,s.108 .S• ifrit1,3A Kuper) - �A - • S-1O1T * l '. A S 109T r1 8-115 3-11 `� � ,�} • -112 -108ir10. 10 11'7 s„1 $ �-- _. ,w., A 8S-1 j`'"• )d $-124 s� A r 8.1414 5.1 ! .1 `�. �~�” -. ii -O9 i l SDT ` K From: Hyatt,Trevor Sent: Thursday, September 12, 2013 2:14 PM To: Schultz, Kirsten L Subject: FW: Sundry application to plug PBU S-116 for redrill Can you help me out with this question? Trevor Hyatt 8P Exploration (Alaska),Inc. Coil Tubing Drilling Engineer I. • • Trevor.Hvatt @bp.com Office:907-564-4627 Cell: 907-223-3087 Fax: 907-564-5510 From: Roby, David S (DOA) [mailto:dave.roby(aalaska.gov] Sent: Thursday, September 12, 2013 1:56 PM To: Hyatt,Trevor Subject: Sundry application to plug PBU S-116 for redrill Trevor, I am reviewing the subject application for potential impacts on reserves and I have a question. In the application it says the subject well was drilled to support the S-117,S-115,and S-118 wells and then goes on to say the reason for sidetrack is a lack of offtake. In reviewing the production data it appears that A-115 and S-117 are producing quite nicely while S- 118 never really produced well. So my question is, has the interpretation changed and in fact the S-116 well is not supporting production from the S-115 and S-117 wells? Regards, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 2 ~ . Anchorage, Alaska 99519-6612 June 25, 2009 t ~~= ~ ~ ~~ ~~~ ~~°-~~ ~-~ Mr. Tom Maunder ~1vL ~ ~~ 2009 Alaska Oil and Gas Conservation Commission ~~~~~~ ~~! ~~~~ ~~~~,~ ~~~r~~~~~~€~ 333 West 7th Avenue brs~~a~c~~c~~ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad ~~~ v~$~ Dear Mr. Maunder, `~ ' ~~~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~ r ~;!~r~ ; ~.~ ,~,~ ~~~~~;.r, a , ~'~ ~' Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report ot Sundry Oparations (10-404) S-pad Date 6/25/2009 Well Name PTD A Initial top ot cement Vol. of cemern um ed Final rop of cement CemeM rop oif date Cortosion inhibitor Corcosion inhibitod sealant date ft bbls ft na al 5-0~8 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 7821650' 0 NA 0 NA O.s 5/2&2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 5-088 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-11B 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1/2009 S-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-78A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19l2009 S-20A 20f0450 025 NA 025 NA 1.3 5/79/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1901270 025 NA 0.25 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982740 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/37l2009 S-29AL1 1960720 0 NA 0 NA 0.85 5/27/2009 S-30 1900660 0.5 NA 0.5 NA S.t 5/37/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 S/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-3a 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 NA .85in 5/31/2009 S36 7921160 0.75 NA 0.75 NA 425 5/27/2009 S37 1920990 125 NA 125 NA 11.9 5/27/2009 S-38 1921270 0.25 NA 025 NA 10.2 5/27/2009 S-47 1960240 1.5 NA 1.5 NA 71.7 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA t.7 5/28/2009 5-44 1970070 0.25 NA 025 NA 1.7 5/28/2009 S•700 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 125 NA 125 NA 11.9 5/29l2009 S-to2L1 2031560 125 NA 125 NA 71.7 5/37Y2009 5-703 2001680 1.5 NA 1.5 NA 71.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 1625 NA 1625 NA 774.3 6/2/2009 5-107 2011130 225 NA 225 NA 26.9 5/78/2009 S-7o9 2011000 3.5 NA 3.5 NA a0 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-110 2011290 11.75 NA 71.75 NA 98.6 5/30/2009 S-~ ~ t 2050510 2 NA 2 NA 19.6 5/30l2009 S-112 2021350 0 NA 0 NA 0.5 5/30/2009 S413 2021430 1J5 NA iJ5 NA 22.1 5/18/2009 5-114A 2021980 125 NA 125 NA 102 5/30/2009 S-t~5 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 1.5 NA 1.5 NA i3.6 5/28/2009 5-1~7 2030120 1.5 NA 1.5 NA 15.3 5/29/2~9 5-118 2032000 5 NA 5 NA 76.5 5/28/2009 5-779 2041620 1 NA 1 NA 52 5/30/2009 S-120 2031960 5.5 NA 5.5 NA 672 5/29/2009 S-121 2060410 4.5 NA 4.5 NA 53.6 5/28I2009 S-~22 ~ 2050810 3 NA 3 NA 27.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 1.75 NA 77.9 5/26/2009 5-125 2070830 225 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 125 NA 15.3 6/1/2009 5-200 1972390 125 NA 125 NA 14.5 5/28/2009 5-207 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6Ii/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-277 2070950 025 NA 025 NA 1.7 6/1/2009 S-400 2070740 2 NA 2 NA 9.4 5/28/2009 S~407 2060780 16 NA 16 NA 99.5 6/2/2009 S•504 0 NA 0 NA 0.85 5/28/2009 I • MEMORANDUM • TO: Jim Regg ~~~~ ~ ~~~ P.I. Supervisor ~ 2' FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, March 02, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-116 PRUDHOE BAY UN AURO 5-116 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~ Comm Well Name: PRUDHOE BAY UN AURO S-116 API Well Number: s0-02 9-23 1 8 3-00-00 Inspector Name: John Crisp Insp Num: mitJCr090302074s29 Permit Number 203-181-0 - Inspection Date: 2/2sl2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel] 5-116 Type Inj. W TVD ~ 6574 ~ IA ~ 440 4020 v 3980 3980 p,T. 2031810 " -- -- --- TypeTest SPT Test psi 1643.5 QA I 230 270 L---- 270 270 Interval aYRTST p~F P ;/ Tubing 1 zsoo ~ 2soo 2soo 2soo Notes' Well was found with ansi 1500 flange on IA. Test would not proceed until flanges were replaced. Flanges replaced & tested OK. /" ~- ~'~-~u,`'s~~ ~~ P~t~ z-(z~~o ~ a ~p~ c~~ LPs ~~ o~~ ~~ yy ©~ ~ ~~ Monday, March 02, 2009 Page 1 of 1 • ~- - ~,: ~~ ~~..,. >~ _ MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc Permit to Drill 2031810 MD 8291"'- REQUIRED INFORMATION ~ Cf ~ ,1.JH\ ~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Well Name/No. PRUDHOE BAY UN AURO S-116 Operator BP EXPLORATION (ALASKA) INC 'Icv:l- 7 ~~.3 API No. 50-029-23183-00-00 ~ TVD 7075,. Completion Date 4/29/2004 Completion Status WAGIN Current Status WAGIN Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / RES / GR, PEXlc, MDT, USIT Well Log Information: Log/ Data Digital TYPyMed/Frmt ¿g 4' ¿'D ~C Lis It;? 6.dg ~ yvc .,..I::'"og ..,/ Log Electr Dataset Number Name Cement Evaluation Log Log Scale Media 5 Col Directional Survey / J1.¡.J Directional Survey ~ Induction/Resistivity Induction/Resistivity 25 Blu I nd uction/Resistivity 25 Blu 13454 Induction/Resistivity 25 Blu Gamma Ray 5 Blu Gamma Ray 5 Blu Well Cores/Samples Information: Name Interval Start Stop Sent Directional Survey ~~ ----- (data taken from Logs Portion of Master Well Data Maint Run No 1 Interval Start Stop 7540 8150 . OH/ CH Received Comments 2/11/2005 USIT/GR/CCL-JEWELRY LOG 0 8291 1/22/2004 0 8291 1/22/2004 3298 8285 Open 9/28/2005 PEX-BHC-GR ~ 3447 8280 Open 9/28/2005 QUAD COMBO PEX-BHC 15 Dec 2003 'Ff..P 3447 8280 Open 9/28/2005 QUAD COMBO PEX-BHC 15 Dec 2003 f1¡ 1) 3447 8280 Open 9/28/2005 QUAD COMBO SS TVD PEX-BHC 15 Dec 2003 300 8232 1/9/2006 FinaLlsUFinaLtif/Final MD & TVD PDS 300 8232 1/9/2006 MEASURED DEPTH LOG . COMPOSITE FINAL PRINT 300 8232 1/9/2006 TRUE VERTICAL DEPTH LOG COMPOSITE FINAL PRINT Received Sample Set Number Comments Permit to Drill 2031810 MD 8291 TVD 7075 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? 'f-i..W- Analysis Received? ~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Well Name/No. PRUDHOE BAY UN AURO S-116 Operator BP EXPLORATION (ALASKA) INC Completion Date 4/29/2004 Completion Status WAGIN Daily History Received? Formation Tops L / Current Status WAGIN ~IN ~/N Date: API No. 50-029-23183-00-00 UIC Y ~ 1 ß;)vM¥ . . RECEiVED 12/28/05 Schlumberger JAN 0 9 2006 ~ Cii & Gas eons. Cof[U11lssicn Anchornge NO. 3634 Schlumberger·DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska 011 & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Well Job# Log Description Date Color BL CD Z-100 40009858 OH LDWG EDIT OF MWD/LWD 12102103 Z-100 40009858 MD CDR-GR 12102103 Z-100 40009858 TVD CDR-GR 12102103 S-116} 40009909 OH LDWG EDIT OF MWDILWO 12114103 5-116 ;.203-12 ( 40009909 MO CDR-GR 12114/03 5-116 40009909 TVD CDR·GR 12114/03 . 5-120 40009967 OH LDWG EDIT OF MWD/LWD 12128/03 5-120 40009967 MD COR-GR 12/28/03 5-120 40009967 TVD COR-GR 12128103 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnica Data Center LR2a1 900 E. Benson Blvd. Anchorage, A/aska 99508 Date Delivered: Sch/umberger-DCS 2525 Gambel! St, Suite 400 Anchorage, AK 99503-2838 ::~~ètJ . Sdlumbepgep Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth Well r\l 'd-116 1 ,\ '\. - \ 0 S-116 I' ul S·116 -116 Job# Log Description 12/15/03 12/15/03 12/15/03 12/15/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: 10662979 OH EDIT LDWG PEX·BHC-GR 10662979 QUAD COMBO PEX-BHC 10662979 QUAD COMBO ·TVD PEX-BHC 10662979 QUAD COMBO- SSTVD PEX-BHC [À~ ~ÀKYr NO. 3467 09/27/05 Company: Alaska 011 & Gas Cons Comm Att": Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Date Color BL Received by: CD . (jjJ . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~ s~::~isor~~l ~ 4{ D6 DATE: Wednesday, March 02, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-116 PRUDHOE BAY UN AURO S- 116 íc}JJ3-L~{ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv-=:Jß12- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN AURO S-Il API Well Number: 50-029-23183-00-00 Inspector Name: Chuck Scheve £ Insp Num: mitCS050224170350 Permit Number: 203-181-0 Inspection Date: 2/24/2005 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ¡ S-116 ¡Type Inj. P I TVD 6574 IA 40 4000 3920 I 3910 ! P.T. I 2031810 ITypeTest SPT I Test psi 1643.5 OA 40 480 460 I 460 Tubing I 1750 I 1750 I 1750 I 1750 i Interval OTHER P/F P I I Notes: MIT performed pre WAG swap to gas. SCANNED JAN 0 3 2007 *--. #-..~ Wednesday, March 02, 2005 Page I of I "'I e rID, 0·· rr ¿f8\\:l IE, ~ ~(..~ jÆK I r rï,,! !!:::!.ü\ n.JJ ~\\ . w IWL...:::¡U:~.....!u e : ')'~'~",Ja( ~Z'/~rlJ" f~ .. "'"r~ S?í ... t¡m^ Ii ¡Œ,·.· ~ .. ffi·, , nl! ii, t i ~ U....· U ¡ A"#A~1iA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Young Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchoragea, Alaska 99519-6612 Re: Prudhoe Bay S-116 Sundry Number: 305-044 Dear Mr. Young: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 da following the date of this letter, or the next working day if the 23rd day falls on a oli y or weekend. A person may not appeal a Commission decision to Superior 000 less rehearing has been requested. DATED this1!lday of February, 2005 Encl. W6Pr "Z.../2-2./ZðO':; () Y5 2./22/5 e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Development D Exploratory D StratigraphicD Service Œ] 9. Well Name and Number: S-116 /~ 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): IEffective Depth TVD (ft): 8200 6923.8 S~ MD nD top bottom top bottom 33 113 33.0 113.0 1490 470 31 8279 31.0 7063.2 5750 3090 32 3450 32.0 2938.6 8160 7020 Tubing Size: Tubing Grade: Tubing MD (ft): 4-112 " 12.6 # L-80 29 7821 ') >, ... , 1. Type of Request: Abandon D D D Suspend D RepairWell D Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Alter Casing Change Approved Program 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.40 KB 8. Property Designation: ADL-028258 11. Presen1 Total Depth MD (ft): 8291 I Total Depth TVD (ft): 7074.6 Length Casing 80 8248 3418 20" 91.5# H-40 7" 29# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6782 - 6793.2 6800 - 6812.1 6893 - 6904.8 CONDUCTOR PRODUCTION SURFACE Perforation Depth MD (ft): 7982 - 7994 8001 - 8014 8100 - 8112 Packers and SSSV Type: 4-1/2" Baker Premier Packer PerforateD / WaiverD StimulateŒ] Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 203-1810 ~ Other D / 6. API Number 50-029-23183-00-00 ~. Plugs (md): None Burst Junk (md): None Collapse Packers and SSSV MD (ft): 12. Attachments: 7761 13. Well Class after proposed work: /~ ServiceŒ Description Summary of Proposal ŒI Detailed Operations ProQram D BOP Sketch D 14. Estimated Date for CommencinQ Operation: Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD --./ VJ~ WAG lYI GINJD Abandoned D February 25, 2005 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: Printed Name Signature rµ.°1~ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test D Subs 10-404· RBDMS BFL MAR 0 1 2005 n PIC, i \,-,"~\fLI: Form 1 0-403 Revised 11/2004 Contact WINJfæ- WDSPLD Prepared by Garry Catron 564-4657. Jim Young Title Phone Petroleum Engineer 564-5754 2/15/05 I Sundry Number: ~I)S- -O~r Location Clearance D BY ORDER OF THE COMMISSION oæe f1Þ/ £ L SUBMIT IN DUPLICATE bp ... ,tI,.,,,. _..~ ~..- ~.,- ---:..,-- ~.,,\ ~... .'i!'.'~\" ". e e To: G ANC WELLWORK Date: February 14, 2005 From: Jim Young S-P AD Engineer Subject: S-116i HPBD (Kuparuk C Sands) AFE: AUD5M0070 Est. Cost: $100M lOR: 300 Priority: New Well Put On Injection A High Pressure Break Down using rock salt is proposed for S-116i to enhance injectivity prior to upcoming WAG swap. Please call Jim Young (W:564-57543, H:248-0133, Cell 440-8007) with any questions. 2 S-116 0 Wellbore Fluids: Perfs: BHT & BHP: cc: w/a: Well File Steve Deckert Treesaver, Pump HPBD/F, POI at max pressure. Produced crude in tubing and gas-lift in IA. (37', 6spf, 0.45" EHD). 145°F & 3000 psia @ 6700' TVDSS ec: G Anc Well work · T.REE = W8.LHEAD = ACTUATOR = KB. 8.EV = ~~~..'-~""-"< BF. 8.EV = KOP= Max Angle = Datum MD = Datum lV D = e 4-1/16" CrN FMC NA 64.7' 36.2' 500' 51 @ 3046' 7760' 6600' 9-5/8" CSG, 40#, L-80, ID = 8.835" H 3450' r- I Minimum Ie = 3.725" @ 7809" 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 7820' ÆRFORA TION SUMMARY REF LOG: ÆX 12/14/03 ANGLE AT TOP ÆRF: 19 @ 7982' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 5 7982 - 7994 0 04/29/04 3-3/8" 5 8001 - 8014 0 04/29/04 3-3/8" 6 8100 - 8112 0 04/29/04 I PBTD 1-1 8199' 17" CSG, 29#, L-80, ID = 6.184" H 8279' DATE 12/19/03 04/08/04 04/29/04 07/12/04 REV BY COMMENTS TMN/KK ORIGINAL COMPLETION JLJ/KAK GLV C/O MJA/KAK IÆRFS KSB/KAK GLV C/O DATE 5-116 = =-1 e 1017' H 9-5/8" TAM PORT COLLAR I 2195' H 4-1/2" HES X NIP, ID = 3.813" 1 GAS LIFT MANDR8.S DEV TYPE VLV LATCH 31 KBG-2 DMY BK 21 KBG-2 DMY BK ----L ST MD lVD 2 4550 3751 1 7630 6451 PORT o o DATE 07/12/04 12/19/03 7699' H 4-1/2"HESXNIP,ID=3.813" I :8: :8: ---i 7761' H 7" X 4-1/2" BKR PREM PKR, ID = 3.875" 7788' H 4-1/2" HES X NIP, ID = 3.813" 1 7809' 1--1 4-1/2" HES XN NIP, ID = 3.725" 1 \ 7,821' I-f 4-112" WLEG, ID = 3.958" 1 7927' I-f 7" MARKER JT W/ RA TAG I ~ REV BY COMMENTS 8102' H 7" MARKER JT W/ RA TAG I A URORA UNIT W8.L: S-116 ÆRMIT No: 2031810 API No: 50-029-23183-00 SEC 35, T12N, R12E, 4271' FSL & 4502' F8. BP Exploration (Alaska) o . . Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ~"'3- t9<õ -S-120 "'l ,/ 1~'-S'123 C7\ 0 "'t" -. ::? ., __ S-116 ?-oJ. - S-118 ;)....0 j - <.I - Job# Log Description 10674426 US IT 10900127 US IT 10674425 USIT 10703986 SCMT 4/16/04 12/22/04 04/15/04 04/12/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrolechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ;¿f/o ~ ~ð' 3 .~ l'it! 02/11/05 NO. 3335 Company: Alaska Oil & Gas Cons Comm Att": Helen Wannan 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Date Color CD BL Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503·5789 :~~I iduura~ ~ . STATE OF ALASKA I ALASKA ~L AND GAS CONSERVATION COMM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended a WAG 20AAC 25,105 20AAC 25.110 21. Logs Run: MWD I GR, MWD / RES I GR, PEXlc, MDT, USIT CASING, LINER AND CEMENTING RECORD SET1"/ Î SDEP1"H MP SertINéPef'rI;H1¥D BOTTOM I ()þ BOTToM 110' Surface 110' 3450' 28' 2939' 8279' 26' 7063' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612. Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4271' NSL, 4502' WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 1327' NSL, 1404' WEL, SEC. 34, T12N, R12E, UM Total Depth: 1247' NSL, 1468' WEL, SEC. 34, T12N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 618930 y- 5980475 Zone- ASP4 TPI: x- 616799 y- 5977497 Zone- ASP4 Total Depth: x- 616736 y- 5977416 Zone- ASP4 18. Directional Survey a Yes 0 No 22. 20" 9-5/8" 91.5# 40# 26# H-40 L-80 L-80 Surface 28' 26' 7" 23. Perforations 0Ren to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3-3/8" Gun Diameter, 5 spf 3-3/8" Gun Diameter, 6 spf MD TVD MD TVD 7982' - 7994' 6782' - 6793' 8100' - 8112' 6893' - 6905' 8001' - 8014' 6800' - 6812' 26. Date First Production: August6,2004 Date of Test Hours Tested 5/1/2004 4 Flow Tubing Casing Pressure Press. 37 1,960 One Other Pre-Produced Injector 5. Date Comp., Susp., or Aband. 04/29/2004 6. Date Spudded 12/7/2003 7. Date T.D. Reached 12/13/2003 8. KB Elevation (ft): 64.4' 9. Plug Back Depth (MD+ TVD) 8200 + 6988' Ft 10. Total Depth (MD+TVD) 8291 + 7075' Ft 11. Depth where SSSV set (Nipple) 2195' MD 19. Water depth. if offshore NIA MSL Revised: 08/10/04, Put on Injection 1b. Well Class: o Development 0 Exploratory o Stratigraphic a Service 12. Permit to Drill Number 203-181 13. API Number 50- 029-23183-00-00 14. Well Name and Number: PBU 5-116 15. Field I Pool(s): Prudhoe Bay Field I Aurora Pool 16. Property Designation: ADL 028258 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 42" 260 sx Arctic Set (Approx.) 12-1/4" 571 sx AS Lite PF, 312 sx Class 'G' 8-314" 293 sx LiteCrete, 159 sx Class 'G' SIZE 4-1/2", 12.6#, L-80 DEPTH SET (MD) 7821' PACKER SET (MD) 7761' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oil-Bel GAs-McF WATER-Bel 513 Oil-Bel GAs-McF WATER-Bel 30 6 18 PRODUCTION FOR TEST PERIOD ... CALCULATED ........ 24-HoUR RATE""" CHOKE SIZE I GAS-Oil RATIO 1760 200 Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None mDMSBfl Form 10-407 Revised 12/2003 ÞŒl1. CONTINUED ON REVERSE SIDE ORIGINAl ~p G , 28. e 29. e GEOLOGIC MARKERS FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4359' Ugnu M Sands 5669' Schrader Bluff N 5942 Schrader Bluff 0 6079' Base Schrader I Top Colville 6412' HRZ 7762' Kalubik 7961' Kuparuk C 7971' Kuparuk B 8032' Kuparuk A 8088' Miluveach 8154' 3592' MDT was ran, log supplied for detail. 4719' 4954' 5072' 5362' 6575' 6762' 6771' 6829' 6882' 6945' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, MDT, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. ./. LI 11 tOL/_ Terrie Hubble "/Q}JlJJl . Ql.t~ PBU S-116 203-181 Well Number Title Technical Assistant Date 08 ~I O-O<{ Prepared By Name/Number: Terrie Hubble. 564-4628 Drilling Engineer: Jim Smith, 564-5773 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None": ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended IBI WAG 20AAC25.105 20AAC25.110 21. Logs Run: MWD / GR, MWD I RES / GR, PEXlc, MDT, USIT CASING, LINER AND CEMENTING RECORD SETTINGDEPTHMD Top BOÍTOM Surface 110' 28' 3450' 26' 8279' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4271' NSL, 4502' WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 1327' NSL, 1404' WEL, SEC. 34, T12N, R12E, UM Total Depth: 1247' NSL, 1468' WEL, SEC. 34, T12N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 618930 y- 5980475 Zone- ASP4 TPI: x- 616799 y- 5977497 Zone- ASP4 Total Depth: x- 616736 y- 5977416 Zone- ASP4 18. Directional Survey IBI Yes 0 No 22. 20" 9-5/8" 91.5# 40# 26# H-40 l-80 L-80 7" 23. Perforations open to Production (MD + TVD of T o,e and Bottom Interval, Size and Number; if none, state' none"): 3-3/8" Gun Diameter, 5 spf 3-3/8" Gun Diameter, 6 spf MD TVD MD TVD 7982' - 7994' 6782' - 6793' 8100' - 8112' 6893' - 6905' 8001' - 8014' 6800' - 6812' 26. Date First Production: Not on Production I Injection Yel One Other Pre-Produced Injector 5. Date Comp., Susp., or Aband. 04/29/2004 6. Date Spudded 12/7/2003 7. Date T.o. Reached 12/13/2003 8. KB Elevation (ft): 64.4' 9. Plug Back Depth (MD+ TVD) 8200 + 6988' Ft 10. Total Depth (MD+TVD) 8291 + 7075' Ft 11. Depth where SSSV set (Nipple) 2195' MD 19. Water depth, if offshore NIA MSl Top Surface 28' 26' BOTTOM 110' 2939' 7063' 42" 260 sx Arctic Set (Approx.) 12-1/4" 571 sx AS lite PF, 312 sx Class 'G' 8-314" 293 sx liteCrete, 159 sx Class 'G' 24. SIZE 4-1/2", 12.6#, l-80 1b. Well Class: o Development 0 Exploratory o Stratigraphic Test IBI Service 12. Permit to Drill Number 203-181 13. API Number 50- 029-23183-00-00 14. Well Name and Number: PBU 5-116 15. Field I Pool(s): Prudhoe Bay Field I Aurora Pool 16. Property Designation: ADl 028258 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) DEPTH SET (MD) 7821' PACKER SET (MD) 7761' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl GAs-McF WATER-Bsl CORE DATA ~~~m~~~~ ~t~~Y~:~~:actu'es, apparent dips and presenœ of oi, gas 0' water (aRËë!~)œssa'Y) None " "'-"":;' .,.. ff, ðði'\UC! 9Fl JJM 0 8 . '. (,1.'7 t)D~ ~~~ ~ .lliN, II" é Fonn 10-407 R;~Lo~ CoN"NUEO ON REVERSE SIDE 0 R t 6t~~ ri" Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ......... Press. 24-HoUR RATE""" Oll-Bsl 27. GAs-McF W A TER-Bsl CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) ( ç' & \:) e e 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4359' Ugnu M Sands 5669' Schrader Bluff N 5942 Schrader Bluff 0 6079' Base Schrader I Top Colville 6412' HRZ 7762' Kalubik 7961' Kuparuk C 7971' Kuparuk B 8032' Kuparuk A 8088' Miluveach 8154' 3592' MDT was ran, log supplied for detail. 4719' 4954' 5072' 5362' 6575' 6762' 6771' 6829' 6882' 6945' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, MDT, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~1IJ\,n W.. ~- T'tl T h IA t t Date 0' ..0 "'I..f\U Terrie Hubble ~ JQ¡v~ ,~l.t(...U\f\..Q Ieee nica ssis an \0 " '-'1 PBU S-116 203-181 Prepared By NamelNumber: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Jim Smith, 564-5773 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 S-116 State MDT.xls ~-~~ Well: 5-116 Date: 12/16/2003 1 165 . Check 2 539 538 1.0 CSG.CHECK 3 8103 3744.0 3731.0 13.0 3478.0 12.2 GOOD TEST P Kuparuk A I ~ 8030 3679.0 3682.0 3.0 512.0 DRY TEST P Kuparuk C 8030 3682.0 3680.0 2.0 24.0 I DRY TEST P Kuparuk C e H 8025 3677.0 3677.0 0.0 34.0 DRY TEST P Kuparuk C 8025 3678.0 3676.0 2.0 3309.0 0.7 ¡GOOD TEST P Kuparuk C 8012 3668.0 3670.0 2.0 3259.0 7.1 IGOOD TEST P Kuparuk C W 8008 3667.0 3668.0 1.0 3269.0 1.3 ¡GOOD TEST P Kuparuk C 8001 3662.0 3664.0 2.0 3270.0 1.4 GOOD TEST P Kuparuk C 11 7993 3658.0 3660.0 2.0 3255.0 2.4 GOOD TEST P Kuparuk C 12' 7991 3659.0 3659.0 0.0 3250.0 2.1 GOOD TEST P Kuparuk C I-ii 7985 3654.0 3656.0 2.0 DRY TEST P Kuparuk C 14 7985 3655.0 3656.0 1.0 3249.0 2.8 GOOD TEST P Kuparuk C 15 6317 2882.0 2857.0 25.0 2815.0 0.5 ¡LOST SEAL P Schrader Bluff OBE . 16¡ 6262 2815.0 2818.0 3.0 ILOST SEAL P Schrader Bluff OBD I 17 6262 2821.0 2822.0 1.0 ¡LOST SEAL P Schrader Bluff OBD 18 6190 2784.0 2784.0 0.0 2504.0 5.7 !GOOD TEST P Schrader Bluff OBC 19 6141 2760.0 2760.0 0.0 2348.0 4.9 IGOOD TEST P Schrader Bluff OBB - 20 6098 2740.0 2740.0 0.0 2465.0 561.3 IGOOD TEST P Schrader Bluff OBA 211 6006 6006 J 2698.0 2697.0 1.0 2132.0 7.5 ¡GOOD TEST P Schrader Bluff NC 221 5983 5983 ¡ 2688.0 2686.0 2.0 2199.0 33.7 GOOD TEST P Schrader Bluff NB e 23 5965 5965 I 2677.0 2678.0 1.0 2210.0 30.8 GOOD TEST P Schrader Bluff NB 24 5914 5914 2655.0 2655.0 0.0 ¡LOST SEAL P Ugnu MC 25 5914 5915 4929 ¡ 2655.0 2655.0 0.0 2233.0 41.0 GOOD TEST P Ugnu MC 26 4454 4454 3669 1980.0 1974.0 6.0 1648.0 318.4 GOOD TEST P UG4A 27 4389 4389 3615 ¡ 1946.0 1946.0 0.0 1628.0 895.2 ¡GOOD TEST P UG4A 28 4076 4076 3368 1813.0 1813.0 0.0 1490.0 488.6 ¡GOOD TEST P SV1 29 4005 4005 3315 ¡ 1783.0 1783.0 0.0 1467.0 996.2 GOOD TEST P SV1 301 3798 3798 3169 I 1704.0 1704.0 0.0 1402.0 87.0 ¡GOOD TEST P SV2 31 ' 3647 3647 I 3068 1651.0 1651.0 0.0 1358.0 352.8 GOOD TEST P SV2 32 3598 3598 ! 3036 1633.0 1633.0 ¡ 0.0 1342.0 471.1 IGOOD TEST P SV2 33 3200 1496.0 1496·~1 0.0 13.0 ..~jQASING CHECK Page 1 Legal Name: 8-116 Common Name: 8-116 12/12/2003 LOT 2/18/2003 LOT 2,557 (psi 6.76 (ppg) 2,531 (psi) 6.59 (ppg) - e Printed: 12/22/2003 9: 19:43 AM ,077 (psi) 975 (psi 9.70 (ppg) 10.20 (ppg) 2,937.0 (ft) 2,937.0 (ft) 3,449.0 (ft) 3,449,0 (ft) e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/612003 End: 12/20/2003 12/5/2003 18:00 - 00:00 6.00 MOB P PRE Disconnect Pit module. Move Pit module, Sattelite camp & Shop to S-Pad along with other miscellaneous equipment. Trouble shoot problem with the Sub Moving System. 12/6/2003 00:00 - 07:00 7.00 MOB P PRE Nabors identified and repaired problem with Sub Base Hydraulic Moving System. 07:00 - 18:00 11.00 MOB P PRE Move Rig Sub off Z-1 00. Move from Z-Pad to S-Pad. 18:00 - 22:00 4.00 MOB P PRE Spot Rig over S-116. Set Pits, Camp & Shop. Hook up steam, air & water to Pit Complex. ACCEPT RIG @ 22:00 HRS, 12/6/2003. 22:00 - 00:00 2.00 RIGU P PRE Cont.RlU. Spot Geologist shack, Spot Cuttings Tank Spud meeting with Rig Crew, Anadrill DD's & MWD hands, MI engineer. 12/7/2003 00:00 - 05:00 5.00 RIGU P PRE Cont. RlU. Spot MWD Shack. RlU Riser. Connect Mud & Flowlines. Load BHA Tools in Pipe Shed. Load DP & HWDP in shed & strap same. 05:00 - 06:00 1.00 DRILL P SURF Service Top Drive & Blocks 06:00 - 07:00 1.00 DRILL N RREP SURF Repair Leak on Iron Roughneck 07:00 - 10:30 3.50 DRILL P SURF P/U & Rack back in Derrick 34 Stands 4" DP. 10:30 -11:15 0.75 DRILL P SURF Bring all BHA Tools to Rig Floor 11:15-12:00 0.75 DRILL P SURF RlU SWS sheaves & E-Line for Gyro Surveys. 12:00 - 13:30 1.50 DRILL P SURF Change out Top Drive Quill to 41/2" IF. 13:30 - 14:30 1.00 DRILL P SURF PJSM w/ SWS & Gyro Data - RlU Gyro Data Tool. 14:30 - 16:00 1.50 DRILL P SURF P/U & Stand back 5" HWDP. 16:00 - 17:30 1.50 DRILL P SURF P/U & M/U BHA #1, Orient & Surface Check. 17:30 - 18:00 0.50 DRILL P SURF Fill Hole & Pressure test Mud Manifold to 3500 psi. - No Leaks. 18:00 - 18:30 0.50 DRILL P SURF C/O Conductor to 110'. 18:30 - 19:45 1.25 DRILL P SURF Drill from 110' to 236',560 GPM @ 800 psi 19:45 - 20:30 0.75 DRILL P SURF POH for MWD & DC's. 20:30 - 21 :30 1.00 DRILL P SURF P/U BHA, Orient & RIH to 236'. 21 :30 - 00:00 2.50 DRILL P SURF Directional Drill 12 1/4" Hole from 236' to 514'. 560 GPM @ 1060 psi. Torque = 1500 Off Bot. 2000 On Bot WOB = 14K ROT, 30K Sliding. P/U, Dn, & ROT Weights all 45K. Daily ART = 2.35 Hrs. AST = 0.39 Hrs 12/8/2003 00:00 - 04:00 4.00 DRILL P SURF Directional Drill 12 1/4" hole from 514' to 914'. 575 GPM @ 1080 psi. Torque On Bot = 3500 Off = 3000. WOB = 35K Sliding, 15K Rotating. RPM = 80. 04:00 - 05:00 1.00 DRILL P SURF C/O Quill on Top Drive to 4" HT -40. 05:00 - 07:30 2.50 DRILL P SURF Directional Drill 12 1/4" Hole from 914' to 1134'. Same Parameters. Having MWD Signal Detection Problems. Unable to get good toolface. 07:30 - 08:30 1.00 DRILL N DPRB SURF C/O lower Standpipe transducer, clean all screens & re-check pulsation dampeners with no success. Unable to detect MWD Signal 08:30 - 09:00 0.50 DRILL P SURF Circulate clean w/ 560 GPM @ 950 psi. while rotating @ 80 RPM and reciprocating string. 09:00 - 11 :00 2.00 DRILL P SURF POH to 88' 11:00 -11:30 0.50 DRILL P SURF RID & UD SWS E-Line sheaves & Line. 11 :30 - 14:30 3.00 DRILL P SURF UD MWD, C/O Bit. P/U & M/U New MWD, Orient & Surface check - OK 14:30 - 15:00 0.50 DRILL P SURF RIH to 1011'. Precautionary wash to bottom @ 1134', No fill- no Problems on trip. 15:00 - 00:00 9.00 DRILL P SURF Directional Drill 12 1/4" Hole from 1134' to 1892'. 575 GPM @ Printed: 12/22/2003 9:19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/6/2003 End: 12/20/2003 12/8/2003 15:00 - 00:00 9.00 DRILL P SURF 1650 psi. WOB = 40K Sliding & 20 to 30K Rotating. Torque on bottom = 5K, off bottom = 3K. Rotating @ 80 RPM.. P/U Wt. = 85K, Dn Wt = 75K, Rot Wt = 80K. Daily ART = 4.26 AST = 6.92 12/9/2003 00:00 - 12:30 12.50 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,892' to 3,465'. WOB Sliding 15,000# - 40,000#, WOB Rotating 20,000# - 35,000# RPM 80, Motor RPM 69, Torque Off Bottom 5,500 ft /Ibs - On Bottom 8,000 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,150 psi, On Bottom 2,325 psi. String Weight Up 115,000#, String Weight Down 75,000#, String Weight Rotating 95,000#. ART = 4.91 hrs, AST = 2.26 hrs. Daily Krevs = 53.2, Total Krevs = 90.9. 12:30 - 14:00 1.50 DRILL P SURF Circulated Bottoms Up. Pump Rate 650 gpm, SPP 2,700 psi. Flow Checked Well, Well Static. Blew Down Top Drive. 14:00 - 16:30 2.50 DRILL P SURF Held PJSM. POOH for Wiper Trip from 3,465' to 1,700'. Maximum Overpull 20,000#, Hole Tight and Swabbed at 2,668'. Back Reamed and Pumped Out from 2,668' to 2,600'. Hole Swabbed at 2,219'. Back Reamed and Pumped Out from 2,219' to 2,150'. 16:30 - 17:30 1.00 DRILL N RREP SURF Repaired Hydraulic Hose on Top Drive. 17:30 - 19:00 1.50 DRILL P SURF POOH for Wiper Trip from 1,700' to 916'. No Overpull, No Swabbing. 19:00 - 20:30 1.50 DRILL P SURF RIH after Wiper Trip from 916' to 3,308'. M / U Top Drive, Washed Down as a Precaution from 3,308' to 3,465'. Pump Rate 550 gpm, SPP 2,000 psi. No Fill. 20:30 - 23:00 2.50 DRILL P SURF Circulated Bottoms Up. Staged Pump Rate Up to 650 gpm, SPP 2,500 psi. Circulated Until Returns over Shaker were Clean. Conditioned Mud to: Vis 150, MW 9.5 ppg. Flow Checked Well, Well Static. Blew Down Top Drive. 23:00 - 00:00 1.00 DRILL P SURF POOH w/4" DP from 3,465' to 2,700'. No Overpull. 12/10/2003 00:00 - 02:00 2.00 DRILL P SURF Held PJSM. POOH w/4" DP from 2,700' to 916'. 02:00 - 04:00 2.00 DRILL P SURF Held PJSM. POOH w/ BHA. Racked 5" HWDP in Derrick, Flushed w/ Water, Broke Out and L / D Flex DCs, MWD and Mud Motor. 04:00 - 05:00 1.00 CASE P SURF Cleared and Cleaned Rig Floor. 05:00 - 06:00 1.00 CASE P SURF Held PJSM. R / U Equipment to Run 9-5/8" Casing. 06:00 - 06:30 0.50 CASE P SURF P / U 9-5/8" Casing Hanger and Landing Joint. Made Dummy Run w/ Casing Hanger and Landed Out, Marked Landing Joint, L / D 9-5/8" Casing Hanger and Landing Joint. 06:30 - 07:00 0.50 CASE P SURF Held PJSM w/ Drilling Crew, Toolpusher, Nabors Casing and Drilling Supervisor. 07:00 - 07:30 0.50 CASE N SURF Repaired Pipe Skate. 07:30 - 08:30 1.00 CASE P SURF M / U Float Shoe Joint, 1 Jt of 9-5/8" Casing and Float Collar Joint. Filled Casing and Checked Float Equipment, OK. Bakerloc'd All Connections on Shoe Track. 08:30 - 12:30 4.00 CASE P SURF M / U and RIH w/82 Joints 9-5/8", 40.0#, L-80, BTC Casing. Average M / U Torque 8,500 ft /Ibs. 12:30 - 13:00 0.50 CASE P SURF M / U 9-5/8" Casing Hanger and Landing Joint. Landed Casing. 9-5/8" Casing Set As Follows: Item Length Depth Float Shoe 1.71 ' 3,449.80' 2 Jts 9-5/8" 40.0# L-80 BTC Csg 83.11' 3,364.98' Float Collar 1.20' 3,363.78' Printed: 12/22/2003 9: 19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/6/2003 End: 12/20/2003 12/10/2003 12:30 -13:00 0.50 CASE P SURF 579-5/8" 40.0# L-80 BTC Csg 2,344.05' 1,019.73' TAM Port Collar Assembly 43.67' 976.06' 239-5/8" 40.0# L-80 BTC Csg 946.16' 29.90' 9-5/8" Casing Hanger 1.95' 27.95' 13:00 - 14:00 1.00 CEMT P SURF Circulated to Condition Hole. Pump Rate 12 bpm, SPP 580 psi. Reciprocated Casing while Circulating. String Weight Up 165,000#, String Weight Down 97,000#. 14:00 - 14:30 0.50 CEMT P SURF R / D Franks Tool, M / U Cement Head w/ Plugs to Landing Joint. 14:30 - 15:30 1.00 CEMT P SURF Circulated to Condition Hole. Pump Rate 12 bpm, SPP 580 psi. Reciprocated Casing while Circulating. String Weight Up 165,000#, String Weight Down 97,000#. 15:30 - 18:00 2.50 CEMT P SURF Held PJSM wlDowell crew, Rig Crew, Truck drivers. Switched over to Dowell. Pumped 5 bbls of water at 5bpm, 210 psi. Shut in cement manifold and tested lines to 3,500 psi. OK. Pumped 75 bbls mud push at 5 bpm., 330 psi. Dropped bottom plug, pumped 435 bbls (568 sks) 10.7 ppg ArticSet Lite III lead cement, followed by 65 bbls (310 sks) 15.8 ppg Premium Tail cement w/ 0.300& bwoc dispersant, 0.40% bwoc Fluid Lodd, 0.20% bwoc Antifoam, 0.90% bwoc Accelerator and 0.40% bwoc UniFLAC-S. Recriprocated casing while cementing. Pumped cement at the following rates: Pumped Rate Pressure 25.0 bbls 7.00 bpm 730 psi 100.0 bbls 6.90 bpm 675 psi 200.0 bbls 6.90 bpm 690 psi 300.0 bbls 6.90 bpm 715 psi 400.0 bbls 6.90 bpm 765 psi 435.0 bbls 6.90 bpm 800 psi Tail Cement 455.0 bbls 7.20 bpm 1800 psi 475.0 bbls 4.50 bpm 840 psi 500.0 bbls 2.80 bpm 370 psi Dropped top plug, pumped 10 bbls water at 6.0 bpm, 400 psi. Switched to rig pumps and displaced w/244 bbls mud at the following rates: Pumped Rate Pressure 50.0 bbls 10.00 bpm 260 psi 100.0 bbls 10.00 bpm 260 psi 150.0 bbls 3.50 bpm 250 psi Cement to surface w/179 bbls displacement pumped 200 bbls 7 bpm 700 psi 225.0 bbls 8.00 bpm 925 psi 254.0 bbls 8.00 bpm 935 psi Wiper plug bumped w/ 254 bbls total displacement pumped. Pressured up to 1,900 psi OK. Aprox. 75 bbls of lead cement to surface. Cement in place @ 1800 hrs. 18:00-19:00 1.00 CEMT P SURF Bled off pressure, floats held. RID cement head and lines. Broke out and UD landing joint 19:00 - 20:00 1.00 CEMT P SURF Flushed riser, flow line and cellar. Blew down all lines. 20:00 - 21 :00 1.00 P PROD1 Held PJSM. Cleaned and cleared rig floor. NID riser and starter head. Printed: 12/22/2003 9:19:50AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: Spud Date: 12/6/2003 End: 12/20/2003 12/5/2003 12/20/2003 PROD1 N / U 13-5/8" x 5,000 psi Split-Speed Wellhead. Tested to 1,000 psi f/1 0 minutes, OK PROD1 Held PJSM. N / U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Top Pipe Ram w/3-1/2" x 6" Variable Rams, Blind Rams, Mud Cross, Lower Pipe Rams w/3-1/2" x 6" Variable Rams and Spacer Spool. PROD1 Held PJSM. N / U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Top Pipe Ram w/3-1/2" x 6" Variable Rams, Blind Rams, Mud Cross, Lower Pipe Rams w/3-1/2" x 6" Variable Rams and Spacer Spool. N / U Kill and Choke Lines. Held PJSM. R / D 9-5/8" Varco Elevators and Long Bales. R / U Short Bales R / U Test Equipment to Test BOPE. M / U Test Joint and Test Plug. RIH and Set Plug in Wellhead, Opened Annulus Valve. Filled BOP Stack. Held PJSM. Tested BOPE. Tested Upper and Lower Rams, Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 4,000 psi High / 250 psi Low. Tested Annular Preventer to 3,500 psi High /250 psi Low. All Tests Held f/ 5 Min. All Pressure Tests Held w/ No Leaks or Pressure Loss. Witnessing of BOPE test Waived by AOGCC Rep Chuck Scheve. Note: Test Pump Line to Control Panel on Rig Floor had to be Thawed Prior to Beginning of BOPE Test. During BOPE Test, External Leaks were Observed on Choke HCR and Kill Line Unibolt Connection. The Pressure was Bled Off and the Connections were Examined and Retightened Resulting in Good Tests. Discovered Line to Gas Buster Frozen while Testing Choke Manifold. The Line was Thawed and the Choke Manifold was Tested off of the Critical Path. During Koomey Test a Pump Malfunctioned, Pump was Repaired, Koomey was Retested, OK. Blew Down All Lines, Closed Annular Valve, Pulled Test Plug, L / D Test Joint. R / D BOPE Test Equipment. Ran and Set Wear Bushing. Serviced Top Drive, P / U 45 Jts of 4" DP, Stood Back in Derrick. Held PJSM. M / U BHA #3.9-7/8" Hycalog DS-70 PDC Bit, Ser# 204642, dressed w/6x14 jets - 6-3/4" XP PDM 4/5 7.0 stg Motor w/1.15 deg Bent Housing - NM Lead Collar - NM 8-3/4" Stabilizer - CDR - MWD - NM 8-3/4" Stabilizer - 2 x NM Drill Collars - NM 8-3/4" Stabilizer - NM Drill Collar - Saver Sub - Drilling Jars - 23 Jts 5" HWDP - Straight Blade Reamer - XO. Total BHA Length - 928.49'. Set Motor Bend and Oriented to MWD. M / U Top Drive and Tested MWD Tools, OK. PROD1 RIH w/ 8-3/4" Directional BHA on 4" DP to 1,000'. P / U Single Joints of DP from Pipe Shed. Slowly Rotated Bit and Stabilizers Through TAM Port Collar at 1,017'. 12/10/2003 21:00-22:00 1.00 WHSUR P 22:00 - 00:00 2.00 BOPSUR P 12/11/2003 00:00-02:00 2.00 BOPSURP 02:00 - 03:00 1.00 CASE P PROD1 03:00 - 04:00 1.00 BOPSURP PROD1 04:00 - 11 :00 7.00 BOPSURP PROD1 11:00 -11:30 0.50 BOPSURP PROD1 11:30-12:00 0.50 DRILL P PROD1 12:00 - 14:30 2.50 DRILL P PROD1 14:30 -18:00 3,50 DRILL P PROD1 18:00 - 19:00 1.00 DRILL P Printed: 12/22/2003 9:19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/6/2003 End: 12/20/2003 12/11/2003 19:00 - 19:30 0.50 DRILL P PROD1 Closed Pipe Rams and Pressure Tested Casing to 1,500 psi to Ensure TAM Port Collar Closed. OK. Bled Off Pressure and Opened Pipe Rams. 19:30 - 22:00 2.50 DRILL P PROD1 Continued to RIH w/8-3/4" Directional BHA on 4" DP to 3,318'. P / U Single Joints of DP from Pipe Shed. 22:00 - 23:00 1.00 EVAL P PROD1 Held PJSM. R / U Circulating Head and Lines. Established Circulation. Shut Down Pump and Closed Upper Pipe Rams. Tested 9-5/8" Surface Casing to 3,500 psi f/30 minutes, OK. Calculated Strokes to Pressure Up to 3,500 psi, 50 - 2.88 bbls, Actual Strokes 62 - 3.57 bbls. Bled off Pressure, Opened Pipe Rams. Blew Down Lines, R / D Lines and Circulating Head. 23:00 - 00:00 1.00 DRILL P PROD1 Slowly Washed Down from 3,318' to 3,360'. Pump Rate 400 gpm, 900 psi, RPM 35, Torque 6,500 ft /Ibs. Tagged Cement at 3,360'. Drilled Cement and Float Equipment from 3,360' to 3,385'. WOB 5,000# - 7,000#, RPM 40, Motor RPM 132, Torque On Bottom 8,000 ft /Ibs, Pump Rate 400 gpm, SPP On Bottom 1,000 psi. 12/12/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Held PJSM. Drilled Cement and Float Equipment from 3,385' to 3,449'. WOB 5,000# - 7,000#, RPM 40, Motor RPM 200, Torque On Bottom 8,000 ft /Ibs, Pump Rate 400 gpm, SPP On Bottom 1,000 psi. Cleaned Out to 3,465'. Displaced Hole to New 9.7 ppg LSND Mud During Drilling Out Operations. 01 :00 - 01 :30 0.50 DRILL P PROD1 Drilled New 8-3/4" Hole from 3,465' to 3,485'. WOB 5,000#- 7,000#, RPM 40, Motor RPM 200, Torque On Bottom 8,000 ft / Ibs, Pump Rate 400 gpm, SPP 950 psi. 01 :30 - 02:00 0.50 DRILL P PROD1 Circulated Bottoms Up to Clean the Hole and Condition Mud. Pump Rate 400 gpm, 800 psi. Circulated Until Returns Over Shaker were Clean and MW In Equaled MW Out, 9.7 ppg. Pulled Into Shoe, Blew Down Top Drive, M / U Circulating Head and Lines. 02:00 - 02:30 0.50 EVAL P PROD1 Held PJSM. Closed Pipe Rams and Performed LOT. Strokes Pmp'd Pressure 4 90 psi 8 235 psi 12 410 psi 16 560 psi 20 715 psi 24 795 psi 28 865 psi 32 960 psi 34 1,000 psi 38 1,077 psi 40 1,096 psi MW 9.7 ppg, Csg Shoe TVD 2,937', Pressure 1,077 psi = 16.75 ppg EMW. Held Pressure f/10 minutes, Pressure Leaked off from 1,096 psi to 890 psi in 5 minutes. Pressure at 10 minutes 840 psi. Bled down Pressure, Opened Pipe Rams. R / D Testing Equipment. 02:30 - 03:00 0.50 DRILL P PROD1 M / U Top Drive, Established Drilling Parameters: String Weight Up 120,000#, String Weight Down 75,000#, String Weight Rotating 91,000#. SPR Pump #1 52 spm - 260 psi, 70 spm - 320 psi; SPR Pump #2 52 spm - 260 psi, 70 spm - 320 psi. Clean Hole Baseline ECD 10.51 ppg. Printed: 12122/2003 9:19:50 AM -- e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/612003 End: 12/20/2003 12/12/2003 03:00 - 12:00 9.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 3,485' to 4,943'. WOB Sliding 5,000# - 8,000#, WOB Rotating 10,000# - 12,000#, RPM 80, Motor RPM 290, Torque Off Bottom 7,000 ft /Ibs - On Bottom 8,000 ft /Ibs, Pump Rate 580 gpm, SPP Off Bottom 2,100 psi, On Bottom 2,300 psi. String Weight Up 138,000#, String Weight Down 90,000#, String Weight Rotating 105,000#. ECD = 10.75 ppg. AST = 1.8 hrs, ART = 2.3 hrs. Pumped 30 bbl Hi-Vis Weighted Sweeps Every 400' . PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 4,943' to 6,300'. WOB Sliding 5,000# - 8,000#, WOB Rotating 10,000# - 15,000#, RPM 80, Motor RPM 290, Torque Off Bottom 8,000 ft /Ibs - On Bottom 10,000 ft /Ibs, Pump Rate 585 gpm, SPP Off Bottom 2,350 psi, On Bottom 2,700 psi. String Weight Up 172,000#, String Weight Down 98,000#, String Weight Rotating 120,000#. ECD = 10.65 ppg. AST = 0.79 hrs, ART = 5.66 hrs. Pumped 30 bbl Sweeps Every 500', Alternated Between Lo-Vis Weighted Sweeps and Hi-Vis Sweeps, 12:00 - 00:00 12.00 DRILL P 12/13/2003 00:00 - 12:00 12.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 6,300' to 7,430'. WOB Sliding 8,000# - 10,000#, WOB Rotating 11,000# -15,000#, RPM 100, Motor RPM 290, Torque Off Bottom 10,000 ft /Ibs - On Bottom 11,500 ft /Ibs, Pump Rate 585 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,200 psi. String Weight Up 210,000#, String Weight Down 108,000#, String Weight Rotating 145,000#. ECD 10.65 ppg. Pumped 30 bbl Sweeps Every 500', Alternated Between Lo-Vis Weighted Sweeps and Hi-Vis Sweeps w/ Mix II. AST = 2,11 hrs, ART = 5.18 hrs. 12:00 -17:00 5.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating from 7,403' to 7,908'. WOB Rotating 10,000# -15,000#, RPM 100, Motor RPM 290, Torque Off Bottom 10,000 ft /Ibs - On Bottom 11,000 ft /Ibs, Pump Rate 585 gpm, SPP Off Bottom 3,250 psi, On Bottom 3,350 psi. String Weight Up 210,000#, String Weight Down 115,000#, String Weight Rotating 145,000#. ECD 10.90 ppg. Began Addition of Spike Fluid at 7,450' to Increase MW to 10.0 ppg. Pumped 30 bbl Sweeps Every 500', Alternated Between Lo-Vis Weighted Sweeps and Hi-Vis Sweeps w/ Mix II. 17:00 - 18:00 1.00 DRILL P PROD1 Circulated 15 minutes, Pump Rate 585 gpm, SPP 3,000 psi. POOH w/ 2 Stands of 4" DP and Racked in Derrick. P / U and RIH w/6 Joints of 4" DP. 18:00 - 20:00 2.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating from 7,908' to 8,120'. WOB Rotating 5,000# - 15,000#, RPM 100, Motor RPM 290, Torque Off Bottom 9,000 ft /Ibs - On Bottom 10,500 ft /Ibs, Pump Rate 585 gpm, SPP Off Bottom 3,250 psi, On Bottom 3,350 psi. String Weight Up 210,000#, String Weight Down 115,000#, String Weight Rotating 145,000#. ECD 10.90 ppg. 20:00 - 21 :00 1.00 DRILL P PROD1 Circulated 15 minutes, Pump Rate 585 gpm, SPP 3,200 psi. POOH w/ 2 Stands of 4" DP and Racked in Derrick. P / U and Printed: 12/22/2003 9: 19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/6/2003 End: 12/20/2003 12/13/2003 20:00 - 21 :00 1.00 DRILL P PROD1 RIH w/6 Joints of 4" DP. 21 :00 - 22:30 1.50 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating from 8,120' to 8,291'. WOB Rotating 10,000# -15,000#, RPM 100, Motor RPM 290, Torque Off Bottom 9,000 ft /Ibs - On Bottom 10,500 ft /Ibs, Pump Rate 585 gpm, SPP Off Bottom 3,250 psi, On Bottom 3,400 psi. String Weight Up 210,000#, String Weight Down 115,000#, String Weight Rotating 145,000#. ECD 11.09 ppg. ART = 6.3 hrs. 22:30 - 00:00 1,50 DRILL P PROD1 Pumped and Circulated Around 30 bbl Hi-Vis Sweep w/ Mix II. Pump Rate 585 gpm, SPP 3,250 psi. Rotated Drill String 120 RPM and Reciprocated Drill String While Circulating. 12/14/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Held PJSM. Circulated 3 x Bottoms Up. Pump Rate 585 gpm, SPP 3,200 psi. Monitored Well, Well Static. Pumped Dry Job, Blew Down Top Drive. 01 :00 - 06:00 5.00 DRILL P PROD1 POOH w/4" DP f/ Wiper Trip from 8,291' - 3,450', 9-5/8" Shoe. Average Drag 8,291' - 5,100' 25,000#. Average Drag 5,100' - 4,250' 10,000#. Encountered 75,000# Overpull and Slight Swabbing 4,250'. M / U Top Drive, Back Reamed and Pumped Out of the Hole from 4,250' - 3,450'. Pump Rate 500 gpm, SPP 1,800 psi. RPM 100, Torque 5,000 ft /Ibs. Calculated Fill 27.5 bbls, Actual Fill 30.25 bbls. 06:00 - 06:30 0.50 DRILL P PROD1 Circulated Bottoms Up, Pump Rate 585 gpm, 1,930 psi, Rotated Drill String 60 RPM, Torque 6,000 ft /Ibs, Reciprocated Drill Sting 60'. Circulated Until Returns Over Shaker Were Clean. Monitored Well, Well Static. 06:30 - 07:30 1.00 DRILL P PROD1 Held PJSM. Attempted to Slip and Cut Drilling Line, Cancelled Operation Due to High Winds. Serviced Top Drive, 07:30 - 10:30 3.00 DRILL P PROD1 RIH f/ 3,450' to 8,195', Filled the Pipe at 5,803'. Precautionary Wash and Ream from 8,195' to 8,291', No Fill. Calculated Displacement 27.5 bbls, Actual Displacement 24.0 bbls. 10:30 - 12:30 2.00 DRILL P PROD1 Circulated to Clean and Condition the Hole. Pump Rate 585 gpm, 3,400 psi. Rotated Drill String 120 RPM, Torque 10,000 ft /Ibs, Reciprocated Drill String 95'. Circulated Until Returns Over Shaker Were Clean. 12:30 - 13:00 0.50 DRILL P PROD1 Monitored Well, Well Static. Pumped Dry Job, Blew Down Top Drive, Dropped Drill Pipe Rabbil. 13:00 - 19:00 6.00 DRILL P PROD1 POOH w/4" Drill Pipe f/8,291' to 928'. Average Drag 10,000#, No Overpull. Calculated Fill = 42 bbls, Actual Fill = 52 bbls. 19:00 - 20:30 1.50 DRILL P PROD1 POOH w/ Directional BHA Racked 5" HWDP in Derrick. Flushed, Broke Down and L / D Directional BHA Components. 20:30 - 21 :30 1.00 DRILL P PROD1 Cleared and Cleaned Rig Floor. 21 :30 - 22:00 0.50 EVAL P PROD1 Held PJSM w/ Drilling Crew, Schlumberger Wireline Crew, Toolpusher and Drilling Supervisor. 22:00 - 23:30 1.50 EVAL P PROD1 R / U Schlumberger Wireline Equipment and Tools. 23:30 - 00:00 0.50 EVAL P PROD1 Tested Logging Tools, OK. Cleared Rig Floor. Schlumberger Loaded Radioactive Sources into Logging Tools. Tools were RIH to 200'. 12/15/2003 00:00 - 02:00 2.00 EVAL P PROD1 Held PJSM. RIH w/ PEX-BHCS Tool on E-Line. Logged Down While RIH. Tagged Up at 8,280'. 02:00 - 03:00 1.00 EVAL P PROD1 Logged Up from 8,280' to 9-5/8" Casing Shoe at 3,449'. During Repeat Log Section, E-Line Pulled 700# Over to Get Off Bottom. No Hole Problems Logging Up from 8,280' to 3,449'. 03:00 - 04:30 1.50 EVAL P PROD1 Held PJSM. POOH w/ Logging Tools to 200'. Cleared Rig Printed: 12/22/2003 9: 19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/612003 End: 12/20/2003 12/15/2003 03:00 - 04:30 1.50 EVAL P PROD1 Floor, Pulled Tools to Surface. Schlumberger Removed and Secured Radioactive Sources. Broke Out and L / D PEX-BHCS Tools. 04:30 - 05:30 1,00 EVAL P PROD1 P / U and M / U MDT Tools. 05:30 - 06:30 1.00 EVAL N SFAL PROD1 Schlumberger's Hydraulics Freezing. Placed Heater Unit on Hydraulic System to Thaw. 06:30 - 08:30 2.00 EVAL N DPRB PROD1 RIH w/ MDT Tools on E-Line to 2,500'. MDT Tools Stacked Out at 2,500'. Attempted to Work Through without Success. POOH. 08:30 - 09:30 1.00 EVAL N DPRB PROD1 M / U 2 Roller Segments onto Tool String, Function Tested MDT Tools, OK. RIH w/ MDT Tools to 2,500'. 09:30 - 10:30 1.00 EVAL P PROD1 RIH w/ MDT Tool on E-Line to 8,150' 10:30 - 18:30 8.00 EVAL P PROD1 Recorded Formation Pressures at 31 Stations from 8,103' to 3,598'. No Hole Problems. 18:30 - 19:30 1.00 EVAL P PROD1 POOH w/ MDT Tools, 19:30 - 20:30 1.00 EVAL P PROD1 Broke Down and L / D MDT Tools. R / D Schlumberger Wireline Equipment. 20:30 - 21 :30 1.00 EVAL P PROD1 Cleared Equipment Off of Rig Floor. 21 :30 - 22:00 0.50 CASE P PROD1 Held PJSM. Brought BHA Components to Rig Floor. 22:00 - 23:00 1.00 CASE P PROD1 M / U Clean Out BHA: 8-3/4" HTC MT Bit Ser# 6011600 - 8-3/4" NB Stabilizer cut f/ Float - 6-3/4" Spiral DC - 8-3/4" Stabilizer - 2 x 6-3/4" Spiral DC - 9 x 5" HWDP - Jars - 14 x 5" HWDP - XO. BHA Total Length 824.66. 23:00 - 00:00 1.00 CASE P PROD1 C/O Elevators. RIH w/ Clean Out BHA on 4" DP. 12/16/2003 00:00 - 01 :00 1.00 CASE P PROD1 Held PJSM. RIH w/ Clean Out BHA on 4" DP to 3,450'. 01 :00 - 01 :30 0.50 CASE P PROD1 R / U Circulating Head and Line, Circulated Bottoms Up, Staged Pump Rate Up to 580 gpm, SPP 1,250 psi. Returns Over Shaker on Bottoms Up Were Clean. No Losses, Shut Down Pump, Monitored Well, Well Static. Blew Down and R / D Lines. 01 :30 - 04:00 2.50 CASE P PROD1 RIH w/ Clean Out BHA to 8,195'. No Losses While RIH. Broke Circulation at 5,500', Pump Rate 400 gpm, 1,150 psi. 04:00 - 04:30 0,50 CASE P PROD1 M / U Top Drive, Precautionary Wash and Ream from 8,195' to 8,291'. Pump Rate 345 gpm, SPP 1,250 psi. RPM 80, Torque 10,000 ft /Ibs. 04:30 - 05:30 1.00 CASE P PROD1 Circulated to Clean and Condition Hole. Staged Pump Rate Up to 450 gpm, SPP 1,275 psi. Rotated Drill String 80 RPM, Torque 10,000 ft /Ibs, Reciprocated Drill String While Circulating. No Losses. String Weight Up 240,000#, String Weight Down 110,000#, String Weight Rotating 155,000#. 05:30 - 07:00 1.50 CASE P PROD1 Pumped and Circulated Around 30 bbl Hi-Vis Weighted Sweep, Pump Rate 580 gpm, SPP 2,700 psi. Rotated Drill String 120 RPM, Torque 10,000 ft /Ibs. Reciprocated Drill String While Circulating. No Losses. String Weight Up 240,000#, String Weight Down 110,000#, String Weight Rotating 155,000#. Pumped and Spotted 150 bbl 2% LubeTex Pill. Monitored Well, Well Static. 07:00 - 08:30 1.50 CASE P PROD1 POOH w/4" DP, Wet from 8,291' to 6,369'. 08:30 - 09:30 1.00 CASE P PROD1 Pumped and Spotted 160 bbl G-Seal Pill, Pump Rate 400 bpm, 1,050 psi. 09:30 - 11 :30 2.00 CASE P PROD1 POOH w/4" DP from 6,369' to 3,405'. 11 :30 - 13:30 2.00 CASE P PROD1 Held PJSM. Slipped and Cut Drilling Line. 13:30 -16:30 3.00 CASE P PROD1 POOH, L / D 75 Joints 4" DP. Calculated Fill f/ Full TOH 42.5 bbls, Actual Fill 51.5 bbls. Printed: 12/22/2003 9:19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/6/2003 End: 12/20/2003 12/16/2003 16:30 - 17:30 1.00 CASE P PROD1 POOH wI Clean Out BHA. Racked 5" HWDP in Derrick. Broke Out and LID Remaining BHA. 17:30 - 19:00 1.50 CASE P PROD1 Cleared and Cleaned Rig Floor. RID DP Elevators, Changed Out Bails, R I U Franks Fill Up Tool. 19:00 - 20:30 1.50 BOPSUR. P PROD1 Held PJSM. M I U Retrieving Tool, Latched and Pulled Wear Bushing. M I U and Installed Test Plug in Wellhead. Changed Out Top 3-1/2" x 6" Variable Rams f/7" Solid Rams. Closed Annular and Tested Door Seals to 3,500 psi, OK. Bled Off Pressure, Opened Annular. Pulled Test Plug, RID Retrieving Tool. 20:30 - 22:00 1.50 CASE P PROD1 R I U 7" Casing Handling Tools. 22:00 - 22:30 0.50 CASE P PROD1 Held PJSM wI Drilling Crew, Nabors Casing, Toolpusher and Drilling Supervisor. 22:30 - 23:00 0.50 CASE P PROD1 M I U Float Shoe Joint, 1 Jt of 7" Casing and Float Collar Joint. Filled Casing and Checked Float Equipment, OK. Bakerloc'd All Connections on Shoe Track. 23:00 - 00:00 1.00 CASE P PROD1 M I U and RIH wI 7", 29.0#, L-80, BTC Casing. Filled Casing Every Joint. Average M I U Torque 7,500 ft Ilbs. 12/17/2003 00:00 - 04:30 4.50 CASE P PROD1 Held PJSM. M I U and RIH wI 7", 29.0#, L-80, BTC Casing to 3,450'. Filled Casing Every Joint. Average M I U Torque 7,500 ft Ilbs. 04:30 - 05:00 0.50 CASE P PROD1 Circulated Bottoms Up at 3,450'. Staged Pumps Up to 7 bpm, 500 psi. No Losses. String Weight Up 110,000#, String Weight Down 87,000#. 05:00 - 08:30 3.50 CASE P PROD1 M I U and RIH wI 7", 29.0#, L-80, BTC Casing TO 5,075'. Filled Casing Every Joint, Broke Circulation Every 10 Joints. Average M I U Torque 7,500 ft Ilbs. Rubber from Fill Up Tool Swab Cup Tore Loose and Dropped in Hole. 08:30 - 10:00 1.50 CASE N SFAL PROD1 RID Franks Tool, M I U Circulating Swedge, Head and Lines. Circulated 2 x Casing Volume. Staged Up Pumps to 7 bpm, SPP 575 psi. Reciprocated While Circulating, String Weight Up 165,000#, String Weight Down 100,000#. M I U New Franks Tool. Recovered Rubber Over Shakers. 10:00 - 15:30 5.50 CASE P PROD1 M I U and RIH wI 7", L-80, BTC Casing, Average M I U Torque 7,500 ft Ilbs. Filled Every Joint, Broke Circulation on 26# Casing Every 10 Joints, Circulated Down 3 Full Joints 15 Minutes per Joint, Every 35 Joints. Pump Rate While Circulating 6 bpm. 15:30 - 16:00 0.50 CASE P PROD1 M I U 7" Casing Hanger and Landing Joint. 7" Casing Set As Follows: Item Length Depth Float Shoe 1.65' 8,278.90' 2 Jts 7" 29.0# L-80 BTC Csg 76.65' 8,200,60' Float Collar 1.05' 8,199,55' 2 Jts 7" 29.0# L-80 BTC Csg 77.44' Printed: 12/22/2003 9: 19: 50 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/612003 End: 12/20/2003 12/17/2003 15:30 -16:00 0.50 CASE P 16:00 - 17:30 1.50 CEMT P PROD1 8,121.71' 7" 29.0# L-80 BTC Marker Jt wI RA Tag 19.67' 8,102.04' 4 Jts 7" 29.0# L-80 BTC Csg 155.09' 7,946.95' 7" 29.0# L-80 BTC Marker Jt wI RA Tag 19.66' 7,927.29' 151 Jts 7" 29.0# L-80 BTC Csg 5,939.42' 1,987.60' 48 Jts 7" 26.0# L-80 BTC Csg 1,958.73' 28.87' 7" Casing Hanger 2.50' 26.37' PROD1 Circulated to Cool and Condition Hole. Staged Up Pumps to 7 bpm, SPP 675 psi. Reciprocated Casing while Circulating. String Weight Up 270,000#, String Weight Down 140,000#. PROD1 RID Franks Tool, M I U Cement Head wI Plugs to Landing Joint. Circulated to Cool and Condition Hole. Pump Rate 7 bpm, SPP 700 psi. Observed 80,000# Overpull While Reciprocating Casing, Landed 7" Casing Hanger in Wellhead. PROD1 Held PJSM wI Dowell Crew, Rig Crew, Truck Drivers, Toolpusher and Drilling Supervisor. Switched Over to Dowell. Pumped 5 bbls of Water at 5bpm, 400 psi. Shut in Cement Manifold and Tested Lines to 4,000 psi. OK. Pumped 20 bbls of CW, Pump Rate 4.90 bpm, 640 psi. Pumped 40 bbls 11.0 ppg Mud Push Pump Rate 5 bpm, 600 psi. Dropped Bottom Plug, Pumped 124 bbls (295 sks) 12.0 ppg Lead Cement wI 0.20 %bwoc Antifoam, 1.00 %bwoc Extender, 1.00% bwoc UniFLAC-S, 0.10% bwoc Retarder, Followed by 34 bbls (146 sks) 15.8 ppg Premium Tail cement wI 3.00 %bwoc Expanding Agent, 0.40 %bwoc Dispersant, 0.10 %bwoc Retarder. Pumped Cement at the Following Rates: Pumped Rate Pressure 10.0 bbls 3.80 bpm 535 psi 25,0 bbls 4.80 bpm 705 psi 50,0 bbls 4.80 bpm 650 psi 75.0 bbls 4.80 bpm 625 psi 100.0 bbls 4.80 bpm 655 psi 124.0 bbls 2.50 bpm 130 psi Tail Cement 134.0 bbls 5.00 bpm 975 psi 144.0 bbls 5.00 bpm 930 psi 158.0 bbls 5.00 bpm 915 psi Opened Floor Valve and Washed Up Lines Behind Plug Dropped Top Plug, Switched to Rig Pumps and Displaced wI 306.5 bbls Clean SWat the Following Rates: Pumped Rate Pressure 10.0 bbls 7.00 bpm 200 psi 50.0 bbls 7.00 bpm 200 psi 100,0 bbls 7.00 bpm 320 psi 150.0 bbls 7.00 bpm 350 psi 200.0 bbls 7.00 bpm 680 psi 250.0 bbls 7.00 bpm 1,010 psi 17:30 - 19:00 1,50 CEMT P 19:00 - 21:30 2.50 CEMT P Printed: 12/22/2003 9: 19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/6/2003 End: 12/20/2003 12/17/2003 19:00 - 21 :30 2.50 CEMT P PROD1 Slowed Pump Rate 280.0 bbls 2,00 bpm 770 psi 300.0 bbls 2.00 bpm 1,080 psi 306.5 bbls 2.00 bpm 1 ,250 psi Wiper Plug Bumped wI 306.5 bbls Total Displacement Pumped. Pressured up to 2,000 psi. Cement in place @ 2120 hrs. Note: 25 bbls of Mud Mixed wI Seawater Displacement Through Pit Valve. 21 :30 - 22:00 0.50 CEMT P PROD1 Pressure Tested 7" Casing to 4,000 psi fl 30 Minutes, OK. Bled Off Pressure, Checked Floats, Floats Holding. 22:00 - 23:30 1.50 CEMT P PROD1 Bled Off Pressure, RID Test Equipment. RID 350 Ton Varco Elevators, Backed Out Landing Joint and LID Same. Changed Out Long Bails to Short Bails. Cleared Equipment From Rig Floor. 23:30 - 00:00 0.50 WHSUR P PROD1 M I U Packoff Running Tool and Packoff. RIH to Install Packoff. 12/18/2003 00:00 - 01 :30 1.50 WHSUR P PROD1 Held PJSM. Ran and Installed 7" Packoff, RILDS. Tested Packoff to 5,000 psi f/1 0 Minutes, OK. 01 :30 - 03:00 1.50 BOPSUR P COMP Held PJSM. Ran and Set Test Plug in Wellhead. Changed Out Top 7" Solid Rams f/3-1/2" x 6" Variable Rams. Body Tested BOP Stack to 3,500 psi f/1 0 Minutes, OK. Pulled Test Plug, R I D Test Equipment. 03:00 - 04:00 1.00 RUNCOMP COMP Rig and Crew Took 1 Hour of Downtime to Clean the Rig. 04:00 - 06:00 2.00 RUNCOMP COMP R I U 4-1/2" TC-II Completion Equipment. SIMOPS: R I U Secondary Kill Line to 9-5/8" x 7" Annulus Valve. Tested Line Against Closed Valve to 4,000 psi, OK. Bled Down Pressure, Opened Valve and Performed LOT: Strokes Pmp'd Pressure 5 200 psi 10 400 psi 15 450 psi 20 600 psi 25 710 psi 30 780 psi 35 830 psi 40 910 psi 45 975 psi 50 990 psi 55 950 psi 60 925 psi MW 10.2 ppg, Csg Shoe TVD 2,937', Pressure 975 psi = 16.58 ppg EMW. Performed Injectivity Test: 1 bpm 925 psi 2 bpm 1,025 psi 3bpm 1,075 psi Cement Compressive Strength 1,200 psi @ 5 hrs. 06:00 - 06:30 0.50 RUNCOMP COMP Held PJSM wI Drilling Crew, Nabors Casing, Baker, Toolpusher and Drilling Supervisor. 06:30 - 07:30 1.00 RUNCOMP COMP M I U 4-1/2" Tail Pipe:4-1/2" WLEG - XN Nipple Assembly wI RHC-M Sleeve - Lower X Nipple Assembly - 7" x 4-112" Baker Premier Packer - 1 Joint 4-1/2" 12.6# L-80 TC-II Tubing - Upper X Nipple Assembly. Torque Turned Connections, M I U Printed: 12/22/2003 9:19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/612003 End: 12/20/2003 12/18/2003 06:30 - 07:30 1.00 RUNCOMP COMP Torque 2,750 ft Ilbs. BAKERLOK'D All Connections Below Packer. 07:30 - 18:00 10.50 RUNCOMP COMP M I U and RIH wI 4-112" 12.6# L-80 TC-II Tubing. PI U Tubing wI Compensator and Torque Turned All Connections, M I U Torque 2,700 ft Ilbs. Tripping Speed Was Reduced to 15' I Minute When 7" x 4-112" Packer Entered 7" 29# Casing, Mud Cut Seawater Flowed Out of the Top of Tubing at Faster Tripping Speed. SIMOPS - Held PJSM. R I U Little Red Hot Oil Unit to 9-5/8" x 7" Annulus. Tested Lines to 3,500 psi. Bullheaded 65 bbls Dead Crude Oil Down Annulus to Freeze Protect. Injection Rate 2.4 bpm, 1,300 psi. 18:00 - 20:00 2,00 RUNCOMP COMP M I U Circulating Head and Line, Circulated to Displace Mud Cut Seawater Out of Wellbore. Pump Rate 2 bpm, 325 psi. Blew Down and RID Line and Circulating Head. 20:00 - 00:00 4.00 RUNCOMP COMP M I U and RIH wI 4-1/2" 12.6# L-80 TC-II Tubing. PI U Tubing wI Compensator and Torque Turned All Connections, M I U Torque 2,700 ft Ilbs. Tripping Speed Was Increased to 35' I Minute. 12/19/2003 00:00 - 03:00 3.00 RUNCOMP COMP M I U and RIH wI a Total of 191 Joints 4-112" 12.6# L-80 TC-II Tubing. PI U Tubing wI Compensator and Torque Turned All Connections, M I U Torque 2,700 ft Ilbs. 03:00 - 05:30 2.50 RUNCOMP COMP 05:30 - 06:00 0.50 RUNCOMP COMP 06:00 - 07:30 1.50 RUNCOMP COMP M I U Circulating Head and Lines. Pumped 150 bbls Clean Seawater to Displace Mud from Wellbore. Pumped 56 bbls Clean Seawater wI Corrosion Inhibitor, Chased wI 80 bbls Clean Seawater. Pump Rate 2.5 bpm, 375 psi. Blew Down and RID Lines. POOH, Broke Out and LID 10 Joints 4-1/2" Tubing. Dropped BallI Rod Assembly. M I U 20' Space Out Pup Joint and Joint# 182. M I U Tubing Hanger, XO and Landing Joint. String Weight Up 126,000#, String Weight Down 83,000#. Drained BOP Stack. RIH and Landed Tubing Hanger. RILDS. Completion Equipment Set At The Following Depths: Item Length Depth WLEG XN Nipple Assembly wI RHC-M Sleeve 22.23' 7,821.40' X Nipple Assembly 20.87' 7,778.30' 7" x 4-1/2" Premier Packer Assembly 27.11' 7,751.19' 1 Jt 4-112" 12.6# L-80 TC-II Tbg 41.27' 7,709.92' X Nipple Assembly 20.83' 7,689.09' 1 Jt 4-1/2" 12.6# L-80 TC-II Tbg 41.91' 7,647,18' #1 GLM Assembly 26.49' Printed: 12/22/2003 9:19:50 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-116 S-116 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/5/2003 12/20/2003 Spud Date: 12/612003 End: 12/20/2003 12/19/2003 06:00 - 07:30 1.50 RUNCOMP COMP 7,620.69' 73 Jts 4-112" 12.6# L-80 TC-II Tbg 3,053.94' 4,566.75' #2 GLM Assembly wI DCK Shear Valve 26.49' 4,540.26' 56 Jts 4-1/2" 12.6# L-80 TC-II Tbg 2,334.02' 2,206.24' X Nipple Assembly 20.78' 2,185.46' 50 Jts 4-112" 12.6# L-80 TC-II Tbg 2,094.94' 89.52' 4-112" 12.6# L-80 TC-II Pup Jt 19.80' 69.72' 1 Jt 4-112" 12.6# L-80 TC-II Tbg 42.41 ' 27.31' Tubing Hanger 3.15' 24.23' 07:30 - 10:30 3.00 RUNCOMP COMP Held PJSM, R I U Circulating Head and Lines. Tested Lines to 4,000 psi, OK. Pressured Up on Tubing To 2,800 psi To Set Packer, Continued To Pressure Up on Tubing To 4,000 psi. Tested Tubing fl 30 Minutes, OK. Bled Tubing Pressure Down to 2,500 psi and Shut In. Tested 7" x 4_112" Annulus to 3,500 psi fl 30 Minutes, OK. Bled Down Tubing Pressure and Observed DCK Valve Shear. Bled Down All Pressures. Blew Down and RID Lines. Broke Out and LID Landing Joint and XO. 10:30-11:00 0.50 WHSUR P COMP Set TWC and Tested from Below to 1,000 psi, OK. 11 :00 - 14:30 3.50 BOPSURP COMP Held PJSM. N I D BOPE. 14:30 - 18:00 3.50 WHSUR P COMP Held PJSM. N I U Adapter Flange and Production Tree. 18:00 - 20:30 2.50 WHSUR P COMP Tested Hanger, Neck Seal and Void to 5,000 psi, OK. Tested Tree to 5,000 psi, OK. 20:30 - 22:00 1.50 WHSUR P COMP Held PJSM. R I U DSM Lubricator, Pulled TWC, RID DSM. 22:00 - 23:00 1.00 WHSUR P COMP Held PJSM. R I U Little Red Hot Oil, Pressure Tested Lines to 3,000 psi, OK, 23:00 - 00:00 1.00 WHSUR P COMP Pumped 75 bbls of Diesel Freeze Protect Down Annulus. Beginning Pump Rate 1.5 bpm, 300 psi, Final Pump Rate 3.5 bpm, 2,400 psi. 12/20/2003 00:00 - 01 :30 1.50 WHSUR P COMP Opened Tree Valves and U-Tubed Diesel Freeze Protect. Blew Down Lines, RID Little Red Hot Oil. 01 :30 - 02:30 1.00 WHSUR P COMP Removed Secondary Annulus Valve. Set BPV. Installed Blind Flange on Tree. Secured Well. Release Rig at 0230 hrs, 121 20 I 2003. Printed: 12/22/2003 9:19:50 AM e . S-116 Prudhoe Bay Unit 50-029-23183-00-00 203-1 B1 Accept: Spud: Release: 12/06/03 12/07/03 12/20/03 Nabors 7ES POST RIG WORK 04/08/04 PULL B&R @ 7781' SLM. PULL DCK @ 4534' SLM. SET OGLV 24/64 @ 4534" SLM. RIH WI GS TO PULL RHC. 04/09/04 PULL 4.5" RHC FROM XN NIPPLE @ 7786' SLM. DRIFT WI 3-3/8" DUMMY GUN TO TD @ 8165' SLM. INFORM PAD OPERATOR OF LEAKING NEEDLE VALVE ON SSV - PANEL SHUT IN. TURN WELL OVER TO PAD OPERATOR - LEFT WELL SHUT IN. 04/15/04 USIT CEMENT BOND LOG RAN FROM 8250' TO TBG TAIL AT 7818', GOOD CEMENT THROUGHOUT WITH EXCEPTION OF SOME GAS CUT CEMENT FROM 7996'-8022'. TAG TAD AT 8186'. PAD OPERATOR NOTIFIED TO LEAVE WELL SHUT IN. 04/29/04 PERFORATED 7982'-7994' 5 SPF & 8001 '-8014' 5 SPF WITH 3 3/8" POWERJET PURE, PERF 8100'-8112' WITH 3 3/8" POWER JET 6 SPF. CHARGE DATA: 3406 PJ 38.6" PENE, 0.45" EH, 22.7 GMS. CORRELATED TO SWS USIT 15-APRIL-2004. WELL SHUT IN. e e S-116 Survey Report Schlumberger Report Date: 14·Dec-03 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Expioration Alaska Vertical Section Azimuth: 216.720' Field: Prudhoe Bay Un~ - WOA Vertical Section Origin: N O.OOOft, E O.Oooft Structure I Slot: 8-PAD/8·116 TVD Reference Datum: KB Well: 8·116 TVD Reference Elevation: 64.40 ft relative to M8L Borehole: 8-116 Sea Bed / Ground Level Elevation: 35.50 ft relative to M8L UWVAPI#: 500292318300 Magnetic Declination: 25.301' Survey Name / Date: 8-116/ December 14, 2003 Total Field Strength: 57565.492 n T Tort I AHD I DDII ERD ratio: 120.636' /3834.76 ft /5.734/ 0.542 Ma9netic Dip: 80.855' Grid Coordinate System: NAD27 Alaska 8tate Planes, Zone 04, U8 Feet Declination Date: December 09, 2003 location Lat/Long: N 702119.111, W 149 22.994 Magnetic Declination Model: BGGM 2003 Location Grid NÆ YIX: N 5980474.810 ftU8, E 618929.950 ftU8 North Reference: True North Grid Convergence Angle: +0.90962871 ' Total Carr Ma9 North -> True North: +25.301 ' Grid Scale Factor: 0.99991607 local Coordinates Referenced To: We~ Head Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Alon9 Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easliog Lat~ude Long~ude Depth Section Departure (ft) ( deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg/1ooft) (deg/1ooft) (deg/1ooft) (flUS) (flUS) 0.00 0.00 0.00 0.00 -64.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5980474.81 618929.95 N 70 21 19.111 W 14922.994 303.16 0.68 263.06 303.15 238.75 1.24 1.80 -0.22 -1.79 0.22 0.22 0.00 5980474.56 618928.17 N702119.109 W 14923.047 393.14 0.96 253.51 393.12 328.72 2.21 3.08 -0.50 -3.04 0.35 0.31 -10.61 5980474.27 618926.92 N 70 21 19.106 W 14923.083 483.39 1.92 255.29 483 .34 418.94 4.00 5.35 -1.09 -5.23 1.06 1.06 1.97 5980473.63 618924.74 N 70 21 19.100 W 14923.147 573.30 2.72 261.83 573.18 508.78 6.69 8.99 -1.78 -8.79 0.94 0.89 7.27 5980472.89 618921.19 N 70 21 19.093 W 14923.252 661.80 2.90 265.07 661.57 597.17 9.65 13.32 -2.27 -13.10 0.27 0.20 3.66 5980472.33 618916.89 N 70 21 19.089 W 14923.377 752.63 4.23 269.57 752.23 687.83 13.20 18.97 -2.49 -18.74 1.50 1.46 4.95 5980472.02 618911.25 N 70 21 19.086 W 14923.542 843.20 5.84 285.04 842.45 778.05 16.92 26.87 -1.32 -26.53 2.31 1.78 17.08 5980473.07 618903.44 N 70 21 19.098 W 14923.770 941.59 7.43 278.33 940.18 875.78 21.80 38.23 0.90 -37.66 1.80 1.62 -6.82 5980475.11 618892.28 N702119.120 W 14924.095 1038.53 9.62 281.87 1036.04 971.64 28.18 52.59 3.47 -51.79 2.32 2.26 3.65 5980477.46 618878.11 N 7021 19.145 W 14924.508 1132.61 10.70 276.88 1128.65 1064.25 35.83 69.18 6.14 -68.16 1.48 1.15 -5.30 5980479.86 618861.71 N 7021 19.171 W 14924.987 1227.01 11.17 269.91 1221.34 1156.94 45.67 87.06 7.17 -86.00 1.49 0.50 -7.38 5980480.61 618843.85 N 7021 19.182 W 14925.508 1323.15 13.23 259.24 1315.31 1250.91 59.36 107.32 5.10 -106.13 3.17 2.14 -11.10 5980478.23 618823.76 N 7021 19.161 W 14926.097 1419.37 15.46 250.27 1408.54 1344.14 78.17 131.12 -1.28 -129.02 3.27 2.32 -9.32 5980471.48 618800.98 N 70 21 19.098 W 14926.766 1515.25 18.04 239.83 1500.36 1435.96 102.49 158.68 -13.06 -153.90 4.12 2.69 -10.89 5980459.31 618776.29 N 70 21 18.983 W 14927.493 1611.23 20.17 233.13 1591.06 1526.66 132.04 190.06 -30.47 -179.99 3.18 2.22 -6.98 5980441 .49 618750.48 N 70 21 18.811 W 14928.256 1706.01 23.65 226.84 1678.99 1614.59 166.44 225.39 -53.28 -206.94 4.42 3.67 -6.64 5980418.25 618723.90 N 70 21 18.587 W 14929.044 1803.43 28.74 221.64 1766.39 1701.99 209.05 268.35 -84.18 -236.78 5.73 5.22 -5.34 5980386.89 618694.56 N 70 21 18.283 W 14929.916 1897.37 29.63 219.96 1648.41 1784.01 254.73 314.16 -118.86 -266.70 1.29 0.95 -1.79 5980351.74 618665.19 N 70 21 17.942 W 149210.790 1992.13 30.91 219.06 1930.25 1865.85 302.44 361.92 -155.71 -297.08 1.43 1.35 -0.95 5980314.41 618635.40 N 70 21 17.580 W 149211.679 2088.63 32.93 216.64 2012.15 1947.75 353.44 412.94 -195.96 -328.43 2.42 2.09 -2.30 5980273.68 618604.70 N 7021 17.184 W 149212.595 2185.83 39.86 216.70 2090.35 2025.95 411.08 470.58 -242.13 -362.93 7.13 7.13 -0.14 5980226.97 618570.94 N 7021 16.730 W 149213.603 2280.32 43.73 216.47 2160.78 2096.38 474.04 533.54 -292.69 -400.45 4.10 4.10 -0.24 5980175.83 618534.23 N 7021 16.232 W 149214.700 2376.59 43.48 215.26 2230.49 2166.09 540.43 599.93 -346.49 -439.35 0.90 -0.26 -1.26 5980121.42 618496.19 N 702115.703 W 149215.837 2471.97 44.04 214.53 2299.38 2234.98 606.36 665.90 -400.60 -477.09 0.79 0.59 -0.77 5980066.72 618459.32 N702115.171 W 149216.940 2567.66 46.54 212.15 2366.70 2302.30 674.23 733.90 -457.42 -514.43 3.15 2.61 -2.49 5980009.32 618422.89 N 7021 14.612 W 149218.031 2662.39 48.27 211.13 2430.81 2366.41 743.69 803.63 -516.79 -551.00 1.99 1.83 -1.08 5979949.38 618387.27 N 7021 14.028 W149219.100 2758.63 49.29 211.27 2494.23 2429.83 815.74 876.02 -578.71 -588.50 1.07 1.06 0.15 5979886.88 618350.76 N 7021 13.419 W 149220.196 2854.37 49.18 210.65 2556.74 2492.34 887.89 948.53 -640.89 -625.81 0.50 -011 -0.65 5979824.12 618314.45 N 7021 12.808 W 149221.286 2950.18 49.26 210.31 2619.32 2554.92 960.01 1021.08 -703.41 -662.61 0.28 0.08 -0.35 5979761.03 618278.65 N 7021 12.193 W 149 2 22.362 3046.02 50.74 211.89 2680.92 2616.52 1033.07 1094.49 -766.27 -700.54 1.99 1.54 1.65 5979697.58 618241.73 N 70 2111.575 W 149223.470 3141.28 49.97 211.83 2741.70 2677.30 1106.16 1167.84 -828.57 -739.25 0.81 -0.81 -0.06 5979634.68 618204.01 N 70 21 10.962 W 149224.602 3237.67 51.07 213.25 2802.99 2738.59 1180.35 1242.24 -891.28 -779.28 1.61 1.14 1.47 5979571.35 618164.99 N 70 21 10.345 W 149225.771 3332.71 50.31 214.12 2863.20 2798.80 1253.78 1315.77 -952.47 -820.06 1.07 -0.80 0.92 5979509.53 618125.19 N 7021 9.743 W 149226.963 3394.67 50.52 213.89 2902.68 2838.28 1301.48 1363.53 -992.05 -846.76 0.44 0.34 -0.37 5979469.53 618099.12 N 70 21 9.354 W 149227.743 3425.90 49.32 213.79 2922.79 2858.39 1325.34 1387.42 -1011.90 -860.Q7 3.85 -3.84 -0.32 5979449.47 618086.13 N70219.159 W 149228.132 3521.75 48.00 213.48 2986.10 2921.70 1397.20 1459.38 -1071.81 -899.93 1.40 -1.38 -0.32 5979388.94 618047.22 N 7021 8.569 W 149 2 29.297 3616.71 48.68 212.27 3049.22 2984.82 1467.99 1530.33 -1131.40 -938.44 1.19 0.72 -1.27 5979328.76 618009.67 N 70 21 7.983 W 149230.422 3713.49 48.40 211.42 3113.30 3048.90 1540.25 1602.85 -1193.01 -976.70 0.72 -0.29 -0.88 5979266.55 617972.39 N 7021 7.377 W 149231.541 3809.95 47.29 209.99 3178.04 3113.64 1611.36 1674.36 -1254.48 -1013.22 1.59 -1.15 -1.48 5979204.51 617936.86 N 7021 6.773 W 149232.608 3906.14 45.25 208.30 3244.53 3180.13 1680.26 1743.86 -1315.17 -1047.08 2.47 -2.12 -1.76 5979143.29 617903.96 N70216.176 W 149233.597 4001.49 42.52 205.74 3313.25 3248.85 1745.40 1809.95 -1374.02 -1077.14 3.41 -2.86 -2.68 5979083.98 617874.85 N 7021 5.597 W 149234.475 4098.23 40.58 202.13 3385.65 3321.25 1807.96 1874.10 -1432.63 -1103.19 3.18 -2.01 -3.73 5979024.97 617849.73 N 7021 5.020 W 149 2 35.236 4193.26 38.46 204.04 3458.96 3394.56 1866.71 1934.56 -1488.26 -1126.88 2.57 -2.23 2.01 5978968.98 617826.93 N 7021 4.473 W 149 2 35.929 4288.44 36.53 207.82 3534.48 3470.08 1923.59 1992.48 -1540.36 -1152.16 3.15 -2.03 3.97 5978916.49 617802.48 N 70 21 3.961 W 149236.667 4382.29 34.71 210.55 3610.77 3546.37 1977.76 2047.13 -1588.08 -1178.79 2.57 -1.94 2.91 5978868.35 617776.62 N 7021 3.492 W 149 2 37.445 4477.98 32.75 214.39 3690.36 3625.96 2030.71 2100.25 -1632.91 -1207.26 3.03 -2.05 4.01 5978823.08 617748.87 N 7021 3.051 W 149 2 38.277 4576.33 30.74 217.89 3774.00 3709.60 2082.43 2151.98 -1674.71 -1237.73 2.77 -2.04 3.56 5978780.81 617719.07 N 70 21 2.639 W 149239.167 4688.36 29.98 219.47 3853.41 378901 2128.92 2198.50 -1711.02 -1266.79 1.20 -0.83 1.72 5978744.04 617690.59 N 70 21 2.282 W 149240.016 4764.71 30.19 219.14 3936.78 3872.38 2177.17 2246.79 -1748.40 -1297.38 0.28 0.22 -0.34 5978706.19 617660.60 N 70211.915 W 149240.910 8urveyEditor Ver 3.1 RT-8P3.03-HF2.03 Bld( d031 rt-546 ) 8-116\8-116\8-116\8-116 Generated 1/21/20049:54 AM Page 1 of 2 e e r Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easling Lat~ude Longitude Depth Section Departure (ft) ( deg) ( deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg/1ooft) (deg/1ooft) (deg/looft) (1tUS) (ftUS) 4861 .23 29.93 218.49 4020.32 3955.92 2225.48 2295.14 -1786.07 -1327.69 0.43 -0.27 -0.67 5978668.05 617630.89 N70211.544 W 149241.796 4956.35 29.82 217.82 4102.80 4038.40 2272.85 2342.52 -1823.32 -1356.96 0.37 -0.12 -0.70 5978630.33 617602.22 N 70211.178 W 149242.651 5052.16 30.13 217.79 4185.79 4121.39 2320.71 2390.39 -1861.14 -1386.30 0.32 0.32 -0.03 5978592.06 617573.49 N 70 21 0.806 W 149243.508 5147.79 30.11 217.52 4268.51 4204.11 2368.69 2438.38 -1899.13 -1415.62 0.14 -0.02 -0.28 5978553.61 617544.78 N 70 21 0.432 W 149244.365 5244.30 29.97 218.22 4352.06 4287.66 2416.99 2486.69 -1937.27 -1445.28 0.39 -0.15 0.73 5978515.00 617515.73 N 70 21 0.057 W 149245.231 5338.50 29.97 216.90 4433.66 4369.26 2464.04 2533.75 -1974.57 -1473.96 0.70 0.00 -1.40 5978477.26 617487.65 N 70 20 59.690 W 149246.069 5434.21 30.02 216.64 4516.56 4452.16 2511.89 2581.59 -2012.90 -1502.60 0.15 0.05 -0.27 5978438.48 617459.62 N 70 20 59.313 W 149246.906 5528.60 30.44 217.02 4598.11 4533.71 2559.41 2629.12 -2050.94 -1531.09 0.49 0.44 0.40 5978400.00 617431.74 N 70 20 58.939 W 149247.739 5624.72 30.37 216.44 4681.01 4616.61 2608.06 2677.76 -2089.93 -1560.18 0.31 -om -0.60 5978360.56 617403.27 N 70 20 58.555 W 149248.588 5720.50 30.70 215.65 4763.51 4699.11 2656.72 2726.43 -2129.27 -1588.81 0.54 0.34 -0.82 5978320.77 617375.27 N 70 20 58.168 W 149249.425 5816.28 30.87 216.06 4845.79 4781.39 2705.73 2775.45 -2169.01 -1617.53 0.28 0.18 0.43 5978280.59 617347.20 N 70 20 57.777 W 149250.264 5912.21 31.18 216.42 4928.00 4863.60 2755.17 2824.89 -2208.88 -1646.76 0.38 0.32 0.38 5978240.25 617318.60 N 702057.385 W 149251.118 6007.02 30.72 215.30 5009.31 4944.91 2803.93 2873.65 -2248.40 -1675.32 0.78 -0.49 -1.18 5978200.29 617290.67 N 70 20 56.996 W 149251.952 6102.57 28.71 213.97 5092.29 5027.89 2851.25 2921.01 -2287.35 -1702.25 2.21 -2.10 -1.39 5978160.92 617264.37 N 702056.613 W 149252.739 6198.71 29.28 213.53 5176.38 5111.98 2897.79 2967.61 -2326.10 -1728.14 0.63 0.59 -0.46 5978121.77 617239.10 N 70 20 56.232 W 149253.495 6295.60 29.73 215.20 5260.71 5196.31 2945.47 3015.32 -2365.49 -1755.08 0.97 0.46 1.72 5978081.97 617212.79 N 70 20 55.845 W 149254.282 6390.38 30.04 214.49 5342.88 5278.48 2992.66 3062.55 -2404.24 -1782.06 0.50 0.33 -0.75 5978042.79 617186.43 N 7020 55.463 W 149255.070 6485.24 30.65 214.38 5424.75 5360.35 3040.55 3110.47 -2443.77 -1809.16 0.65 0.64 -0.12 5978002.84 617159.97 N 70 20 55.075 W 149255.862 6582.13 29.45 213.52 5508.61 5444.21 3089.01 3158.99 -2484.01 -1836.26 1.32 -1.24 -0.89 5977962.18 617133.51 N 70 20 54.679 W 149256.654 6677.70 27.64 213.98 5592.56 5528.16 3134.61 3204.66 -2521.98 -1861.63 1.91 -1.89 0.48 5977923.81 617108.75 N 70 20 54.305 W 149257.395 6773.41 27.61 213.69 5677.36 5612.96 3178.94 3249.03 -2558.85 -1886.34 0.14 -0.03 -0.30 5977886.56 617084.63 N 70 20 53.943 W 149258.116 6868.53 27.75 212.88 5761.60 5697.20 3223.04 3293.22 -2595.78 -1910.58 0.42 0.15 -0.85 5977849.25 617060.98 N 70 20 53.579 W 149 2 58.825 6964.95 27.88 212.93 5846.88 5782.48 3267.93 3338.21 -2633.56 -1935.03 0.14 0.13 0.05 5977811.09 617037.14 N 70 20 53.208 W 149259.539 7059.82 25.72 217.05 5931.56 5867.16 3310.66 3380.97 -2668.61 -1959.49 3.00 -2.28 4.34 5977775.66 617013.24 N 70 20 52.863 W 14930.253 7155.61 25.84 217.10 6017.81 5953.41 3352.32 3422.63 -2701.85 -1984.61 0.13 0.13 0.05 5977742.03 616988.65 N 702052.536 W 14930.987 7250.92 25.80 215.65 6103.61 6039.21 3393.83 3464.14 -2735.27 -2009.23 0.66 -0.04 -1.52 5977708.22 616964.57 N 70 20 52.207 W 14931.706 7347.57 24.97 215.70 6190.93 6126.53 3435.26 3505.57 -2768.93 -2033.39 0.86 -0.86 0.05 5977674.19 616940.95 N 70 20 51.876 W 14932.412 7441.76 23.14 218.12 6276.94 6212.54 3473.64 3543.96 -2799.64 -2056.42 2.21 -1.94 2.57 5977643.12 616918.41 N 70 20 51.574 W 14933.085 7537.33 22.12 219.40 6365.15 6300.75 3510.39 3580.73 -2828.32 -2079.43 1.19 -1.07 1.34 5977614.08 616895.86 N 70 20 51.292 W 14933.757 7633.33 21.30 219.37 6454.34 6389.94 3545.86 3616.24 -2855.76 -2101.96 0.85 -0.85 -0.03 5977586.29 616873.76 N 70 20 51.022 W 14934.415 7729.19 20.51 220.60 6543.89 6479.49 3580.01 3650.45 -2881.97 -2123.94 0.94 -0.82 1.28 5977559.73 616852.21 N 702050.764 W 14935.057 7822.53 19.88 220.54 6631 .49 6567.09 3612.16 3682.67 -2906.45 -2144.89 0.68 -0.67 -0.06 5977534.93 616831.65 N 70 20 50.523 W 14935.669 7920.98 19.25 220.49 6724.25 6659.85 3645.05 3715.64 -2931.51 -2166.31 0.64 -0.64 -0.05 5977509.53 616810.63 N 70 20 50.277 W 14936.295 8013.85 19.D4 219.63 6811.99 6747.59 3675.46 3746.09 -2954.82 -2185.91 0.38 -0.23 -0.93 5977485.91 616791.40 N 70 20 50.048 W 14936.867 8112.93 18.79 218.89 6905.72 6841.32 3707.54 3778.21 -2979.69 -2206.24 0.35 -0.25 -0.75 5977460.73 616771.48 N 70 20 49.803 W 14937.461 8210.74 18.41 217.98 6998.42 6934.02 3738.73 3809.41 -3004.13 -2225.64 0.49 -0.39 -0.93 5977435.99 616752.47 N 70 20 49.563 W 14938.027 8291.00 18.41 217.98 7074.57 7010.17 3764.07 3834.76 -3024.11 -2241.23 0.00 0.00 0.00 5977415.77 616737.20 N 70 20 49.366 W 14938.483 LeQal Description: Northina (Y) [ftUS] Eastina (XI [ftUSl 8urface : 4271 F8L 4502 FEL 835 T12N R12E UM 5980474.81 618929.95 BHL: 1246 F8L 1467 FEL 834 T12N R12E UM 5977415.77 616737.20 8urveyEditor Ver 3.1 RT-8P3.03-HF2.03 Bld( d031 rl-546 ) 8-116\8-116\8-116\8-116 Generated 1/21/20049:54 AM Page 2 of 2 ~ e "TREE = 4-1/16" CIW WELLHEAD = FI'vC ACnJA TOR = NA A_'L.A 'H.A KB. B...BI = 64.7' BF. B...EV = 36.2' -KOP~ 500' ._- - , IlAax Angle = 51 @ 3046' A< ....__~<N_'..·~" < ",_ ~< ~_~_~~ Datum fv[) = 7760' ^A ..m..·..~A.. '. M"~" 'M"'''_.~,,,~.MmM' Datum 1V 0 = 6600' 9-518" CSG, 40#, L-BO, 10 = 8.835" H 3450' r-- I Minimum ID = 3.725" @ 7809' I 4-1/2" HES XN NIPPLE 4-1/2"TBG,12.6#, L-BO, .0152 bpf, 10 =3.958" H 7820' PffiFORA TION SUMM'\ RY REF LOG: ÆX 12/14/03 ANGLE AT TOP PERF: 19 @ 7982' t-bte: Refer to A"oduction DB for historical Jerf data SIZE SPF INTER\! AL OpnlSqz DA TE 3-3/8" 5 7982 - 7994 0 04/29/04 3-3/8" 5 8001 - 8014 0 04/29/04 3-3/8" 6 8100 - 8112 0 04/29/04 1 R3TD H 8199' 17" CSG, 29#, L-BO, 10 = 6.184" H 8279' DA TE RBI BY COM'v18\1TS 12/19103 TMN/KK ORIGINAL COMPLETION 04108104 JLJ/KAK GLV 00 04129104 MJA/KAK IPffiFS e 5-116 :---- 1017 H 9-518" TAM PORT COLLAR I 2195' H 4-1/2"I-ESXNIP,10=3.813" I l ST fv[) 1V 0 2 4550 3751 1 7630 6451 GAS LIFT M'\NORB...S DEV lYPE VLV LATa-i 31 KBG-2 SO BK 21 KBG-2 OMY BK PORr DATE 24 04108104 12/19103 7699' H 4-1/2" HEB X NIP, 10 = 3.813" Z Z ---I 7761' H 7" X 4-1/2" BKR !'REM PKR, 10 = 3.875" 7788' H 4-1/2" HEB X NIP, 10 = 3.813" 7809' H 4-1/2" HEB XN NIP, 10 = 3.725" I 7,821' H 4-112" WLEG, 10= 3.958" I \ 7927' H 7" MARKffi Jf WI RA TAG I 8102' H 7" MARKffi Jf W/ RA TA G I ~ DATE REV BY COMrvENTS AURORA lJ\IlT WELL: &-116 PffiMT t-b: 2031810 AA No: 50-029-23183-00 SEC 35, T12N, R12E, 4271' FSL & 4502' FEL BP Exploration (Ataska) . . &03-'}ð) Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No S-116 Date Dispatched: 5-Dec-03 Installation/Rig Nabors 7ES Dispatched By: F. Alabi Data No Of Prints No of Floppies Surveys 2 Received By: <-·~-~rf'U_.~,-ç.G~")~::::.ry,\ Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 LWD Log Delivery V 1.1 , 10-02-03 Rr:erlV1=nm I , ' t) r- '\00. ~ \....:,i¡ t...L (.. i.j. Schlumberger Private Alaska Oil & Gas Cons. Comrnillan Am:horage R~ðN\~ SCHLUMBERGER Survey report Client.. ...... ...........: BP Exploration (Alaska) Inc. Field... .............. ...: Prudhoe Bay Unit - Aurora Well.....................: S-116 API number..... ..........: 50-029-23183-00 Engineer. ................: B.Barnes Rig:...... ...............: Nabors 7ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Seal Level Depth reference..........: Driller's pipe Tally GL above permanent.......: 28.80 ft KB above permanent.......: N/A DF above permanent.......: 64.40 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 216.72 degrees RECEIVED !.~:: ? r, 2004 \""..... , .... .--. ,A.iaska Oil & Gas Cons. Cornmialktn ftJiGttorage [(c)2003 IDEAL ID8 1C_01J 'R~'ü\'f\~ 14-Dec-2003 08:32:54 Spud date. . . . . . . . . . . . . . . . : Last survey date... ......: Total accepted surveys...: MD of first survey. ......: MD of last survey... .....: .. t)C)~3 --\ B \ Page 1 of 4 07-Dec-03 14-Dec-03 87 0.00 ft 8291. 00 ft . ----- Geomagnetic data ---------------------- Magnetic model... .... ....: BGGM version 2003 Magnetic date. ...........: 07-Dec-2003 Magnetic field strength..: 1151.33 HCNT Magnetic dec (+E/W-).....: 25.30 degrees Magnetic dip.............: 80.85 degrees ----- MWD survey Reference Reference G.. .... ..... ...: Reference H..............: Reference Dip..... .......: Tolerance of G..... ......: Tolerance of H...... .....: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151. 33 HCNT 80.85 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections ----------------------~---- Magnetic dec (+E/W-).....: 25.30 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.30 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction . SCHLUMBERGER Survey Report 14-Dec-2003 08:32:54 Page 2 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0 TIP None 2 303.16 0.68 263.06 303.16 303.15 1.24 -0.22 -1. 79 1. 80 263.06 0.22 G-MAG None 3 393.14 0.96 253.51 89.98 393.12 2.21 -0.50 -3.04 3.08 260.73 0.35 G-MAG None 4 483.39 1. 92 255.29 90.25 483.34 4.00 -1. 09 -5.23 5.34 258.17 1. 06 G-MAG None 5 573.30 2.72 261.83 89.91 573.18 6.69 -1. 78 -8.79 8.97 258.56 0.94 G-MAG None 6 661.80 2.90 265.07 88.50 661. 57 9.65 -2.27 -13 .10 13.30 260.17 0.27 G-MAG None 7 752.63 4.23 269.57 90.83 752.23 13 .20 -2.49 -18.74 18.91 262.42 1.50 G-MAG None . 8 843.20 5.84 285.04 90.57 842.45 16.92 -1. 32 -26.53 26.57 267.15 2.31 G-MAG None 9 941.59 7.43 278.33 98.39 940.18 21. 80 0.90 -37.66 37.67 271.37 1. 80 G-MAG None 10 1038.53 9.62 281.87 96.94 1036.04 28.18 3.47 -51.79 51.91 273.84 2.32 G-MAG None 11 1132.61 10.70 276.88 94.08 1128.65 35.83 6.14 -68.16 68.43 275.14 1.48 G-MAG None 12 1227.01 11.17 269.91 94.40 1221. 34 45.67 7.17 -86.00 86.30 274.77 1.49 G-MAG None 13 1323.15 13 .23 259.24 96.14 1315.31 59.36 5.10 -106.13 106.25 272.75 3.17 G-MAG None 14 1419.37 15.46 250.27 96.22 1408.54 78 .17 -1.28 -129.02 129.03 269.43 3.27 G-MAG None 15 1515.25 18.04 239.83 95.88 1500.36 102.49 -13.06 -153.90 154.45 265.15 4.12 G-MAG None 16 1611.23 20.17 233.13 95.98 1591.06 132.04 -30.47 -179.99 182.55 260.39 3.18 G-MAG None 17 1706.01 23.65 226.84 94.78 1678.99 166.44 -53.28 -206.94 213.69 255.56 4.42 G-MAG None 18 1803.43 28.74 221. 64 97.42 1766.39 209.05 -84.18 -236.78 251.30 250.43 5.73 G-MAG None 19 1897.37 29.63 219.96 93.94 1848.41 254.73 -118.86 -266.70 291.99 245.98 1.29 G-MAG None 20 1992.13 30.91 219.06 94.76 1930.25 302.44 -155.71 -297.08 335.42 242.34 1.43 G-MAG None 21 2088.63 32.93 216.84 96.50 2012.15 353.44 -195.96 -328.43 382.45 239.18 2.42 G-MAG None . 22 2185.83 39.86 216.70 97.20 2090.34 411.08 -242.13 -362.93 436.29 236.29 7.13 G-MAG None 23 2280.32 43.73 216.47 94.49 2160.78 474.04 -292.69 -400.45 496.01 233.84 4.10 G-MAG None 24 2376.59 43.48 215.26 96.27 2230.49 540.43 -346.49 -439.35 559.54 231.74 0.90 G-MAG None 25 2471.97 44.04 214.53 95.38 2299.38 606.36 -400.60 -477.09 622.97 229.98 0.79 G-MAG None 26 2567.66 46.54 212.15 95.69 2366.70 674.23 -457.42 -514.43 688.38 228.36 3.15 G-MAG None 27 2662.39 48.27 211.13 94.73 2430.81 743.69 -516.79 -551.00 755.43 226.84 1. 99 G-MAG None 28 2758.63 49.29 211.27 96.24 2494.22 815.74 -578.71 -588.50 825.37 225.48 1. 07 G-MAG None 29 2854.37 49.18 210.65 95.74 2556.74 887.89 -640.89 -625.81 895.75 224.32 0.50 G-MAG None 30 2950.18 49.26 210.31 95.81 2619.32 960.01 -703.41 -662.61 966.35 223.29 0.28 G-MAG None [(c)2003 IDEAL ID8_1C_OIJ SCHLUMBERGER Survey Report 14-Dec-2003 08:32:54, Page 3 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 3046.02 50.74 211.89 95.84 2680.92 1033.07 -766.27 -700.54 1038.23 222.43 1. 99 G-MAG None 32 3141.28 49.97 211.83 95.26 2741.70 1106.16 -828.57 -739.25 1110.41 221. 74 0.81 G-MAG None 33 3237.67 51.07 213.25 96.39 2802.99 1180.35 -891.28 -779.28 1183.91 221.16 1. 61 G-MAG None 34 3332.71 50.31 214.12 95.04 2863.20 1253.78 -952.47 -820.06 1256.86 220.73 1. 07 G-MAG None 35 3394.67 50.52 213.89 61. 96 2902.68 1301.48 -992.05 -846.76 1304.29 220.48 0.44 G-MAG None 36 3425.90 49.32 213 .79 31. 23 2922.79 1325.34 -1011.90 -860.07 1328.03 220.36 3.85 SLB INC TREND . - 37 3521.75 48.00 213.48 95.85 2986.10 1397.20 -1071.81 -899.93 1399.52 220.02 1.40 G-MAG None 38 3616.71 48.68 212.27 94.96 3049.22 1467.99 -1131.40 -938.44 1469.94 219.67 1.19 G-MAG None 39 3713.49 48.40 211.42 96.78 3113.30 1540.25 -1193.01 -976.70 1541.82 219.31 0.72 G-MAG None 40 3809.95 47.29 209.99 96 .46 3178.04 1611.36 -1254.48 -1013.22 1612.56 218.93 1.59 G-MAG None 41 3906.14 45.25 208.30 96.19 3244.53 1680.26 -1315.17 -1047.08 1681.09 218.53 2.47 G-MAG None 42 4001.49 42.52 205.74 95.35 3313.25 1745.40 -1374.02 -1077.14 1745.90 218.09 3.41 G-MAG None 43 4098.23 40.58 202.13 96.74 3385.65 1807.96 -1432.63 -1103.19 1808.17 217.60 3.18 G-MAG None 44 4193.26 38.46 204.04 95.03 3458.96 1866.71 -1488.26 -1126.88 1866.76 217.13 2.57 G-MAG None 45 4288.44 36.53 207.82 95.18 3534.48 1923.59 -1540.36 -1152.16 1923.59 216.80 3.15 G-MAG None 46 4382.29 34.71 210.55 93.85 3610.77 1977.76 -1588.08 -1178.79 1977.76 216.59 2.57 G-MAG NOne 47 4477.98 32.75 214.39 95.69 3690.36 2030.71 -1632.91 -1207.26 2030.73 216.48 3.03 G-MAG None 48 4576.33 30.74 217.89 98.35 3774.00 2082.43 -1674.71 -1237.73 2082.45 216.47 2.77 G-MAG None 49 4668.36 29.98 219.47 92.03 3853.41 2128.92 -1711.02 -1266.79 2128.93 216.52 1. 20 G-MAG None 50 4764.71 30.19 219.14 96.35 3936.78 2177.17 -1748.40 -1297.38 2177.17 216.58 0.28 G-MAG None 51 4861.23 29.93 218.49 96.52 4020.32 2225.48 -1786.07 -1327.69 2225.49 216.63 0.43 G-MAG None . 52 4956.35 29.82 217.82 95.12 4102.80 2272.85 -1823.32 -1356.96 2272.85 216.66 0.37 G-MAG None 53 5052.16 30.13 217.79 95.81 4185.79 2320.71 -1861.14 -1386.30 2320.71 216.68 0.32 G-MAG None 54 5147.79 30.11 217.52 95.63 4268.51 2368.69 -1899.14 -1415.62 2368.69 216.70 0.14 G-MAG None 55 5244.30 29.97 218.22 96.51 4352.06 2416.99 -1937.27 -1445.28 2416.99 216.72 0.39 G-MAG None 56 5338.50 29.97 216.90 94.20 4433.66 2464.04 -1974.57 -1473.96 2464.04 216.74 0.70 G-MAG None 57 5434.21 30.02 216.64 95.71 4516.56 2511.89 -2012.90 -1502.60 2511.89 216.74 0.15 G-MAG None 58 5528.60 30.44 217.02 94.39 4598.11 2559.41 -2050.94 -1531.09 2559.41 216.74 0.49 G-MAG None 59 5624.72 30.37 216.44 96.12 4681.01 2608.06 -2089.93 -1560.18 2608.06 216.74 0.31 G-MAG None 60 5720.50 30.70 215.65 95.78 4763.51 2656.72 -2129.27 -1588.81 2656.72 216.73 0.54 G-MAG None [(c)2003 IDEAL ID8_1C_01J .- SCHLUMBERGER Survey Report 14-Dec-2003 08:32:54 Page 4 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5816.28 30.87 216.06 95.78 4845.79 2705.73 -2169.01 -1617.53 2705.73 216.71 0.28 G-MAG None 62 5912.21 31.18 216.42 95.93 4928.00 2755.17 -2208.88 -1646.76 2755.17 216.71 0.38 G-MAG None 63 6007.02 30.72 215.30 94.81 5009.31 2803.93 -2248.40 -1675.32 2803.93 216.69 0.78 G-MAG None 64 6102.57 28.71 213.97 95.55 5092.29 2851.25 -2287.35 -1702.25 2851.25 216.66 2.21 G-MAG None 65 6198.71 29.28 213.53 96.14 5176.38 2897.79 -2326.10 -1728.14 2897.80 216.61 0.63 G-MAG None 66 6295.60 29.73 215.20 96.89 5260.71 2945.47 -2365.49 -1755.08 2945.48 216.57 0.97 G-MAG None . 67 6390.38 30.04 214.49 94.78 5342.88 2992.66 -2404.24 -1782.06 2992.68 216.55 0.50 G-MAG None 68 6485.24 30.65 214.38 94.86 5424.75 3040.55 -2443.77 -1809.16 3040.57 216.51 0.65 G-MAG None 69 6582.13 29.45 213.52 96.89 5508.61 3089.01 -2484.01 -1836.26 3089.04 216.47 1. 32 G-MAG None 70 6677.70 27.64 213.98 95.57 5592.56 3134.61 -2521.98 -1861.63 3134.65 216.43 1. 91 G-MAG None 71 6773.41 27.61 213.69 95.71 5677.36 3178.94 -2558.85 -1886.34 3178.99 216.40 0.14 G-MAG None 72 6868.53 27.75 212.88 95.12 5761.60 3223.04 -2595.78 -1910.58 3223.11 216.35 0.42 G-MAG None 73 6964.95 27.88 212.93 96.42 5846.88 3267.93 -2633.56 -1935.03 3268.02 216.31 0.14 G-MAG None 74 7059.82 25.72 217.05 94.87 5931.56 3310.66 -2668.61 -1959.49 3310.76 216.29 3.00 G-MAG None 75 7155.61 25.84 217.10 95.79 6017.81 3352.32 -2701.85 -1984.61 3352.41 216.30 0.13 G-MAG None 76 7250.92 25.80 215.65 95.31 6103.61 3393.83 -2735.27 -2009.23 3393.92 216.30 0.66 G-MAG None 77 7347.57 24.97 215.70 96.65 6190.93 3435.26 -2768.93 -2033.39 3435.35 216.29 0.86 G-MAG None 78 7441.76 23.14 218.12 94.19 6276.93 3473.64 -2799.64 -2056.42 3473.73 216.30 2.21 G-MAG None 79 7537.33 22.12 219.40 95.57 6365.15 3510.39 -2828.32 -2079.43 3510.47 216.32 1.19 G-MAG None 80 7633.33 21.30 219.37 96.00 6454.34 3545.86 -2855.76 -2101.96 3545.93 216.35 0.85 G-MAG None 81 7729.19 20.51 220.60 95.86 6543.88 3580.01 -2881.97 -2123.94 3580.07 216.39 0.94 G-MAG None . 82 7822.53 19.88 220.54 93.34 6631.49 3612.16 -2906.45 -2144.89 3612.20 216.43 0.68 G-MAG None 83 7920.98 19.25 220.49 98.45 6724.25 3645.05 -2931. 51 -2166.31 3645.09 216.46 0.64 G-MAG None 84 8013.85 19.04 219.63 92.87 6811.99 3675.46 -2954.82 -2185.91 3675.49 216.49 0.38 G-MAG None 85 8112.93 18.79 218.89 99.08 6905.72 3707.54 -2979.69 -2206.24 3707.57 216.52 0.35 G-MAG None 86 8210.74 18.41 217.98 97.81 6998.42 3738.73 -3004.13 -2225.63 3738.75 216.53 0.49 G-MAG None 87 8291.00 18.41 217.98 80.26 7074.57 3764.07 -3024.11 -2241.23 3764.09 216.54 0.00 Projected to TD [(c)2003 IDEAL ID8 1C_01J . ~~~~E ffi)} ~~~~~~~ ~11"SIiA OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 . FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit S-116 BP Exploration (Alaska), Inc. Pennit No: 203-181 Surface Location: 4271' NSL, 4502' WEL, Sec. 35, TI2N, RI2E, UM Bottomhole Location: 1313' NSL, 1432' WEL, Sec. 34, T12N, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thi~ day of October, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section t'\lcA- I "11-Z{ 2.-003 B Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4271' NSL, 4502' WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 1429' NSL, 1351' WEL, SEC. 34, T12N, R12E, UM Total Depth: 1313' NSL, 1432' WEL, SEC. 34, T12N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-618930 y-5980475 Zone7\SP4 16. Deviated Wells: Kickoff Depth 18. Casing Progn!lm Size Casinç¡ 20" 9-5/8" _ STATE OF ALASKA . ALASKA O~ND GAS CONSERVATION COM~SION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratol1Þ' 0 Development Oil 0 Multiple Zone o Stratigraphic Test B Service r 0 Development Gas 0 Single Zone 5. Bond: ~ Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU 5-116 ",. 6. Proposed Depth: 12. Field I Pool(s): MD 8128' TVD 6980' Prudhoe Bay Field I Aurora Pool 7. Property Designation: ADL 028258 9. Acres in Property: 2560 13. Approximate Spud Date: 12/01/03 14. Distance to Nearest Property: 11750' 8. Land Use Permit: Weiç¡ht 91.5# 40# 26# Lenç¡th 80' 3332' 8128' 10. KB Elevation Plan RKB 15. Distance to Nearest Well Within Pool (Height above GL): = 64.7' feet S-117 is 2100' away at 7841' MD 17. Anticipated pressure (see 20 MC 25.035) /' Max. Downhole Pressure: 3350 psig. Max. Surface Pressure: 2680 psig Settil"lgDepth.< .......... .......... Quantity of Ce i1éht Top/ .... . i/' Bottom (c.f. or .sacks) MD TVD MD TVD (includinç¡ stage data) Surface Surface 110' 110' 260 sx Arctic Set (Approx.) Surface Surface 3332' 2875' 520 sx AS Lite PF, 298 sx Class 'G' ..> Surface Surface 8128' 6980' 254 sx LiteCrete, 123 sx Class 'G' /' Hole 42" 12-1/4" 8-314" 500' ft Maximum Hole Angle Sp~cifiGé!ltion$ Grade Coupling H-40 Weld L-80 BTC L-80 BTC-M 49° 7" 19. PRESENT WELLCQNDITION.SUMMARY (To b~ completed for RedrinAND RErentry Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD Junk (measured): Structural Conductor Surface Intermediate Production liner fl .\ " I L \...' \, " I: I \1 {~'"'\ ......,,,..1 ",p", 9 0 I il, ¡ . '.t. u Ccn!>.. Cßr,.\ riili;¡;;¡ 20. Attachments ~ Filing Fee 0 BOP Sketch ~ Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): ~ Drilling Program 0 Time vs Depth Plot o Seabed Report ~ Drilling Fluid Program o Shallow Hazard Analysis ~20 MC 25.050 Requirements Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Smith, 564-5773 Printed Lowell Crane Title Senior Drilling Engineer J I-G",fU. L Phone 564-4089 Date lól UD 03 See cover letter for other requirements o Yes ~No )5?Yes 0 No Permit To Drill Permit APP~o~' 7 / Number:2ð,3>-/?/ 50- 0.2-7'- 2.3/?'3 Date: /.J(~(<>3 Conditions of Approval: Samples Required 0 Yes )gNo Mud Log Required Hydrogen Sulfide Measures 0 Yes ~No Directional Survey Required Other: T es.t 80PE to ~OO~ (JÇ.t!. ^;,LT, u"lÁeM..-t.!/llll; k1 bj 'f"-RÂu.,t"Y'-"'J. P¿4 z,.o A'At: 'l-~, D~S (h. 1[1..)" dLvevky "'ebu..A."NZ.~,4.(.i: ; ~ wct.iV'eJ, ~:";~~~ Ret;j3 ~ ¡\,fJtr'"srONER ~~~~~~~;rON Date /DI-4-~/~ Submit l~u~licate e ,\t~.I. bp ......~'4 ,.~.....- ~- --:..~ ~...~ -F....~ ·'jj'~~I\" ". e To: Winton Aubert, AOGCC Date: OCt. 15, 2003 From: Jim Smith Subject: Dispensation for 20 AAC 25.035 (c) on 8-116 - permit submitted BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. / To date, none of the 40-plus Ivishak wells at S-pad, nor the recent AuroraIPolaris wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first ten surface holes for the AuroraIPolaris development were drilled no deeper than the shale underlying the SV-I sands; S-116 is planned to TD in the shallower SV-3 shale, as did the most recent wells. The shale underlying the SVl is the deepest planned surface casing setting depth for future pad development wells. This casing point is ±770' TVD above the U gnu horizon. ,/ The shallowest and most recent RFf points recorded in the area are from S-201, recording a pore pressure of 1,423psi at 3,175' TVDss (8.6 ppg EMW) and not exceeding 8.7 ppg EMW above 3700' TVDss. S-116 is planned to reach 9.5 ppg mud weight before TD at 2,875' TVD. Supporting surface hole gas detection information is on file with the AOGCC from the recently drilled S- J:.e5 as requested by AOGCC. ./ ií'S W6A- Your consideration of the waiver is appreciated. ~. n~ere;b . im Smith GPB Rotary Drilling Engineer 564-5773 e e IWell Name: 18-116 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Injector Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: x = 618,930.' Y = 5,980,475' 4271' FSL, 4502' FEL, Sec. 35, T12N, R12E ",,- X = 616,850' Y = 5,977,600' 1429' FSL, 1351' FEL, Sec. 34, T12N, R12E ,,- X = 616,771' Y = 5,977,483' 1313' FSL, 1432' FEL, Sec. 34, T12N, R12E / I AFE Number: 1 AUD5M0067 I I Rig: I Nabors 7ES / I Estimated Start Date: 112/01/2003 I / I Operating days to complete: 113.2 I MD: 18128 I TVD: 16980' I RT/GL: 128.5' I I RKB/MSL: 164.7' I I Well Design (conventional, slim hole, etc.): I Ultra Slimhole (Iongstring) I Objective: 1 Single zone injector into the Kuparuk formation. Mud Program: 12 %" Surface Hole (0-3332'): Densitv (ppg) Initial 8.5 - 9.2 Base PF to top SV 9.0 - 9.5 SV toTD 9.5 max Viscosity (seconds) 250-300 200 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100fe) (mls/30min) 45 - 70 NC 35 - 45 25 n 35 <8 <8 9.0-9.5 9.0- 9.5 9.0- 9.5 8 %" Production Hole (3332' - 8128'): LSND Interval Density YP PV pH API 10'Gel (ppg) Filtrate Upper 9.7 25-30 1 0-15 9.0--9.5 6-8 10 Interval 9.9-~ Top of HRZ 22-28 1 0-15 9.0-9.5 4-6 10 to TD I ., VJó¡\- S-116 Drilling Program-Draft Page 1 e e Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1985' 550 4" 14.0# 90 1800 10.0 N/A 18,18,18,16 .942 1985' -3332' 650 4" 14.0# 110 2400 10.2 N/A 18,18,18,16 .942 Production Hole: 8 3,4" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 3332' - 8128' 600 4" 14.0# 240 3400 10.8 N/A 3x14,3x15 .969 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Pipe GPM Rotation Mud Weight Hole Cleaning Condition 110'-3332' Surface to SV-3 9.5 Superior hole cleaning practices at connections will greatly enhance cuttings transport in the sliding mode Sweeps and fully reamed connections to maintain minimum hole cleaning requirements 3332'-8128' 9-5/8" to TD Casing Criteria: Casing Description Burst Rating (psi) Collapse Rating (psi) 20" insulated conductor 9-5/8" , 40#, L-80, BTC 7", 26#, L-80, BTCM 5750 7240 3090 5410 S-116 Drilling Program-Draft Page 2 Di rectional: Ver. I Anadri!l P9 KOP: 500' Maximum Hole Angle: Close Approach Wells: None e e 49.4 deg at 2635' MD All wells pass major risk criteria. The nearest wells are: 8-112 at 495'MD on S-116, 58' centerto center 8-200 at 599'MD on S-116, 31' center to center /. 8-216 at 1001 'MD on 8-116, 35' center to center 8-44 at 698'MD on 8-116, 28' center to center IFR-M8 corrected surveys will be used for survey validation. Logging Program: Surface Intermediate/Production Hole Formation Tops KOP SV6 Base Permafrost SV5 SV4 SV3 9-5/8" sfc casing SV2 SV1 UG4A UG3 UG1 Ugnu Ma Top Schrader NA Schrader OA Base OBf CM1(Colville) THRZ BHRZ (Kalubik) Target TKUP Kuparuk C2 LCU (Kuparuk B) Kuparuk A5 TMLV (Miluveach) TD/7" casing Criteria Formation Markers: MD 500 1597 1985 2304 2574 3179 3332 3416 3862 4325 4652 5272 5576 5816 5925 6269 7411 7721 7832 7841 7841 7864 7895 7941 7979 8128 8-116 Drilling Program-Draft Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: TVDss 435 1510 1860 2120 2315 2710 2810 2865 3200 3600 3885 4425 4690 4900 4995 5295 6290 6560 6657 6665 6665 6685 6712 6752 6785 6980 / MWD / GR None None MWD/RE8/GR PEXlc, MDT US IT Estimated pore pressure, PPG KOP in Permafrost cr.'; 9-5/8" casing ÐIL 8.6 ppg EMW ~.. \¡.l4k Hydrocarbon bearing, possible . pg EMW Hydrocarbon bearing, 9.0 ppg EM Hydrocarbon bearing, 9.2 ppg EMW Hydrocarbon bearing, 8.8ppg EMW Hydrocarbon bearing, 8.8 ppg EMW ~.1 Hydrocarbon Bearing, 9.5 ppg EMW Hydrocarbon Bearing, 9.5 ppg EMW Hydrocarbon Bearing, 9.5 ppg EMW 150' MD below Miluveach top Page 3 e e CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top . Btm Size Tbg a.D. / /' MDnvD MDITVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110'/110' 12 %" 9 5/8" 40# L-80 BTC 3332' GL 3332'/2875' 8%" 7" 26# L-80 BTC-M 8128' GL 8128'/6980' Tubing 4 %" 12.6# L-80 TC-II 7678' GL 7691 '/6598' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW 11.6 ppg EMW Target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casing Size 19-5/8" Surface I Basis: Lead: Based on conductor set at 110', 1875' of annulus in the permafrost @ 225% excess and 582' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 764' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2568' MD,2310'TVD /1 I Total Cement Volume: Lead 411 bbl/ 2308fe 1~~plskS~.. rctic Set Lite permafro...s..t cement at 10. 7 rp~d 4~~f/sk. ._ Tail 61.5 bbl I 345 ft I &SkS of 'G' at 15.8 ppg and Y.16 dIsk. C::::= Casing Size 17" Production Longstring I Basis: Stage 1: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: Tail from shoe to 7341' MD, lead from 7341' to 3825 , - 500' above UG4A sand Total Cement Volume: Lead Tail /",. 1 03 b s' 580 ft~ I ~~~sks of Litecrete slurry at 12.0 ppg and .2 dIsk. ..r) 26 b ' 1'147 ft~ I.A2;Ysks of gasBLOK 'G' at 15.8 ppg and .4kf/sk. t./ j 8-116 Drilling Program-Draft Page 4 e e Well Control: .,/ Surface hole will be drilled without diverter pending AQGCC approval. The production hole well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for future fracture stimulation treatment, the BOP equipment will be tested to 4000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: . Maximum surface pressure: 3350 psi @ 6700' TVDss - Kuparuk A5 Sands 2680 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 4000 psi (The casing and tubing will be tested to 4000 psi as r' required for fracture stimulation.) · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. 5-116 Drilling Program-Draft Page 5 e e DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed in Oct. 2003. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: / 1. MIRU Nabors 7ES. 2. Nipple up spool (diverter waiver has been submitted). PU 4" DP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWD/GR to kick off at 500' and directionally drill surface hole to approximately 100' TVD below the SV3 Sands. An intermediate wiper/bit trip to surface will be performed prior to exiting the Permafrost. 4. Run and cement the 9-5/8", 40# surface casing. Cement to surface. / /' 5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. . 6. MU 8-3/4" drilling assembly with MWD/RES/GR and RIH to float collar. Test the 9-5/8" casing to 3500 (' psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.7 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. / O. I \Ñ~ 8. Drill to +/-100' above the HRZ, ensure mud is condition for 1Q:e""ppg and perform short trip as needed. / Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 9. Drill ahead to TD at -150' MD below Top Miluveach. 10. Condition hole for PEX/Sonic and MDT (pressure sample) e-Iogging. 11. Run PEX/Sonic, if hole remains in good condition follow immediately with MDT (possibly on DP due to _ sticking risks). Take pressure only sets (20-25 sets). 12. Perform wiper trip and condition hole for running 7" 26# long-string casing. 13. POOH and lay down drillpipe. 14. Run and cement the 7" production casing in a single stage. (To be reviewed )Jased on log/operational results.) Displace the cement with 8.5 ppg filtered seawater if single stage. 15. Freeze protect the 7" x 9-5/8" annulus as required with diesel. Record formation breakdown pressure on the Morning Report. 16. Test casing to 4000 psi for 30 minutes. 17. Run the 4-1/2", 12.6#, L-80 TC-II completion assembly. Set packer and test the tubing to 4000 psi / and annulus to 4000 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below TWC to 1000 psi. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 19. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. / 20. Rig down and move off. USIT logging will be performed post-rig as will perforating. / S-116 Drilling Program-Draft Page 6 e e 5-116 Drilling Program Job 1: MIRU Hazards and Contingencies / ~ S-Pad is not designated as an H2S site. Recent well tests indicate near 8ppm H2S concentrations as typical but S-40 had 70 ppm on 1/00. Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest well location is S-44, 30' to the south. S-200 is 30' to the north and a new conductor is placed 15' north of the S-116. The S-44 well has been shut in for 12 months and S-200 has been shut in for 6 months, both will remain shut in for some time yet. No wells will require a surface shut in during move in. ~ Check the landing ring height on S-116 prior to rig mobilization. The BOP nipple up may need review for proper space out prior to spud. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" _/M_ Job 2: Drillinq Surface Hole ~ There are four nearby well in the surface hole. Those are S-44, S-200, S-112 and S-216. Refer to page 4 for details. ~ An electronic gyro survey is required per the directional plan to 1000' MD or until the magnetic interference at the surface has dissipated. ~ Gas hydrates have been observed in wells drilled on S-Pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation ~ S-116 is not expected to cross any faults in the surface hole. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations Job 3: Install Surface Casinq Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 225% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at ±1 OOO'MD to allow remedial cementing should that be necessary. Reference RPs .:. "Casing and Liner Running Procedure" S-116 Drilling Program-Draft Page 7 e e .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" Job 7: Drillinq Production Hole Hazards and Contingencies ~ S-116 will cross one two faults - in the SV1/Ugnu - 3400'TVDss, 4095' MD (+/- 250') and in the . Colville -6350'TVDss, 7480' MD (+/-100'). Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. );> KICK TOLERANCE: In the scenario of 9:5 ppg pore pressure at the Kuparuk target depth,gauge hole, a fracture gradient of 11.8 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 26 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 11.8 ppg. )0> Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1-10.3 were required to contain the pressure. Several S-Pad wells drilled in 2000 used 10.5 ppg to drill this interval as a precaution. Since that time nineteen wells have been drilled on S Pad without encountering the overpressure. Gas cut mud, mud flow and oil in the returns may indicate that the overpressure is still present at which point the mud should be weighted up. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HRZ" Job 8: Loq Production Hole Hazards and Contingencies ~ Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. The MDT pressure sampling run is currently planned on electric line only if the hole is in excellent condition, otherwise it will be DP conveyed due to sticking risks. The first log run will be PEX with sonic. ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7"longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The interval is planned to be cemented in a single stage with a 12.0 ppg lead ( to 500'MD above the UGNU 4Aa) and a 15.8 ppg tail (top at 500' above the Kuparuk). If a single stage cement job is deemed too risky while drilling, then a 2 stage cement job may be performed. S-116 Drilling Program-Draft Page 8 e e ~ Ensure the upper production cement has re'ached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with dead crude to 2324' MD, 2200'TVD), the hydrostatic pressure will be 7.6 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 139 psi underbalance to the open hole. ~ Cement is being placed from TD to 500' above the UGNU 4A (top at 4325'MD/3565'TVD). Planned TOC is 3825'MD which is less than 500' below the 9-5/8" casing shoe. It may be prudent to insure the 9-5/8" x 7" annulus is clear if there is a delay in cement reaching adequate thickening/compressive strength development. );> Ensure a minimum hydrostatic equivalent of 10.0 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. );> Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 12: Run Completion Hazards and Contingencies );> Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be underbalanced if there is a casing integrity problem. );> When testing annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus pressure to avoid premature shear of the DCK valve. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus S-116 Drilling Program-Draft Page 9 e e Job 13: ND/NUlRelease Riq Hazards and Contingencies y No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus OperaüonalSpecifics · ND stack. NU tree and test to 250 and 5000 psi with diesel. Test packoff to 5000 psi. Pull TWC. · R/U hot oil truck and freeze protect well by reverse circulating diesel to the lowermost 4-1/2" GLM. Allow diesel to U-tube from annulus to tubing and equalize. Refer to RP: Freeze Protection of Inner Annulus. · Install SPV & test to 1000 psi from below. . Rig down and release the rig. 8-116 Drilling Program-Draft Page 10 e e S-116 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates may be encountered near the base of the Permafrost at 1985'MD and near the TD hole section as well. · S-30 and S-25 located on the Southern portion of the pad, reported outer annulus pressures in the past. In December 2002 S-25 was shut in. S-30 is on production however and is being monitored. The pressure does not appear to have charged up any shallow sands in the wells drilled since that time. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: · The production section will be drilled with a recommended mud weight of 10.0 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.5 pore pressure. · Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1-10.3 were required to contain the pressure. Several S-Pad wells drilled in 2000 used 10.5 ppg to drill this interval as a precaution. Since that time nineteen wells have been drilled on S Pad without encountering the overpressure. Gas cut mud, mud flow and oil in the returns may indicate that the overpressure is still present at which point the mud should be weighted up. · S-116 will cross a fault at · -3400' TVDss, 4095' MD (+/-250') in the SV1/Ugnu and another in the Colvile -6350' TVDss, 7480' MD. Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S · This drill-site is not designated as an H2S drill site. Recent wells tests indicate 7 ppm H2S concentration in Kuparuk wells. Standard OperatinQ../ Procedures for H2S precautions should be followed at all times. CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION S-116 Drilling Program-Draft Page 11 TREE'" 4-1/16" CrN WELLHEAD = FMC ACTUA TOR = NA KB. ELEV = 64.7 BF. ELEV = 36.2 .m~~ ." .. m KOP = 500 . -------------.-----.... Max Angle = 49.4@2635 " Datunï""MO";;;;- ..... ' . om·"@"l DatumTVD= XXX'SS e 9-5/8" CSG, 40#, L-80, ID = 8.835" H 3332' ~ Minimum IC = 3.750" 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12.6#. L-80, TC-II ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLE AT TOP ÆRF: xx @ xxxx' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE I PBTD H 17" CSG, 26#, L-80, .0383 bpf. ID = 6.276" H 8043' 8128' DATE 09/30109 REV BY COMMENTS JES PROPOSED COMPLETION DATE 5-116 - =1 ST MD 1 2 ---1: z .~ \ . ~ REV BY COMMENTS / e 1000' 2200' contingent 9-5/8" TAM I PORT COLLAR 4-1/2" HES X NIP, ID = 3.813" I GAS LIFT MANDRELS TVD DEV TYÆ VLV LATCH PORT 3800 7400 DATE 7779' H 7" x 4-1/2" BKR SB3 PKR 4-112" X nipple 4-1/2" XN nipple Short Joints 1jt above top KUP and 1 at base A5 GPB BOREALIS WELL: S-116 ÆRMrT No: API No: BP Exploration (Alaska) S-116 (P9) Proposal Schlumberger Report Date: October 8, 2003 SUlvey / DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 216.720' Field: Prudhoe Bay Unit· WOA dy Vertical Section Origin: N 0.000 ft, E 0,000 ft Structure / Slot: S-PAD/S-1169·18·3 IIIllIty stu TVD Reference Datum: KB Well: Plan S-116 f aslbl I TVD Reference Elevation: 64.7 ft relative to MSL Borehole: S-116 . e UWIIAPI#: 50029 Magnetic Declination: 25,322' Survey Name / Date: S-116 (P9) 1 October 8, 2003 Total Field Strength: 57564.012 nT Tort / AHD / DDI/ ERD ratio: 77.567' 13753.54 ft 15,5311 0.53E Magnetic Dip: 80.854' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: November 21, 2003 Location LatlLong: N 70.35530913, W 149,03416469 Magnetic Declination Model: B88M 2003 Location Grid N/E YfX: N 5980475,000 ftUS, E 618930,000 ftUS North Reference: True North e Grid Convergence Angle: +D.90962912' Total Corr Mag North·) True North: +25,322' Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head I Comments Measured I Inclination I Azimuth I TVD I Sub·Sea TVD I Vertical I NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Easting Latitude I Longitude Depth Section (ft) (deg) (deg ) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (deg/100 ft) (deg1100 ft) (deg) (ftUS) (ftUS) KBE 0.00 0.00 280.00 0.00 -64.70 0.00 0.00 0.00 0.00 0.00 0.00 -80.00M 5980475.00 618930.00 N 70.35530913 W 149.03416469 KOP Bid 1/100 500.00 0.00 280.00 500.00 435.30 0,00 0.00 0.00 0.00 0.00 0.00 -80.00M 5980475.00 618930.00 N 70.35530913 W 149.03416469 Bid 2.5/100 600.00 1.50 280.00 599.99 535.29 0.59 0.23 -1.29 1.50 1.50 0.00 -80.00M 5980475.21 618928.71 N 70.35530975 W 149.03417516 700.00 3.50 280.00 699.89 635.19 2.55 0.98 -5.58 2.00 2.00 0.00 -80.00M 5980475.90 618924.40 N 70.35531182 W 149.03421004 800,00 5.50 280,00 799.57 734.87 6.08 2.35 -13.31 2,00 2.00 0.00 O.OOG 5980477.14 618916.65 N 70.35531554 W 149.03427278 900.00 7.50 280.00 898.93 834,23 11.17 4.31 -24.46 2.00 2.00 0.00 O.OOG 5980478.92 618905.48 N 70.35532091 W 149.03436330 1000,00 9.50 280.00 997.82 933.12 17.81 6.88 -39.01 2.00 2.00 0.00 O.OOG 5980481.26 618890.88 N 70.35532792 W 149.03448149 Cry 3/100 1100.00 11,50 280.00 1096.14 1031.44 26.01 10.04 -56.96 2.00 2.00 0.00 -78.50G 5980484.14 618872.89 N 70.35533657 W 149.03462720 1200.00 12.45 266.23 1193.99 1129.29 37.49 11.07 -77.53 ~,OO 0.95 -13.77 -65.03G 5980484.83 618852.31 N 70.35533936 W 149.03479426 1300.00 13.97 254.90 1291.36 1226.66 53.98 7.21 -99.95 3.00 1.53 -11.33 -54.00G 5980480.62 618829.96 N 70,35532883 W 149.03497627 1400.00 15.92 246.02 1387.98 1323,28 75.43 -1.51 -124.14 3.00 1,95 -8.88 -45.42G 5980471.52 618805.91 N 70.35530501 W 149.03517273 1500.00 18.15 239.15 1483.60 1418.90 101,80 -15,07 -150.05 3.00 2.23 -6.87 -38.84G 5980457.55 618780.22 N 70.35526795 W 149.03'" ~10 SV6 1596.54 20.48 233.95 1574.70 1510.00 131.83 -32,72 -176.62 3.00 2.42 -5.38 -33.94G 5980439.48 618753,93 N 70.35521973 W 149.0.34 1600.00 20.57 233.79 1577.94 1513.24 132.99 -33.44 -177.60 3.00 2.49 -4.77 -33.78G 5980438.75 618752.97 N 70.35521777 W 149.0. 81 1700.00 23,12 229.54 1670.76 1606.06 168.94 -56.56 -206.72 3.00 2.55 -4.25 -29.84G 5980415.17 618724.22 N 70.35515460 W 149.03 4323 1800,00 25.76 226.10 1761,80 1697.10 209.53 -84.38 -237.33 3.00 2.64 -3.43 -26.71G 5980386.87 618694.06 N 70.35507861 W 149.03609173 1900.00 28.4 7 223.28 1850,80 1786.10 254.67 -116.81 -269.33 3.00 2.71 -2.83 -24.19G 5980353.94 618662.58 N 70.35499001 W 149.03635162 Base Perm 1985,04 30,82 221.23 1924.70 1860.00 296.52 -147.95 -297.59 3.00 2.76 -2.40 -22.42G 5980322.36 618634.82 N 70.35490492 W 149.03658105 2000.00 31.23 220,90 1937.52 1872,82 304.21 -153.77 -302.66 3,00 2.78 -2.21 -22.14G 5980316.46 618629.85 N 70.35488904 W 149.03662219 2100.00 34.03 218.89 2021,74 1957,04 358.04 -195.15 -337.21 3.00 2.80 -2.02 -20.43G 5980274.54 618595.96 N 70.35477598 W 149.03690270 2200,00 36.85 217.14 2103.20 2038.50 416.00 -240.84 -372.88 3.00 2.82 -1.75 -19.01G 5980228.29 618561.02 N 70.35465114 W 149.03719237 2300.00 39.70 215.61 2181.70 2117.00 477.93 -290.72 -409.59 3.00 2.85 -1.53 -17.81G 5980177.84 618525.11 N 70.35451487 W 149.03749041 SV5 2303.90 39.81 215.55 2184.70 2120.00 480.43 -292.75 -411.04 3.00 2.86 -1.43 -17.77G 5980175.78 618523.69 N 70.35450932 W 149.03750220 2400,00 42.56 214.25 2257.02 2192.32 543.67 -344.66 -447.23 3.00 2.86 -1.35 -16.79G 5980123.32 618488.33 N 70.35436753 W 149.03779601 2500.00 45.44 213.04 2328.94 2264,24 613.02 -402.49 -485.70 3.00 2.88 -1.22 -15.91G 5980064.89 618450.79 N 70.35420952 W 149.03810833 Version DO 3.1 RT ( d031 rt_546 ) 3.1 RT-8P3.03 8-116 9-18-3\Plan 8-116\8-116\8-116 (P9) Generated 10/8/20033:46 PM Page 1 of 2 I Comments Measured I Inclination I Azimuth I TVD I Sub·Sea TVD I Vertical I NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Eastlng Latitude Longitude Depth Section (It) (deg) (deg ) (It) (It) (It) (It) (It) (deg/100 It) (deg/100 It) (deg/100 It) (deg ) (ltUS) (ltUS) SV4 2573.75 47.57 212.22 2379.70 2315.00 666,39 -447.55 -514.54 3,00 2.89 -1.11 -15.35G 5980019.38 618422.67 N 70.35408642 W 149.03834246 2600.00 48.33 211,94 2397.28 2332.58 685.81 -464.07 -524,89 3.00 2.89 -1.06 -15.16G 5980002.70 618412.59 N 70.35404129 W 149.03842650 End Cry 2635.09 49.35 211,57 2420,37 2355.67 712.13 -486.53 -538.79 3.00 2.90 -1.03 O.OOG 5979980.02 618399.05 N 70.35397993 W 149.03853936 SV3 3178.99 49.35 211,57 2774.70 2710.00 1123.12 -838.09 -754.86 0.00 0.00 0,00 O.OOG 5979625.11 618188.60 N 70.35301945 W 149,04029340 Fault Target 3278.76 49.35 211,57 2839,70 2775.00 1198.51 -902.58 -794.50 0.00 0,00 0.00 O.OOG 5979560.00 618150.00 N 70.35284325 W 149.04061516 9-5/8" Gsg PI 3332.49 49.35 211.57 2874.70 2810.00 1239.11 -937.31 -815.84 0.00 0.00 0.00 O,OOG 5979524.94 618129.21 N 70.35274837 W 149,04078840 Cry 3/100 3363.19 49.35 211.57 2894.70 2830.00 1262.31 -957.15 -828.03 0.00 0.00 0.00 175.23G 5979504.91 618117.33 N 70.35269416 W 149.04088740 3400.00 48.25 211.70 2918.95 2854.25 1289.89 -980.73 -842.56 3.00 -2.99 0.33 175.15G 5979481.10 618103.19 N 70.35262974 W 149.04100532 SV2 3416.07 47.77 211.75 2929.70 2865.00 1301.79 -990.89 -848.84 3.00 -2.99 0.34 175.11G 5979470.84 618097.07 N 70.35260198 W 149,04105631 3500.00 45.26 212.05 2987.45 2922.75 1362.46 -1042.58 -881,02 3.00 -2.99 0.36 174.90G 5979418.65 618065.72 N 70.35246075 W 149.04131749 3600.00 42.27 212.45 3059.66 2994.96 1431.42 -1101.08 -917.92 3.00 -2.99 0.40 174.62G 5979359.59 618029.75 N 70.35230094 W 149.0411"705 3700.00 39.29 212,90 3135.38 3070,68 1496.56 -1156.05 -953.17 3.00 -2.99 0.44 174.28G 5979304.06 617995.38 N 70.35215073 W 149.~ 17 3800.00 36.30 213.40 3214.39 3149.69 1557,72 -1207.36 -986.67 3.00 -2.98 0.50 173.88G 5979252.23 617962.71 N 70.35201055 W 149. . '07 SV1 3861.71 34.46 213.75 3264.70 3200.00 1593.39 -1237.13 -1006.42 3.00 -2.98 0.56 173.60G 5979222.16 617943.43 N 70.35192922 W 149,0 43 3900.00 33.32 213.98 3296.49 3231.79 1614.72 -1254.86 -1018.32 3,00 -2.98 0.61 173.40G 5979204.24 617931.81 N 70.35188078 W 149.04243200 4000.00 30.34 214.66 3381.44 3316.74 1667.40 -1298.42 -1048.05 3.00 -2.98 0.68 172.82G 5979160.22 617902.79 N 70.35176176 W 149.04267326 End Cry 4033.67 29,34 214.92 3410.65 3345.95 1684.15 -1312.18 -1057.61 3.00 -2.98 0.76 O.OOG 5979146.31 617893.45 N 70.35172417 W 149.04275086 UG4 4302.17 29,34 214.92 3644.70 3580.00 1815.64 -1420.05 -1132.92 0.00 0,00 0.00 O.OOG 5979037.27 617819.87 N 70.35142945 W 149.04336214 UG4A 4325.11 29.34 214.92 3664.70 3600.00 1826.88 -1429.27 -1139,35 0.00 0.00 0.00 O.OOG 5979027.95 617813.58 N 70.35140426 W 149.04341437 UG3 4652.05 29,34 214.92 3949.70 3885.00 1987.00 -1560.62 -1231.06 0.00 0.00 0.00 O.OOG 5978895.17 617723.98 N 70.35104538 W 149.04415867 UG1 5271.51 29.34 214.92 4489.70 4425,00 2290.37 -1809.49 -1404.81 0.00 0.00 0.00 O.OOG 5978643.59 617554.21 N 70.35036540 W 149.04556886 Ma 5575.50 29,34 214.92 4754.70 4690.00 2439.25 -1931.63 -1490.08 0.00 0.00 0,00 O.OOG 5978520.13 617470.90 N 70.35003170 W 149.04626086 Na 5816.40 29.34 214.92 4964.70 4900,00 2557.23 -2028.41 -1557,65 0.00 0.00 0.00 O.OOG 5978422.29 617404,88 N 70.34976725 W 149.04680923 OA 5925.38 29.34 214.92 5059.70 4995.00 2610.60 -2072.19 -1588.21 0.00 0.00 0.00 O.OOG 5978378.03 617375.02 N 70.34964762 W 149.04705729 OBd 6114.66 29,34 214,92 5224.70 5160.00 2703.30 -2148.24 -1641,31 0.00 0.00 0,00 O,OOG 5978301.16 617323.14 N 70.34943984 W 149.04748813 Base OBf 6269.52 29.34 214.92 5359.70 5295.00 2779.15 -2210.46 -1684,74 0.00 0,00 0.00 O.OOG 5978238.27 617280.70 N 70.34926984 W 149.04784063 GM1 7410,93 29.34 214.92 6354.70 6290.00 3338. 15 -2669.03 -2004,90 0.00 0,00 0.00 O.OOG 5977774.71 616967.89 N 70.34801684 W 149.05043851 Top HRZ 7720.66 29.34 214.92 6624.70 6560,00 3489.84 -2793.47 -2091.78 0,00 0.00 0.00 O.OOG 5977648.92 616883.01 N 70.34767683 W 149.05114341 Kalubik 7831.93 29.34 214,92 6721.70 6657.00 3544.33 -2838.17 -2122.99 0.00 0,00 0.00 O.OOG 5977603.73 616852.51 N 70.34755467 W 149.05139664 5-116 Tgt 7841,11 29,34 214.92 6729.70 6665.00 3548,83 -2841.86 -2125.56 0.00 0.00 0.00 O.OOG 5977600.00 616850.00 N 70.34754460 W 149.05141753 Top Kup 1 G4 7841.12 29,34 214.92 6729.71 6665,01 3548.83 -2841.87 -2125.57 0.00 0.00 0.00 O.OOG 5977600.00 616850.00 N 70.34754459 W 149..55 Kup G2B 7864,05 29.34 214.92 6749.70 6685,00 3560.06 -2851,08 -2132.00 0.00 0.00 0.00 O.OOG 5977590,68 616843.71 N 70.34751941 W 149. 74 Kup G1G 7881.26 29.34 214.92 6764,70 6700.00 3568.49 -2857.99 -2136.82 0.00 0.00 0.00 O.OOG 5977583.69 616839.00 N 70.34750052 W 149.05150890 LGUIKupB 7895.03 29.34 214.92 6776.70 6712.00 3575.23 -2863,52 -2140.69 0.00 0.00 0.00 O.OOG 5977578.10 616835.22 N 70.34748541 W 149.05154023 Kup A5 7940.91 29.34 214.92 6816.70 6752.00 3597.70 -2881.96 . -2153.56 0.00 0.00 0.00 O.OOG 5977559.47 616822.65 N 70.34743504 W 149.05164465 TMLV 7978.77 29.34 214.92 6849,70 6785.00 3616.24 -2897.17 -2164.17 0.00 0.00 0.00 O.OOG 5977544.09 616812.27 N 70.34739348 W 149.05173080 TD 1 7" Csg pt 8128.77 29,34 214.92 6980.46 6915.76 3689.71 -2957.43 -2206.25 0,00 0.00 0.00 O.OOG 5977483.17 616771.17 N 70.34722881 W 149.05207216 LeQal Description: NorthlnQ (y) [ftUS] EastinQ (X) mUS] 5urface : 4271 F5L 4502 FEL 535 T12N R12E UM 5980475.00 618930.00 Fault Target: 3369 F5L 17 FEL 534 T12N R12E UM 5979560.00 618150.00 5-116 Tgt: 1429 F5L 1351 FEL 534 T12N R12E UM 5977600.00 616850.00 BHL: 1313 F5L 1432 FEL 534 T12N R12E UM 5977483.17 616771.17 Version DO 3,1RT (do31r,-546) 3.1RT-5P3.03 5-116 9-18-3\Plan 5-116\5-116\5-116 (P9) Generated 1018/20033:46 PM Page 2 of 2 well MagneticPëllëlfTl8t8rs Model: 8GGM 2003 5-116 (P9) £ 0- o o ~ ê = ~ II Q) m () en o ¡:: e e Schlumberger FIELD Prudhoe Bay Unit - WOA STRUCTURE 5.PAD Dip" 80.854' MagDec.: +25.322" Surface Location Date: November 21, 2003 lat N702119.113 FS' 51564.0nT Lon: W14922.993 ................ Slot: $.1169-18-3 Plan: S-116(P9 TVD Ref: KB (64.70 ft above MSL) SntyDate: 0d0ber08,2003 NAD27 Alaska State PIanes,Zone 04, us Feat NoI1hing: 5980475.00ftUS GridConv: +0.90962912' Easting: 618930.00 ftUS Scale Fact 0.9999160676 o 1000 2000 3000 4000 o . . . . ..-~.- -=~;~~1··--·····--··-1 -----1 1000 Cry 31100 ; ...........~......................¡...............,.......... · . · . · . · . · . ........................ 2000 · . . . -..-.. - 'l""1i:V6' - ..-..- . - "-"-" -,. -..-.. -,. -..-.. -.. - ..-..- .,-..-.. - . - ..-.. -., -. .-..-.. r" -..-..-., - ..-.. -,. -. .-.. - r - ..-..-.. - ..-..-..- ~..:.~.::~::. :-:....~,::~.:',~::.~>:::.: ~~;:p.¡rm::. ~::·:·::~r ~..:.:.:: ~..:.~::.:.::::.. ~::.~.::::~~:. ··~:·:~·::~·':·~::·:·::~::·~::::·::t::·~::·~·::~::,~"~..~>:::.:..~::.~:.::.~: ~.':.-::.:7.::~:.~-:.·.:-:.::~. EtmCrv ~ ~ ~ -"-"-' --,.-..-. 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';' -..-.. -.. - ..-.. -.. - ..-.. -. ~-..-.. -.. -, .-...... 'Bir" ~.. -..-...... -..-..-.. -..-.. "1' -..-..-.. - ..-......- - ..-..-..-. .-.. -T' -. .-..-.. -.. -..-.. -.. -"T -.. -..----..-.. -..-.. - "-r' _. '''''-''-' .-..-.. .. šé '~èr-"-"- ..-..-..-.. -.. -r-" -.. -......-.. - .... -..-......-........ 5000 6000 . _.. _H_··...·· _.._.. _,. _.._._.. .........._....................v.............v......... ....-........."........... ..."................................. ..,.......................................,..............vn,' .....-...... .-..-".... ..,,~.... ....-..-.......-..-.... -..-..-......-..- '-"éM1 7000 5-1ra Tgt -..-.. - -. _H_'._.. ,...---.. - ..-..-..-. .-..-..- . -:. _u_.. -. ,- H_"_.. - .._" _. :-" -.. - ... "fôp-HFri ._'^_.. -.. _ .._.._~. _.. _.. _.. _ .._.._.._ ~;;~~!~~¡~:;~jj~.:~f.::.~.1!~.!~.~::~.1.1~.:!~.~.:~11~.!.~.~.~.~:.1~,jj~.¡.1.~.::~.1~~.:~.~1;.~.11~~!~1:~:j~~~~~~~~1~~¡~.~~:.:~..;>~:~11~1~~~~~~~ o 1000 2000 3000 4000 Vertical Section (ft) Azim = 216.72°, Scale = 1(in):1000(ft) Origin = 0 Nt-S. 0 EI-W o 1000 2000 3000 4000 5000 6000 7000 e WEll 5-116 (P9) FIELD Prudhoe Bay Unit - WOA MagneticParameters Model' BGGM2003 _",,,,,,,I 575604.0nT Surface Location Lat N702119.113 lon" W149 2 2.993 NAD27 Alaska state Planes, Zone 04, US Feet Northing" 596005.00 ftUS Grid Coov; +0.90962912' Easting 618930.00 ftUS Scale Fact: 0.9999100676 Dip: 80.854' Mag Dee: +25.322' "..., FS: -2000 -1600 o . . ---I--~-T--- ¡ J ¡ ¡ P4:~ 1 ......_--_...,-~~ ............................... -400 -800 -1200 -800 ,............................*............,........ ,...,....................,.......................... , , ... ,............ ,. ..,'.',.. "'~""""'" .... .., ,...... ......,. ,.. "" · . · . ^ ^ ^ z 4? o o ~ ê = ~ -1200 II Q) (ij o en en v v v -1600 -2000 ~FaultTarget ~9-518"CS9 PI : Cry 31100 e Schlumberger STRUClURE 5-PAD """"""'" Slot 5-1169-16-3 Plan: 8-116(P9J TVD Ref; KB (64.70 ft above MSl) SrvyDale:October06.2003 -400 o Cry 31100 o · . .....................................,................. · . · . · . · . · . · . · . · . · . -400 , . ... ........ ,....~.......,. ............. ... ......." ..-:. ........ .., o. · . -800 . . . ...................................."............,..,.......,......,..........,..·.....'..a'..'.."...." . . . -1200 -1600 · . . ,...,·..,,"",..................."'n....~.................,,',.....................',............. · . . ......................,............. -2000 · . . . w -rW-.WT- -2400 ···..·H'...·····...... ...........,............ -2800 ,......................... 5-116 Tgt ~ : ~ ¡ S-116(P9) Ti /7" Csg PI -2000 -1600 -1200 -800 <<< W Scale = 1(in):400(ft) E »> ...................... ...".................... .........j.... ..................... ........................ -2400 ......................... -2800 -400 o e BPX AK Anticollision Report e Company: Field: Reference Site: Reference Well: Reference Wellpath: BPAmoco Prudhoe Bay PB S Pad Plan S-116 Plan S-116 Date: 10/8/2003 TilDe:. 16:01:57 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan S-116, True North S-116 plan 64.7 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 8128.77 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Suñace: Db: SyÞase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 8/29/2003 Validated: No Planned From To Survey ft ft 28.50 8128.77 Planned: Plan #9 V1 Version: 3 Toolcode Tool Name MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 3332.49 2874.70 9.625 12.250 95/8" 8128.77 6980.46 7.000 8.750 7" Summary < Offset Wellpa.th > Reference Offset Ctr-Ctr . No-Go Allowable Site Well Well path MD MD Distance Area Deviation Warning/ ft ft ft ft ft PB S Pad S-01A S-01A V1 2396.54 2250.00 536.53 47.39 489.14 Pass: Major Risk PB S Pad S-01B S-01 B V1 2393.40 2250.00 536.58 47.32 489.26 Pass: Major Risk PB S Pad S-01 S-01 V1 2436.68 2300.00 497.41 58.69 438.72 Pass: Major Risk PB S Pad S-02APB1 S-02APB1 V1 2254.03 2150.00 614.17 39.07 575.10 Pass: Major Risk PB S Pad S-02A S-02A V1 2254.03 2150.00 614.17 39.07 575.10 Pass: Major Risk PB S Pad S-02 S-02 V1 2252.95 2150.00 614.16 39.05 575.11 Pass: Major Risk PB S Pad S-03 S-03 V1 2331.84 2350.00 596.71 37.82 558.90 Pass: Major Risk PB S Pad S-04 S-04 V1 626.19 650.00 694.00 11.00 682.99 Pass: Major Risk PB S Pad S-05APB 1 S-05APB 1 V1 540.97 550.00 755.34 12.23 743.10 Pass: Major Risk PB S Pad S-05A S-OSA V1 540.97 550.00 755.34 12.23 743.10 Pass: Major Risk PB S Pad S-05 S-05 V1 535.37 550.00 755.29 12.16 743.14 Pass: Major Risk PB S Pad S-06 S-06 V1 540.11 550.00 823.42 9.93 813.49 Pass: Major Risk PB S Pad S-07A S-07A V1 622.31 650.00 896.82 11.13 885.68 Pass: Major Risk PB S Pad S-07 S-07 V1 622.31 650.00 896.82 11.13 885.68 Pass: Major Risk PB S Pad S-08 S-08 V1 538.51 550.00 982.14 13.10 969.04 Pass: Major Risk PB S Pad S-08 S-08A V1 538.51 550.00 982.15 13.11 969.03 Pass: Major Risk PB S Pad S-08 S-08B V3 538.51 550.00 982.15 13.11 969.03 Pass: Major Risk PB S Pad S-09 S-09 V1 8092,85 8300.00 1495.01 451.60 1043.41 Pass: Major Risk PB S Pad S-100 S-100 V10 350.04 350.00 166.76 5.85 160.91 Pass: Major Risk PB S Pad S-101 S-101 V2 1249.59 1250.00 111.28 22.24 89.04 Pass: Major Risk PB S Pad S-101 S-101PB1 V9 1248.70 1250.00 110.99 22.07 88.92 Pass: Major Risk PB S Pad S-102 Plan#4 S-102A V1 Plan: 250.49 250.00 181.92 4.64 177.27 Pass: Major Risk PB S Pad S-102 S-102V11 250.49 250.00 181.92 4.64 177.27 Pass: Major Risk PB S Pad S-102 S-102PB1 V14 250.49 250.00 181.92 4.64 177.27 Pass: Major Risk PB S Pad S-103 S-103 V6 853.73 850.00 303.50 12.92 290.58 Pass: Major Risk PB S Pad S-104 S-104 VO 350.20 350.00 375.78 6.58 369.21 Pass: Major Risk PB S Pad S-105 S-105 V5 1100.00 1100.00 365.65 16.81 348.84 Pass: Major Risk PB S Pad S-106 S-106 V2 294.49 300.00 331.90 6.31 325.59 Pass: Major Risk PB S Pad S-106 S-106PB1 V12 294.49 300.00 331.90 6.31 325.59 Pass: Major Risk PB S Pad S-107 5-107 V35 444.67 450.00 286.88 8.74 278.14 Pass: Major Risk PB S Pad S-108 S-108 V6 443.59 450.00 237.18 7.45 229.73 Pass: Major Risk PB S Pad S-109 S-109 V8 697.95 700.00 193.19 12.04 181.15 Pass: Major Risk PB S Pad S-109 S-109PB1 V2 697.95 700.00 193.19 12.04 181.15 Pass: Major Risk PB S Pad S-10APB1 S-10APB1 V1 536.88 550.00 1157.37 10.61 1146.76 Pass: Major Risk PB S Pad S-10A S-10A V1 536.88 550.00 1157.37 10.56 1146,81 Pass: Major Risk PB S Pad S-10 S-10 V1 536.88 550.00 1157.37 10.61 1146.76 Pass: Major Risk PB S Pad S-110 S-110 V18 494.52 500.00 206.05 9.75 196.30 Pass: Major Risk PB S Pad S-112 S-112V19 494.87 500.00 - 58.07- 9.36 48.71 Pass: Major Risk PB S Pad S-113 S-113V13 849.67 850.00 272.03 16.44 255.59 Pass: Major Risk PB S Pad S-113 S-113A V2 849.67 850.00 272.03 16.29 255.74 Pass: Major Risk PB S Pad S-113 S-113B V5 849.67 850.00 272.03 16.29 255.74 Pass: Major Risk PB S Pad S-114 S-114V13 544.64 550.00 349.54 10.71 338.84 Pass: Major Risk PB S Pad S-114 S-114A V6 544.64 550.00 349.54 10.55 338.99 Pass: Major Risk PB S Pad S-115 S-115 ST V1 Plan: Plan 952.01 950.00 123.59 14.78 108.82 Pass: Major Risk e BPX AK e Anticollision Report C,unpany: BP Amoco Date: 10/8/2003 Time: ·16;01 :';)7 Page: 2 Field: Prudhoe Bay Reference Site: PB S Pad CO-Qrdinate(NE) Reference: Well;PlanS-116, True North Reference Well: Plan 8-116 Vertical (TVD) Reference: S-116 plan 64.7 Referenc.e Wellpath: Plan 8-116 Db: Sybase Summary Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft PB S Pad S-115 S-115V7 952.01 950.00 123.59 14.68 108.91 Pass: Major Risk PB S Pad 8-117 S-117V4 1146.75 1150.00 91.86 19.92 71.94 Pass: Major Risk PB S Pad 8-11A 8-11A V7 447.77 450.00 1255.34 8.33 1247.01 Pass; Major Risk PB 8 Pad 8-11B S-11B V5 560.62 550.00 1249.98 11.35 1238.63 Pass; Major Risk PB S Pad S-11 S-11 V1 535.91 550.00 1249.64 11.06 1238.58 Pass: Major Risk PB 8 Pad S-12A S-12A V1 568.80 600.00 1342.53 12.28 1330.25 Pass: Major Risk PB S Pad S-12 S-12 V1 97.57 100.00 1349.02 2.18 1346.85 Pass; Major Risk PB 8 Pad S-13 S-13 V1 534.53 550.00 1448.29 9.21 1439.08 Pass: Major Risk PB S Pad S-14 8-14 V1 600.00 650.00 1548.81 19.32 1529.49 Pass: Major Risk PB S Pad S-15 8-15 V2 2877.54 2600.04 673.87 54.29 619.57 Pass: Major Risk PB 8 Pad 8-16 S-16 V1 2981.75 2650.00 723.62 55.03 668.59 Pass: Major Risk PB 8 Pad S-17 8-17 V1 5976.37 5750.00 752.03 109.03 643.00 Pass; Major Risk PB 8 Pad S-17 8-17A V1 5976.37 5750.00 752.03 109.03 643.00 Pass: Major Risk PB S Pad S-17 S-17AL1 V1 5976.37 5750.00 752.03 109.03 643.00 Pass; Major Risk PB S Pad S-17 S-17APB1 V1 5976.37 5750.00 752.03 109.03 643.00 Pass; Major Risk PB 8 Pad S-17 S-17B V1 5976.37 5750.00 752.03 109.03 643.00 Pass; Major Risk PB 8 Pad S-17 8-17C V1 5976.37 5750.00 752.03 108.92 643.11 Pass: Major Risk PB S Pad 8-17 S-17CPB1 V2 5976.37 5750.00 752.03 108.92 643.11 Pass; Major Risk PB 8 Pad 8-17 8-17CPB2 V1 5976.37 5750.00 752.03 108.92 643.11 Pass; Major Risk PB S Pad S-18 8-18 V1 585.76 600.00 1308.59 10.77 1297.82 Pass: Major Risk PB S Pad 8-18 8-18A V15 588.64 600.00 1308.64 10.75 1297.89 Pass; Major Risk PB S Pad S-19 8-19 V1 2305.26 2200.01 565.76 40.54 525.22 Pass; Major Risk PB 8 Pad 8-200PB1 S-200PB1 V4 599.29 600.00 f 30.64 8.68 21.96 Pass: Major Risk PB 8 Pad S-200 8-200 V2 599.29 600.00 30,64 8.79 21.85 Pass: Major Risk PB S Pad S-201 S-201 V2 250.28 250.00 315.35 4.35 311.01 Pass; Major Risk PB 8 Pad 8-201 8-201PB1 V11 250.28 250.00 315.35 4.35 311.01 Pass; Major Risk PB S Pad 8-20 8-20 V4 635.10 650.00 636.88 10.93 625.95 Pass: Major Risk PB 8 Pad S-20 8-20A V2 635.10 650.00 636.88 10.94 625.94 Pass; Major Risk PB 8 Pad S-213 8-213 V6 848.56 850.00 . 72.09 11.91 60.18 Pass; Major Risk PB 8 Pad 8-215 S-215 V7 3864.07 3550.00 817.38 69.60 747.78 Pass: Major Risk PB S Pad 8-216 8-216 V1 1001.23 1000.00 _ 35.39 16.79 18.60 Pass: Major Risk PB S Pad 8-21 S-21 V1 500.00 500.00 666.93 8.49 658.44 Pass; Major Risk PB S Pad 8-22A S-22A V1 2332.20 2200.00 537.07 37.13 499.95 Pass; Major Risk PB S Pad 8-22B S-22B V2 2332.20 2200.00 537.07 37.29 499.79 Pass: Major Risk PB S Pad 8-22 8-22 V1 2332.20 2200.00 537.08 37.12 499.97 Pass; Major Risk PB S Pad 8-23 8-23 V1 2186.44 2100.00 660.55 34.79 625.76 Pass: Major Risk PB S Pad 8-24 Plan#4 8-24B VO Plan: 591.82 600.00 682.94 10.18 672.75 Pass; Major Risk PB 8 Pad S-24 8-24 V5 589.57 600.00 682.90 9.96 672.94 Pass: Major Risk PB 8 Pad S-24 8-24A V1 591.82 600.00 682.94 10.01 672.93 Pass: Major Risk PB 8 Pad S-25APB1 8-25APB1 V1 887.34 950.00 702.64 26.96 675.68 Pass; Major Risk PB 8 Pad S-25A S-25A V1 588.54 600.00 715.23 9.95 705.28 Pass: Major Risk PB S Pad 8-25 S-25 V1 588.54 600.00 715.23 9.95 705.28 Pass: Major Risk PB S Pad 8-26 8-26 V1 544.01 550.00 734.48 8.18 726.30 Pass; Major Risk PB S Pad 8-27 Plan 8-27B V4 Plan; PI 544.25 550.00 774.77 8.79 765.98 Pass: Major Risk PB 8 Pad 8-27 8-27 V1 500.00 500.00 774.52 8.77 765.75 Pass; Major Risk PB 8 Pad 8-27 8-27A V2 587.48 600.00 775.51 9.43 766.07 Pass; Major Risk PB S Pad S-28 8-28 V4 543.13 550.00 798.69 9.22 789.47 Pass: Major Risk PB S Pad 8-28 8-28A V1 543.13 550.00 798.69 9.22 789.47 Pass; Major Risk PB S Pad 8-28 8-28B V2 544.16 550.00 798.71 9.24 789.46 Pass: Major Risk PB S Pad 8-28 8-28BPB1 V7 544.16 550.00 798.71 9.24 789.46 Pass; Major Risk PB 8 Pad 8-29AL 1 8-29AL 1 V1 537.80 550.00 1007.74 9.63 998.11 Pass; Major Risk PB S Pad 8-29A Plan S-29AL2 VO Plan; 541.01 550.00 1007.79 9.46 998.32 Pass; Major Risk PB S Pad 8-29A 8-29A V1 537.80 550.00 1007.74 9.63 998.11 Pass: Major Risk PB 8 Pad 8-29 Plan 8-29B V1 Plan; S- 541.01 550.00 1007.79 9.63 998.15 Pass; Major Risk PB S Pad 8-29 S-29 V1 537.80 550.00 1007.74 9.63 998.11 Pass; Major Risk PB S Pad 8-30 S-30 V1 542.92 550.00 873.02 9.38 863.64 Pass: Major Risk PB 8 Pad 8-31A 8-31 A V3 540.10 550.00 922.45 9.08 913.37 Pass: Major Risk PB 8 Pad 8-31 S-31 V1 540.10 550.00 922.45 9.08 913.37 Pass: Major Risk PB S Pad 8-32 8-32 V1 539.51 550.00 1127.63 12.31 1115.32 Pass; Major Risk PB 8 Pad 8-33 8-33 V1 537.70 550.00 951.53 8.96 942.57 Pass; Major Risk PB 8 Pad 8-34 8-34 V1 494,29 500.00 1191.15 7.99 1183.16 Pass; Major Risk PB 8 Pad 8-35 8-35 V1 536.19 550.00 1221.42 8.38 1213.04 Pass: Major Risk PB 8 Pad 8-36 8-36 V1 534.49 550.00 1283.26 8.26 1275.00 Pass: Major Risk Company: Field: Reference Site: Reference Well: Reference Wellpath: Summary PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad PB S Pad BPAmoco Prudhoe Bay PB S Pad Plan S-116 Plan S-116 Offset Wellpath Well S-37 S-38 S-40A S-40 S-41L 1 S-41PB1 S-41 S-42PB1 S-42 S-43L 1 S-43 S-44L 1 PB 1 S-44L 1 S-44 e BPX AK Anticollision Report e Date: 10/8/2003 Time: 16:01:57 Page: 3 Co-ordinate(NE) Reference: Vertical (fVD) Reference: We":PlanS~116, True North S-116 plan 64.7 Db: Sybase > Reference Offset Ctr-Ctr NO-Go Allowable Wellpath MD MD Distance. Area Deviation Warning ft ft ft ft ft S-37 V1 534.27 550.00 1311.15 7.92 1303.23 Pass: Major Risk S-38 V1 536.45 550.00 1095.86 8.23 1087.63 Pass: Major Risk S-4ÒA V1 2914.39 2400.00 922.16 50.66 871.50 Pass: Major Risk S-40 V1 2914.39 2400.00 922.16 50.66 871.50 Pass: Major Risk S-41L1V1 835.58 850.00 118.28 13.58 104.69 Pass: Major Risk S-41PB1 V1 835.58 850.00 118.28 13.58 104.69 Pass: Major Risk S-41 V1 835.58 850.00 118.28 13.58 104.69 Pass: Major Risk S-42PB1 V1 940.01 950.00 93.47 14.73 78.74 Pass: Major Risk S-42 V2 940.01 950.00 93.47 14.73 78.74 Pass: Major Risk S-43L 1 V2 794.86 800.00 55.04 12.77 42.27 Pass: Major Risk S-43 V3 794.86 800.00 55.04 12.77 42.27 Pass: Major Risk S-44L 1 PB 1 V3 698.01 700.00 )28.31 10.66 17.65 Pass: Major Risk S-44L 1 V5 698.01 700.00 28.31 10.66 17.65 Pass: Major Risk S-44 V10 698.01 700.00 128.31 10.66 17.65 Pass: Major Risk -294 200 100 -0 100 200 -294 Field: Prudhoe Bay Site: PB S Pad Well: Plan S-116 Wellpath: Plan S-116 Ddm,IØ.JO~-107 (S-107) ß 0 S-I$~~ S·IOI (S-IOIPBI) S·101 (S-IOI) 27Ü" e e S-44J($~(lS.I~LIPBI) S-42~SJI\! -42PB I) S-112 (S-H2) S-43J($~3L1) 90s-41~~P)J I) 180 294 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation {lOOn/in] Polygon I 2 3 4 Site: PH S Pad .. Drilling Target Conf.: 9570. Description: Map Northing: 5977600.00 ft Map Easting: 616850.00 ft Latitude: 70°20'51.161 N Xft 76.19 72.22 -177.77 -173.80 Target: S-116 Kup Tgt yft 73.81 -176.18 -172.21 77.78 e:PlanS-116 d on: Planned Program Vertical Depth: 6665.00 ft below Mean Sea Level Local +N/-S: -2841.85 ft Local +E/-W: -2125.56 ft Longitude: 149°03'05.103W Map E ft 616925.00 616925.00 616675.00 616675.00 Map N ft 5977675.00 5977425.00 5977425.00 5977675.00 -2500 -2l00 -2800 -2900 ~ -3000 -3100 0 CJ CJ CJ CJ CJ CJ o 0 CJ CJ CJ CJ CJ CJ o 0 ~ (I) N CJ 0- m o 0 ø ~ N N N N o ( ~ I I I I ~ ~ ~ e ......0 --- -..... \ Vì e 27 26 25 S PAD " ~ 36 N 1100-' ~..;¡¿ =« ;...~ II I IJ)(f)(f · · <ÞH· . ~~~~~ª~2 ~~~~~g5~ ~~~~~g ~ ~ ~ ~ ~~~~~~~~ ~g¡~~~~~ ~~~~~¡ ~ ~ ~ ~ (I) ¿J 34 S-PAD N 1010 T.12N. T.11N 2 ....... VICINITY MAP N.T.S. N 840 -, I ~ I- a:: <..') z ¡::: UJ X w ~AN~ MANIFOLD MODULE '" '" 30 .... z « -' a. , -~- I LEGEND -+ AS-STAKED CONDUCTOR . EXISTING CONDUCTOR NOTES: 1. DATE OF SURVEY: SEPTEMBER 27, 2003 2. REFERENCE FIELD BOOK: W003-09 PAGES 25-27. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.9999165. 6. HORIZONTAL CONTROL IS BASED ON MONUMENTS S-3 & S-4. (HELD S-4) 7. BASIS OF VERTICAL CONTROL IS OPERATOR MONUMENTATION. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. LOCATED WITHIN PROTRACTED SEC. 35, T. 12 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL ASP. PLANT GEODETIC GEODETIC GROUND SECTION NO. COORDINA TES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS S-116 Y=5,980,474.96 N. 1010.00 70'21'19.112" 70.3553089' 35.6' 4,272' FSL X= 618,929.98 E. 380.00 149'02'02.994" 149.0341650' 4,502' FEL S-118 Y= 5,980,489.96 N. 1010.00 70'21'19.260" 70.3553500' 35.6' 4,287' FSL X= 618,929.97 E. 365.00 149'02'02.987" 149.0341631' 4,501' FEL Y= 5,980,459.96 N. 1010.00 70'21 '18.965" 70.3552681' 36.0' 4,257' FSL S-Spare X= 618,929.98 E. 395.00 149'02'03.000" 149.0341669' 4,502' FEL ! F Robert DRAWN ~ COTTON ]ffi CHECKED vbp RFA DATE: 9/23/03 DRAWING: SH EET FRB03 WOA-S 01-00 WOA S-PAD ~ GJg)g)[lJ[bo JOB NO· SCALE: AS-STAKED CONDUCTOR ENGlNE:IR5ANUlANDSlJRvEYORS WELLS S-116, S-118 & SPARE 1or1 JJC RF A S01W£'ST f1!'/E'IoEED LAN!: 1"= 150' BY CHK MlœOP"GL AL1o.Sk" 99SQJ ~ 0 9/30/03 ISSUED FOR INFORMATION ~ NO. DATE RE'v1S1ON w DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DATE I I CHECK NO. e 8/22/2003 055152 VENDOR DISCOUNT NET H p055152 . ß/22/2003 INV# PR082003L PERMIT TO DRILL ~EE 5, \ \ lo i ~ II I Ii ,00i, '¡oil j:! ¡ iE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ TO THE ORDER OF: NATIONAL CITY BANK 56-389 Ashland, Ohio 412 PAY: 1110 5 5 . 5 2111 I: 0 ... . 2 0 ~ a ~ 5 I: o. 2 ? a ~ bill . PTD#:2031810 Administration Appr RPC Date 1 0/21/2003 Appr WGA 18 19 20 21 22 23 24 25 26 27 Date 28 10/22/2003 29 30 31 32 33 34 Engineering Geology 35 36 Date 37 10/21/2003 38 39 Appr RPC Geologic Com~sioner: Ol.s Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UN AURO S-116 Program DEV Well bore seg Field & Pool PRUDHOE BAY, AURORA OIL - 640120 Initial ClasslType DEV 11WINJ GeoArea Unit On/Off Shore ~ Annular Disposal 1 Permittee attached_ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 2 _Leasenumberappropri<lte_ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _Yes _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _Unique weltname_aod ol!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJlJoc<lted in a defil1ed.pool _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJlJoc<lted proper _distance_ from driJling ul1itboul1d_alY_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . Yes _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJoc<lted pr_oper _distance from otber wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ 7 _S_ufficiel1tacreag.eaYail<lble in_dJilliog unjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ Yes _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 8 Jtdeviated, js_ weJlbore platil1cJuded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ 9 _O.perator only: affected party _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _O.per_ator has_appropriateJ).ond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Permit cao be iSSl!ed without co_nservaJiOI1 order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 12 Permit cao be iSSl!ed without ad_mil1i$tratÎ\le_a'ppr~JVaJ _ _ _ _ _ _ _ _ . . _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 13 Can permit be approved before 15-day wait Yes 14 WellJocated within area and_strata _authorized by lojectioo Order # (puUO# in_cDmmeotsUFor_ Yes _ AIO 22B _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . 15 AJI wells_wit!1inJl4Juile_area_of review ideotlfied (FDrservjcewell OI1IYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ YeL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produ_ced iojector; duration_of pre-.productiol1less than:3 montbs_ (For_service well onJy) . . _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 _AÇMPJ'ïndjng 9f Con_si$teocyhas beenjssuedJorJbis prolect _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _C90duct9r strin.9_PJovlded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _S_urfacecasil1g_PJotects alLknown USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _CMT vDl adequ_ateJo circulate_oncol1d_uctoO!! $UJtC$g _ _ _ _ _ _ _ _ . _ _ _ _ _ . . Yes _ _ _ _ _ _ Adequate excess, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _CMT v_ol adequateJo tie-in Jong _string to_surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ CMTwill coyer_all koownJ)ro_ductiye borizon_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _C_asiog de_sigos adeClua_te fDr CJ, B_&_permafrDst _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ MequateJan_kage_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ l\Iab9rsJ_ES, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ JtaJe-drill~ bas a_ to:4.0;3 for abandonment beeo ¡¡PPJoved . _ _ _ . _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Mequatewellbore separ¡¡tion_pr0.posed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Jtdiverter JectuiJed, does it meet_ reguJatiol1s_ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ Diverter waiveJ gr_aoted. _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _DJilliog fluid_program schematic_&. ectuipJistadequ¡¡te_ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Max MWJ!>J_ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _BOPES,dDthey meet reguJatiol1 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _BOPE_pre_ss raJiog ap'propriate;_testto_(puJ psig In_commel1ts)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ Yes _ Test tDAOOO_psLMS~ 26_80 psi._ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ C_hoke_manifold compJies w/AP'- R~-53. (May 84) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ Yes _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Work will occ_ur withoutoper¡¡tion_shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ Js preseoce of H2S gas_ probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ No_ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Mecbanlc¡¡LcoodJtloo pfwells within AOR yerified (For servicewelJ 0 nJyJ_ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _l\Iowell$jnAQR._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ - - - - - - Permit cao be iSSl!ed w/o hydrogen sulfide meas_ures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _D_ata_PJeseoted on_ pote_ntial oveJpreSSureZOl1e$ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _SeismlcanalysJs. of sbaJlow gasz_ooes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . NA _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _SeabedcOl1ditipo survey.(if off-sh_ore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Conta_ct l1amelp!1oneforweekly progress_reports [exploratOIY.oo1yt _ _ _ _ _ _ _ _ _ . NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ .. _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: /Ojè//j Engineering Commissioner: Þ Date ~ ~~ \.,jJ ~. Public ... ~ commiss~ /'l2 ?/ ~ o e e
