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203-152
~ ) ) . 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. J 0:3 - J ~ ~ Well History File Identifier Organizing (done) o Two-sided 11111111111 "'11111 o Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA ~kettes. No. I D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: o Greyscale Items: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: BY: ÇMaria ') Date: / It)? JDh D Other:: NOTES: Isl mP BY: (: Maria) Date: 1/9-.7. ' D (P Ii X 30 = 30 Date: 1/tJ-7¡ 00 frf0 + ~ to = TOTAL PAGES Õ /:; (Count does not include cover sheet) vVlð Isl r ' r 1111 1111 1111111111111111111 Project Proofing Isl Scanning Preparation BY: '- Maria ) Production Scanning Stage 1 Page Count from Scanned File: 57 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES B Date: J j/}7' ób If NO in stage 1, page(s) discrepancies were found: BY: Isl NO .!J m, Stage 1 YES NO BY: Maria Date: Isl 111II111I1111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc • • -~_. ,,.~_ -. MICROFILMED 03/01 /2008 DO NOT PLACE ~. ~~ ANY NEW MATERIAL UNDER THIS PAGE F:l1,aserFiche~C~rPgs_Inserts~Microfilm_Marker.doc \6~ r¿rv~/ Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well V-114 V-114 V-114 V-114 V-114 40009730 40009730 40009730 40009730 40009730 Job# Log Description OH LDWG EDIT OF CDR/AND MD CDR-RESISTIVlTY TVD CDR-RESISTIVITY MD VISION DENINEUTRON TVD VISION DEN/NEUTRON 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, Alaska 99508 Date Delivered: NO. 3624 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color BL CD 10/28/03 10/28/03 10/28/03 , 10/28/03 1wwoot , Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth R''''''''{ OUCJ\~O I n 12/21/05 RECEIVED JAN 0 6 2006 Alaska Oif & Gas Cons. ~ Anchorage ._~ ~ q N\ \J ;< ~ \~ \or- DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Permit to Drill 2031520 Well Name/No. PRUDHOE BAY UN BORE V-114 Operator BP EXPLORATION (ALASKA) INC 5~ :1l~a-~ API No. 50-029-23178-00-00 MD 8340"-- TVD 6876", Completion Date 1 0/29/2003 ".. Completion Status P&A Current Status P&A UIC N ----~---- Mud Log No Samples No Direct~Y \.... " Yes ~ REQUIRED INFORMATION -- ~----- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, AZM, DEN, NEU, RES, PWD Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Name Interval Start Stop Log Log Run Interval OH/ -- Scale Media No Start Stop CH Received Comments 0 8340 12/1/2003 Text, Word & Excel surveys 0 8340 12/1/2003 Sample Set Sent Received Number Comments ~-- ---- ------ ¥D D Asc ~Pt L_ ___"__ "___ _~___ Directional Survey Directional Survey Well Cores/Samples Information: ADDITIONAL INFORMATION Well Cored? Y@ Chips Received? ~ Daily History Received? 0N ~N Formation Tops Analysis Received? ~ - .. -~. ------------------- c-o~~-e-~~~-IV~t.b-G~l.~ H~(~ ~~'~I þc~(.(1j, f3c~. / Ç~l{(þS (. \M..<A; b1- 1\ Vl~ r;.oIoN'-'-V f? q1 'i. fa~.-...... ~ ~lA ~ Compliance Reviewed By: - ~ M ~.$) ,\ \#. ') P o..~ "" (\,. t ~ "t.~ ¡ 'f J..,... ^ ~~ ~ ) ) l...-/ ~ 7 l" ~ ~~J u--. ~ rr r,W Vl J)....; r/ L- ~o Jet ~ b\c> ~~G (1~¡" r.; r? ~ Co YY\. Date: )$ ))o~~ - --------..------- . - --- ------ --- - ------ \ STATE OF ALASKA ~ ALASKA ,L AND GAS CONSERVATION COMr'v. )ION , WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: D Oil D Gas D Plugged B Abandoned D Suspended D WAG 20AAC 25.105 20AAC 25.110 Zero Other 5. Date Comp., Susp., or Aband. 10/29/2003 v" 6. Date Spudded 10/22/2003 D GINJ D WINJ D WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4649' NSL, 1789' WEL, SEC. 11, T11N, R11E, UM Top of Productive Horizon: 1150' NSL, 3305' WEL, SEC. 11, T11 N, R11 E, UM Total Depth: 851' NSL, 3242' WEL, SEC. 11, T11 N, R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590515 y- 5969896 Zone- ASP4 TPI: x- 589043 y- 5966379 Zone- ASP4 Total Depth: x- 589111 y- 5966081 Zone- ASP4 No. of Completions 18. Directional Survey BYes DNa 21. Logs Run: MWD, GR, AZM, DEN, NEU, RES, PWD 7. Date T. D. Reached 10/28/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 81.8' 9. Plug Back Depth (MD+ TVD) 2983 + 2719 10. Total Depth (MD+TVD) 8340 + 6876 11. Depth where SSSV set NIA MD 19. Water depth, if offshore NIA MSL RECEIVED DEC 2 92003 1 b. Atésk;;ü"~ Gas' GÖ\U. CommissiQ1 B DeveloPnAmthdüsþploratory D Stratigraphic D Šervice 12. Permit Number 203-152 303-326 13. API Number 50- 029-23178-00-00 14. Well Number PBU V-114 15. Field and Pool Prudhoe Bay Field 1 Borealis Pool Ft Ft 16. Lease Designation and Serial No. ADL 028245 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 22. . CASING'. Size· .... 20" 9-5/8" :; ~'''I "1': ,:' ,', I :/. ':~I' ,,:,' I 'I. 1:' I I: ,I ':,:' I ,',: ,'1;' ,', ': ': I , . WTIIP~~' Ft. I ,'il"~RADe' 91.5# H-40 40# L-80 CASING, LINER AND CEMENTING RECORD '. ... SETliING,DI:ÞTH 'i ,,' . . ',trlq'·' '~d.· '..!:., . ,. '. .". ,i· :,. .:',...,."..,,;.,.' ., :i. ',....'. .....'..",' .:'.':',," I,.., I I I 'II,'" .,'., ".I,. ,I ·1'1"1' I IMjõ ,1,,111'1 "I' -:'1'1,1 'I ·I",:.I"'I''''I,;I",'' 'II~' l'i':' "I;'¡"III'II,'i" '·,''''''''1,"1, , I :'~I',!r·,'; ,I "~I, , ',' \:rOR:.I',I.!,:' I' BOTTdM ,··::,:SI~~I·.·'.',GEM~Nf NGI'~gcþij:Q;:¡'il'I":' ,I, ,'::, '........,.:.' Surface 108' 30" 260 sx Arctic Set (Approx.) 28' 2946' 12-1/4" 525 sx AS Lite, 336 sx Class 'G' II, I",·' I I,',' ,I','", 'I" ',1,1 ':.." '", :';, , , "I: I ,," ,," :,'i '~:: l'l:p ::1:: ,:,:, :;' i :::; ,.: '¡:I / ,,' :,': ':, : I:' I ',,: ,I, ': 1 AMOt:JNT'I?!;J ;;~ :b:: .. "',' '" "", 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 26. 24.,' , . . TU.BING .RecÓRD·. DEPTH SET (MD) SIZE NIA PACKER SET (MD) TVD 25: 'I,!" ..~CIÄ;FfRAÄ~~RË,j~EMENr$QUE~E"Erc:' , : ::: , ' , ," , ' , : " :,', " :,:... "I ", ' ' :' " ' .." ' ' .. " :'" : ': " 1 ' .. ~' , ..,'" " " : ' , , '.., ' , , ,I, " I, ': ; :' '"",,', ' , , DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3698' P&A, Plugs, 44 + 145 Bbls Class 'G' 2983' Kick Off Plug, 88 Bbls Class 'G' bf ~\O' \\\Ø\.. /' /' Date First Production: Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oll-BBl PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-BBl Press. 24-HoUR RATE GAs-McF CHOKE SIZE GAS-Oil RATIO W A TER-BBl GAs-McF W A TER-BBl 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 Form 10-407 Revised 2/2003 Ø!¿s, Bfl nECS1. CONTINUED ON REVERSE SIDE G ~0 28. GEOLOGIC MARKERS ) 29. )RMATION 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 3191' Ungu M Sands 4508' Schrader Bluff N Sands 4821' Schrader Bluff 0 Sands 5009' Base Schrader / Top Colville 5426' HRZ 7320' Kalubik 7782' Kuparuk D 7990' Kuparuk C 8044' Kuparuk B 8211' 2900' None 4038' 4306' 4467' 4824' 6356' 6598' 6705' 6732' 6813' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 203-152 303-326 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. PBU V-114 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Neil Magee, 564-5119 ITEM 1 a: 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). IrEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Name: V-114 Common Name: V-114 Test Date 1 0/25/2003 11/5/2003 LOT FIT Test Type Test Depth (TMD) 2,946.0 (ft) 8,225.0 (ft) BP Leak-OffT est Summary Test Depth (ND) 2,687.0 (ft) 6,663.0 (ft) AMW 9.70 (ppg) 9.30 (ppg) Surface Pressure 650 (psi) 1,310 (psi) Leak Off Pressure (BHP) 2,004 (psi) 4.529 (psi) Page 1 of 1 EMW 14.36 (ppg) 13.08 (ppg) ,~ '.-' Printed: 11/24/2003 8:32:35 AM ') ) BP Opera.tionsSummaryReport Page 1 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 Date From .;.To Hours Task Code NPT Phase Description of Operations 10/20/2003 19:00 - 20:30 1.50 MOB P PRE PJSM. RID & prepare to move Camp, Shop & Pit module. 20:30 - 00:00 3.50 MOB P PRE Move camp, shop & pit module from W-209i to V-pad location. Continue rigging down. Lay down 9ES derrick & prepare sub-base for rig move. 10/21/2003 00:00 - 02:00 2.00 MOB P PRE Continue rigging down 9ES & prepare for rig move. Held PJSM with Rig Crew, Peak, Tool Services & all personnel involved in the rig move. 02:00 - 07:00 5.00 MOB P PRE Move rig off W-209i well slot & off W-Pad location onto Spine road. Rig in transit, arrived on V-Pad @ 07:00 hrs with no problems. 07:00 - 12:00 5.00 RIGU P PRE Move rig's sub base over V-114 conductor, lay herculite around same. Held PJSM. Raise derrick. Spot and level rig. Spot pit module & cuttings tank. Hook-up power,water, steam and mud lines. Accept Rig at 12:00 hrs on October 21, 2003. 12:00 - 00:00 12.00 RIGU P PRE Continue rigging up 9ES for drilling operations. Mix spud mud, N/U Bell-nipple on pre-install 21-1/4" Diverter. Load Pipe Shed with 4" DP & BHA tools. P/U & rack back 25 stands of 4" DP in derrick + 7 stands of 4" HWDP + drilling jars & one stand of 7" NMDC. 10/22/2003 00:00 - 01 :30 1.50 RIGU P PRE Slip & cut 88' of drill line. Re-set & test C-O-M. 01 :30 - 02:00 0.50 RIGU P PRE Held Pre-Spud meeting with Nabors rig crew & all service company personnel. 02:00 - 03:00 1.00 RIGU P PRE M/U 12-1/4" Drilling assembly. Adjust mud-motor to 1.50 deg bend. Orient MWD/Mud-motor. 03:00 - 03:30 0.50 RIGU P PRE Function test 21-1/4" Diverter system (20 seconds to close element) ** Lou Grimaldi with the AOGCC waived witnessing the 21-1/4" Diverter test **. 03:30 - 04:00 0.50 RIGU P PRE Fill up hole with water. Check for leaks on Diverter & Flow line-OK. Clean out 20" conductor to 108'. 04:00 - 06:00 2.00 DRILL P SURF SPUD WELL @ 04:00 HRS. Drill 12-1/4" hole from 108' to 353' (Start sliding @ 321'). WOB = 5-20k. RPM = 75 + Mud-motor (Motor factor = 0.2216 rpm/gal) GPM = 610 w/1000 psi wI 170 psi DIFF Torque off Btm = 950 FtLb. Torque on Btm = 2500-4000 FtLb P/U 53K. SIO 53K. ROT 53K. 06:00 - 06:30 0.50 DRILL P SURF CBU from 353'. POOH two stands & P/U drill jars. Trip back to bottom with no problems. 06:30 - 16:30 10.00 DRILL P SURF Drill 12-1/4" directional hole from 353' to 1559'. Slide as required to build angle & maintain azimuth. WOB = 30-35K RPM = 80 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 2000 FtLb Torque on Btm = 6000 FtLb GPM = 670 @ 2580 psi w/ 200-250 psi Diff. P/U 82K SIO 71 K ROT 74K 16:30 -17:00 0.50 DRILL P SURF Pump Lo-Vis sweep & circulate hole clean (2.5 Btm-up) from 1559' @ 670 gpm wI 2580 psi. Reciprocate & rotate drill string while circulating. 17:00 - 19:00 2.00 DRILL P SURF POOH for bit change. Had a few mild intermittent tight spots with 10-20k overpull. Worked drill string back down through each tight spot & pulled back up through same with no problems. Hole in good shape. Printed: 11/24/2003 8:32:44 AM ) ) BP Operations Summary Report Page 2" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1 0/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 Date From - To Hours Task Code NPT Phase Description of Operations 10/22/2003 19:00 - 19:30 0.50 DRILL P SURF Break off bit. MIU new Hughes MXC1. 19:30 - 20:00 0.50 DRILL P SURF Clean rig floor of excess mud generated from trip out. 20:00 - 21 :00 1.00 DRILL P SURF TIH with 12-1/4" Steerable Drilling assembly to 1466' with no problems. M/U TDS. Establish circulation. Precautionary wash to bottom @ 1559'. 21 :00 - 00:00 3.00 DRILL P SURF Drill 12-1/4" directional hole from 1559'-1869'. Slide as required to build angle & maintain azimuth. WOB = 30-35K RPM = 80 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 2100 FtLb Torque on Btm = 6400 FtLb GPM = 670 @ 2610 psi w/275 psi Diff. P/U 85K SIO 75K ROT 77K AST/24 Hrs = 6.86 hrs ART/24 Hrs = 2.87 hrs Drilling Time last 24 Hrs= 9.73 hrs 10/23/2003 00:00 - 05:00 5.00 DRILL P SURF Drill 12-114" directional hole from 1869'-2959' (9-5/8" csg point). Slide as required to build angle & maintain azimuth. WOB = 30-45K. RPM = 80 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 3200 FtLb. Torque on Btm = 7000-9000 FtLb. GPM = 670 @ 3340 psi w/ 200-275 psi Diff. P/U 98k S/O 75k ROT 88k Note: Encounter hydrates while drilling from 2270'·2680'. Drilled through same with no problems. AST Hrs = 1 hrs ART Hrs = 2 hrs 05:00 - 06:30 1.50 DRILL P SURF Circulate & condition mud prior to making wiper trip. CBU x 3 at 650 gpm & 100 RPM. 06:30 - 11 :00 4.50 DRILL P SURF Monitor well. POOH with no problems (10-15k intermittent drag) to 1890', hole pulling tight. Unable to work past this depth. TIH to 1930'. M/U TDS & backream up to 1550'- previous bit run. 650 gpm, 2500 psi. 11:00 ·13:00 2.00 DRILL P SURF POOH without pumping from 1550' to 1280'. Hole started swabbing· unable to work past tight spot @ 1280'. MIU TDS & establish circulation. Backream from 1280' to 950'. Pump & pull up to 500'. 13:00 - 14:00 1.00 DRILL P SURF Stand back HWDP, Jars & drill collars. Clean off balled up stabilizer. 14:00 - 19:00 5.00 DRILL P SURF TIH. Tag up on obstruction @ 940'. M/U TDS into 4" DP_ Establish circulation. Stage up mud pumps to 225 gpm & apply 45 RPM to drill string. Work bit past obstruction. Continue TIH. Encountered excessive drag @ 1890'. Work drill string down to 2015' tagging up solid on obstruction. M/U TDS. Establish circulation. Ream down breaking through obstruction @ 2056'. TIH to 2567', tag up. M/U TDS. Establish circulation. Ream down to 2587'. Circulate & work drill string from 2587'-2496' for 15 minutes to clean up hole. Finish TIH to 2868' with no problems. 19:00 - 20:30 1.50 DRILL P SURF M/U TDS. Establish circulation. Wash to bottom @ 2959'. Circulate & condition mud/hole with 650 gpm @ 3060 psi. Reciprocate & rotate drill string (90-100 RPM) while circulating. Had a lot of cuttings & dehydrated looking mud come across shakers on bottoms up. After getting bottoms-up, pumped a 40 bbl Super-Sweep & circulated hole clean. Very little increase in Printed: 11124/2003 8:32:44 AM ) ) BP Operations Summary Report Page 3_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 Date From -To Hours Task Code NPT Phase Description of Operations 10/23/2003 19:00 - 20:30 1.50 DRILL P SURF cuttings noticed when the Super-Sweep came across shale shakers. P/U 98k S/O 81 k Rot Wt 88k 20:30 - 21 :30 1.00 DRILL P SURF POOH to run 9-5/8" surface casing. Pulled 6 stands with no problems to 2190'. Hole started swabbing & pulling tight. M/U TDS & establish circulation. Backream up to 2100' with 650 gpm @ 2575 psi + 90-100 RPM. Had excessive torque F/ 2150-2115'. At 2115' torque decreased to normal rate. 21 :30 - 22:00 0.50 DRILL P SURF TIH 4 stands to 2493' too check hole conditions-OK. 22:00 - 00:00 2.00 DRILL P SURF Backream from 2493' to 1733'. Attempt to pull pipe with no pumps. Hole swabbing. Pump & pull up to 1276'. POOH with no pumps from 1276' to the top of BHA @ 905'-midnight depth. 10/24/2003 00:00 - 01 :00 1.00 DRILL P SURF POOH with BHA from 905'. 01 :00 - 02:30 1.50 DRILL P SURF UD 12-1/4" BHA. Clear Rig Floor of excess drilling tools & equipment. 02:30 - 04:00 1.50 CASE P SURF P/U 9-5/8" casing landing joint with casing hanger assembly. Make dummy run. UD same. Change elevator bails. RlU 9-5/8" casing running equipment. M/U Franks Fill-up tool to TOS. 04:00 - 11 :00 7.00 CASE P SURF M/U 9-5/8" shoe track. Check floats - OK. Run 70 jts of 95/8" 40# l-80 BTC casing filling every joint. Circ 2 jts down from 2345' to 2425' to move mud in annulus & started taking weight. Work & circ 4 jts casing down to 2580' - acting as if something caught alongside pipe, not below. Able to run casing to bottom from 2580' without circulating. MU hanger & landing jt & land casing - OK. Shoe at 2946' MD. 11 :00 - 13:00 2.00 CEMT P SURF Circ and condition mud - reduce FV to -70 see for cement job. Circ at 10-12 bpm with no losses. 13:00 - 13:15 0.25 CEMT P SURF PJSM for cement job with crew and all service company personnel. 13:15 -13:35 0.33 CEMT P SURF Switch to cementers. Pump 5 bbl water. Test lines to 3500 psi. Pump 5 bbl water followed by 75 bbl Mudpush II spacer at 10.1 ppg. 5 bpm @ 200 psi. 13:35 - .14:40 1.08 CEMT P SURF Release bottom plug. Mix & pump 400 bbls (525 sx) ArcticSet Lite lead slurry at 10.7 ppg. 7 bpm @ 200 psi. 14:40 - 14:50 0.17 CEMT P SURF Switch to tail surry - mix & pump 70 bbls (325 sx) Class G tail at 15.8 ppg. 6 bpm @ 400 psi. 14:50 -15:30 0.67 CEMT P SURF Kick out top plug with 10 bbl water from OS. Switch to rig pump and displace cement with 208 bbl mud at 10 bpm with final displacement pressure of 800 psi. Slow to 3 bpm for last 10 bbls of displacement. Bump plug with 1800 psi. Able to reciprocate casing throughout cement job until half way through displacement. Got back 125 bbls of good lead cement. CIP at 1520 hrs. Bleed off pressure. Floats holding. 15:30 - 17:30 2.00 CEMT P SURF Flush flow line & Oiverter. RID cement head. UD 9-5/8" casing Landing Joint. RID casing running equipment. Clean out rotary table drip pan & shale shakers. 17:30 - 19:30 2.00 DIVRTR P INT1 NID bell-nipple & 21-1/4" Diverter system. 19:30 - 20:30 1.00 WHSUR P INT1 Install FMC Gen-5 11" Unihead system on 9-5/8" casing hanger mandrel & test to 1000 psi. Test was API. 20:30 - 22:30 2.00 BOPSUJP INn N/U 11" 5m x 13-5/8" 5m OSA + 13-5/8" 5m BOP's & all surface related equipment. 22:30 - 23:00 0.50 BOPSU P INT1 M/U BOP test plug on 4" drill pipe & RIH. RIU BOP test equipment. Printed: 11/2412003 8:32:44 AM ') ) BP Operations Summary Report Page 4_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 Date From - To Hours Task Code NPT Phase Description of Operations 10/24/2003 23:00 - 00:00 1.00 BOPSUR P INT1 Start testing BOPE to 250 psi low/4000 psi high. Plan to test all rams, lines, valves and choke manifold. Test annular to 250 psi low/3500 psi high. Witness of BOP test waived by Lou Grimaldi with AOGCC. 10/25/2003 00:00 - 02:00 2.00 BOPSUR P INT1 Finish testing BOPE to 250 psi low/4000 psi high. Test all rams, lines, valves CIK manifold, TDS valves. Test annular to 250 psi low/3500 psi high. All test were API. Witness of BOP test waived by Lou Grimaldi with AOGcC. 02:00 - 02:30 0.50 WHSUR P INT1 Pull test plug. Run & install wear bushing in wellhead. UD 4" drill pipe test joint. 02:30 - 08:00 5.50 DRILL P INT1 P/U a total of 117 joints of 4" drill pipe & rack in derrick. Clean off rig floor. 08:00 - 10:00 2.00 DRILL P INn M/U a new 8-3/4" DS70 bit + PDM w/1.5 deg bend + XO + NM Stab + LWD/MWD/ADN. 10:00-11:00 1.00 DRILL P INT1 Held PJSM regarding loading RA source in LWD. Load source & finish M/U 8-3/4" BHA. 11 :00 - 12:30 1.50 DRILL N DFAL INT1 Attempt to test MWD. Unable to pump at the required rate due to a restriction somewhere in the drill string. POOH to LWD. PJSM on unloading RA source. Remove source. UD LWD/MWD & Mud-motor. 12:30 - 14:00 1.50 DRILL N DFAL INT1 M/U 8-3/4" BHA. P/U fresh Mud-motor + MWD/LWD tools. PJSM on source loading. Load source. M/U BHA & first stand of 4" HWDP. 14:00 - 14:30 0.50 DRILL N DFAL INn M/U TDS. Establish circulation. Test MWD & Mud-motor. Everything working OK. 14:30 - 15:00 0.50 DRILL P INT1 Finish M/U BHA. 15:00 - 16:30 1.50 DRILL P INT1 TIH with 8-3/4" Steerable drilling assembly to 2620' (P/U 54 Jts of 4" DP). 16:30 - 17:30 1.00 CASE P INn M/U TDS. Break circulation. Close BOP & test 9-5/8" casing to 3500 psi for 30 minutes. Test was API. Manually bled-off pressure to zero. Open BOP. 17:30 - 18:00 0.50 DRILL P INT1 TIH from 2620' to 2864'. Tag-up on float collar. 18:00-19:15 1.25 DRILL P INT1 M/U TDS. Establish circulation. Drill float collar @ 2864'. Drill out 9-5/8" shoe track (firm cement) & drill float shoe @ 2947'. Clean out 12-1/4" rathole to 2959', 19:15 -19:30 0.25 DRILL P INT1 Drill 8-3/4" Directional Hole from 2959' to 2979'. WOB = 10-15k RPM = 50 + Mud-motor ( Mud-motor factor = 0.500 rpm/gal ) Torque on btm = 3900-4300 FtLb GPM = 500 w/1875 psi. ART = 0.25 Hrs 19:30 - 20:00 0.50 DRILL P INT1 Pump a 40 bbl HV spacer & displace hole with 9.7 ppg LSND mud. Reciprocate & rotate (80 rpm) drill string while circulating (504 gpm @ 1300 psi). 20:00 - 20:30 0.50 DRILL P INT1 Perform Leak-off test: Pressure up on formation & obtained a leak-off pressure of 650 psi with 9.7 ppg mud. 9-5/8" casing shoe TVD = 2687'. EMW = 14.35 ppg. 20:30 - 21 :00 0.50 DRILL P INT1 Place bit outside of 9-5/8" casing shoe @ 2947'. Stage pumps to maximum circulating rate of 590 gpm to establish a baseline ECD of 10.46 ppg 21 :00 - 00:00 3.00 DRILL P INT1 Drill 8-3/4" directional hole from 2979 to 3366'. Slide as required to maintain angle & azimuth. Printed: 11/24/2003 8:32:44 AM ') ) BP Operations Summary Report Page 5_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/25/2003 21 :00 - 00:00 3.00 DRILL P INn WOB = 10-20k RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 2600 FtLb Torque on Btm = 4000 FtLb GPM = 590 @ 2100 psi wI 200-300 psi Diff. P/U 101k SIO 80k ROT 95k AST/24 Hrs = 0.25 hrs ART/24 Hrs = 1.50 hrs Drilling Time last 24 Hrs= 2.0 hrs 10/26/2003 00:00 - 00:00 24.00 DRILL P INT1 Drill 8-3/4" directional hole from 3366' to 6882'. Slide as required to maintain inclination & azimuth. WOB = 15-25k RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 4300 FtLb Torque on Btm = 7200 FtLb GPM = 590 @ 3320 psi wI 300-340 psi o iff. P/U 153k SIO 120k ROT 136k Backream every stand at 590 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 6882' = 10.47 --- Actual ECD = 10.68 From 6387' sliding between 40' and 70' per stand. Start building angle to a planned 58 degrees and turning to the left decreasing azimuth from 213 degrees to a planned azimuth of 170 degrees needed by 7430' as per well plan. Note: At around 6820' the ADN tool malfunctioning (intermittently stopping & starting). AST last 24 hrs. = 5.75 hrs. ART last 24 hrs. = 9.6 hrs. ConnlSurvey hrs. = 9.65 hrs Drilling Time last 25 Hrs= 15.35 hrs 10/27/2003 00:00 - 03:00 3.00 DRILL P INT1 Drill 8-3/4" directional hole from 6882' to 7206' MD/6288' TVD. Slide as required to maintain inclination & azimuth. WOB = 15-25k RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 4300 FtLb Torque on Btm = 7200 FtLb GPM = 590 @ 3320 psi wI 300-340 psi o iff. P/U 154k SIO 124k ROT 138k ART = 0.75 Hrs AST = 1.55 Hrs. Backream every stand at 590 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 7206' = 10.47 -- Actual EcD = 10.70 ADN tool (sIn 286) not working at all. NOTE: Crossed fault @ 6944' MD/6120' TVD. Top of HRZ estimated to be @ +/- 6340' KBTVD Continue sliding from 6882' @ 40'-70' per stand. Building angle to a planned 58 degrees and decreasing azimuth from 213 degrees to a planned azimuth of 170 degrees needed by 7430' as per well plan. 03:00 - 06:00 3.00 DRILL P INT1 Rack back one stand (No room to work drill string). Circulate & Printed: 11/24/2003 6:32:44 AM ) ) BP Operations Summary· Report Page 6_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 Date From - To Hours Task Code NPT Phase Description of Operations 10/27/2003 03:00 - 06:00 3.00 DRILL P INT1 condition (590 gpm @ 3490 psi) mudlhole prior to POOH (Trip for ADN tool). Increase mud weight while C & C mud with 11 ppg Spike fluid from a 9.7 ppg to 10.2 ppg before POOH. Riciprocate & rotate (80 rpm) drill string while circulating from 7195'-7101'. 06:00 - 09:00 3.00 DRILL N DFAL INT1 POOH (Trip for ADN tool) from 7195' to 3250' with no problems. Max drag was 10k. At 3250' hole swabbing. Work drill string down to 3366' & attempt to pull. Hole swabbing. 09:00 - 09:30 0.50 DRILL N DFAL INT1 M/U TDS. Establish circulation. Backream from 3366' to 9-5/8" csg shoe @ 2946' with 500 gpm @ 1800 psi & 80 rpm. 09:30 - 10:30 1.00 DRILL N DFAL INT1 Circulate bottoms-up x 2.5 with 590 gpm @ 2180 psi & 80 rpm. Flow check well-OK. Pump slug. Calculated EcD @ 2946' = 10.9 --- Actual ECD = 11.02 Note: Observed Hydrates breaking out of the mud while POOH. 10:30 - 12:00 1.50 DRILL N DFAL INT1 POOH from 2946' with drill string to top of BHA. 12:00 - 13:00 1.00 DRILL N DFAL INT1 Held PJSM. Continue POOH with BHA to LWD tool. Remove RA source. Finish POOH. UD ADN + MWD/LWD tools & bit. 13:00 - 13:30 0.50 DRILL N DFAL INT1 Clean & clear rig floor of excess drilling equipment & mud residue generated from trip. 13:30 - 15:00 1.50 DRILL N DFAL INT1 M/U BHA #4. P/U fresh MWD/LWD/ADN tools. Load RA source, TIH w/ DC's, HWDP & Ghost Reamer. Shallow Test Anadrill Tools. Everything working OK. 15:00 - 16:00 1.00 DRILL N DFAL INT1 TIH with 8-3/4" Steerable Drilling Assembly on 4" drill pipe to 2946'. 16:00 - 17:30 1.50 DRILL P INT1 Slip & cut 59' of drill line. Reset & test C-O-M. Service TDS. 17:30 - 17:45 0.25 DRILL N DFAL INT1 Circulate @ 570 gpm + 80 rpm & obtained benchmark ECD reading of 11.05 ppg. 17:45 - 20:00 2.25 DRILL N DFAL INT1 Continue TIH to 7101' with no problems. Hole in good shape. 20:00 - 21 :00 1.00 DRILL N DFAL INT1 M/U TDS. Establish circulation. Precautionary wash/ream to bottom @ 7206' with no problems. Circulate bottoms-up to clean hole before drilling ahead. Calculated ECD @ 7206' = 11.17 --- Actual ECD = 11.47 21 :00 - 00:00 3.00 DRILL P INT1 Drill 8-3/4" directional hole from 7206' to 7476. Slide as required to maintain inclination & azimuth. WOB = 15-25k RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 6000 FtLb Torque on Btm = 8500 FtLb GPM = 580 @ 3530 psi w/ 300-320 psi o iff. P/U 162k S/O 117k ROT 139k ART = 0.84 Hrs AST = 0.68 Hrs. ConnlSurvey hrs. = 2.18 hrs Drilling Time last 24 Hrs= 3.82 hrs Backream every stand at 590 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 7206' = 10.99 - Actual ECD = 11.10 NOTE: Top of HRZ @ 7319' MD/6355' KBTVD 10/28/2003 00:00 - 08:00 8.00 DRILL P INT1 Drill 8-3/4" directional hole from 7476' to 8340'. Slide as required to maintain inclination & azimuth. WOB = 15-25k Printed: 11/2412003 8:32:44 AM ) ') BP Operations Summary Report Page 7'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 Date From - To Hours Task Code NPT Phase Description· of Operations 10/28/2003 00:00 - 08:00 8.00 DRILL P INT1 RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 8-8.2k FtLb, Torque on Btm = 10-11 k FtLb GPM = 550 @ 3830 psi wI 300-320 psi Diff. P/U 171 k S/O 121 k ROT 140k Backream every stand at 580 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 8340' = 10.89 --- Actual ECD = 11.28 ART = 6.00 Hrs AST = 0.36 Hrs. Drilling Time last 24 Hrs= 6.36 hrs NOTE: Base of HRZ @ 7782'MD 16598' KBTVD Top of K-1 @ 7863'MD 16641' KBTVD NOTE: Kuparuk is wet and well is to be plugged back and sidetracked to a new BHL. 08:00 - 09:00 1.00 DRILL P INT1 Pump Hi-vis sweep surface to surface. 100 rpm, 580 gpm @ 3850 psi. Continue circulating an additional bottoms up. 171 klbs up, 121 klbs down, 140 klbs rotate. Calculated ECD = 10.89 ppg, Actual ECD = 10.91 ppg 09:00 - 09: 15 0.25 DRILL P INT1 Monitor well - static 09:15 -13:30 4.25 DRILL P INT1 POH wet 15 stands to 7008'.5-15 klbs drags through this interval. Pump dry job and continue POH, intermittent areas of 5-10 klb drag. 180 klbs up, 125 klbs off bottom. Monitored well at the csg shoe and again before pulling the BHA through the BOP - static with some hydrates breaking out. 13:30 - 14:00 0.50 DRILL P INT1 PJSM with Schlumberger and all rig personnel on laying down the BHA and unloading RA sources. 14:00 - 15:30 1.50 DRILL P INT1 Stand back jar and collar stand. PJSM. Unload RA source. LD BHA. 15:30 - 16:00 0.50 DRILL P INT1 Clean and clear rig floor. 16:00 - 17:00 1.00 DRILL C INT1 Rig service - top drive, drawworks and disc brake. 17:00 - 18:00 1.00 REMCM-C INT1 RU 3-1/2" tbg equipment to make up stinger assembly. 18:00 - 19:30 1.50 REMCM-C INT1 MU muleshoelplug catcher assembly. RIH with 24 jts of 3-1/2" 9.3# NSCT tbg. 19:30 - 20:00 0.50 REMCM-C INT1 RD tbg equipment. 20:00 - 21 :00 1.00 REMCM-C INT1 Continue RIH with 3-1/2" tbg stinger on 4" DP to csg shoe at 2946'. 21 :00 - 22:30 1.50 REMCM-C INT1 Circulate and condition mud at the csg shoe. 70 klbs up, 63 klbs down. 22:30 - 00:00 1.50 REMCM-C INT1 Continue RIH with 3-1/2" tbg stinger on 4" DP. 10/29/2003 00:00 - 01 :30 1.50 REMCM-C INT1 Cont RIH with cementing stinger on DP. Wash to bottom at 8340'. 01 :30 - 03:30 2.00 REMCM-C INT1 Circ & cond mud - 550 gpm @ 3150 psi. 03:30 - 03:45 0.25 REMCM-C INT1 PJSM prior to pumping first cement abandonment plug. ~ 03:45 - 04:30 0.75 REMCM-C INT1 Pump 13.5 bbl water ahead. Test lines to 3500 psi. Pum 44. bbls (215 sx) Class 'G' slurry at 15.8 ppg. Pump 1.5 bbl er behind plug to balance and displace with 75 bbl mud at 7 bpm dropping to 2 bpm for last 20 bbls. Calc plug 8340'·7890'. - 04:30 - 05:00 0.50 REMCM-C INn RD cement line & head pin. Pull up out of cement plug to Printed: 11/2412003 8:32:44 AM ) ) BP Operations Summary Report Page 8 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 Date From -To Hours Task Code NPT Phase Description of Operations 10/29/2003 04:30 - 05:00 0.50 REMCM-C INT1 7700'. Calc Top of cement plug at 7890'. 05:00 - 06:30 1.50 REMCM-C INn Circ at 590 gpm @ 2800 psi. Circ out cement contaminated mud. 06:30 - 07:30 1.00 REMCM-C INT1 Monitor well. POH to 5700' for laying Form-a-Plug. 07:30 - 08: 15 0.75 REMCM-C INT1 Circ & thin mud prior to pumping FAP. MW inlout 10.2 ppg. 08:15 - 09:00 0.75 REMCM-c INT1 Switch to cementers. Pump 20 bbl1 0.2 ppg viscosified mud spacer followed by 20 bbl Form-a-Plug at 10.7 ppg. Follow with 2 bbl spacer to balance and displace with 49 bbl mud to put plug in place from 5700'-5500'. 09:00 - 09:30 0.50 REMCM-c INT1 Kelly up. Pull up out of plug 3 stands at 60 fpm while pumping 3/4 bpm to push FAP out of DP. POH 2 more stands (5 total). 09:30 - 10:00 0.50 REMCM-C INT1 Circ 1 DP vol at 500 gpm to clear cement from pipe. Pump wiper dart to plug catcher at 300 gpm to wipe DP & stinger. 10:00 - 13:00 3.00 REMCM-C INT1 POH with DP and cement stinger. 13:00 - 14:00 1.00 REMCM-C INT1 RU 3-1/2" tbg equipment. Stand back tbg stinger in derrick. Recover wiper dart from cementing sub. 14:00 - 16:00 2.00 REMCM-C INT1 MU muleshoe and plug catcher. RIH with 3-1/2" tbg stands and 36 jts of tbg from pipe shed. 16:00 - 17:30 1.50 REMCM-C INT1 RD tbg equipment. Continue RIH with tbg stinger on DP to 5200' 17:30 - 18:00 0.50 REMCM-C INT1 Wash down to 5500', 450 gpm @ 1300 psi 18:00 -19:15 1.25 REMCM-C INT1 CBU at 5500', 450 gpm @ 1350 psi. Good Form-A-Plug returns on bottoms up. Circulate and condition mud for cement plug #2. 19:15 - 19:30 0.25 REMCM-C INT1 PJSM with OS, MI, Veco and all rig personnel on pumping plug #2. 19:30 - 21:00 1.50 REMCM-C INT1 Pump 5 bbls water ahead, test lines t~Si. Continue pumping 10.5 bbls water ahead. Pum 14 bls (705 sx) 15.8 ppg Class G slurry. Pump 1.5 bbls wate eheind to balance and diplace with 32 bbls mud at 7 bpm dropping to 2 bpm for last 20 bbls. Calc plug 5500'-4000'., -- 21 :00 - 22:00 1.00 REMCM-C INn RD cement line & head pin. Pull up out of cement plug to 3700'. Calc Top of cement plug at 4000'. 22:00 - 22:30 0.50 REMCM-C INT1 Circulate 3 x DP volume to clean residual cement from string. 500 gpm @ 1150 psi 22:30 - 23:00 0.50 REMcM-C INT1 POH to csg shoe at 2946' 23:00 - 00:00 1.00 REMCM-c INT1 WOC. Rig maint. - CO valves and seats on both pumps 10/30/2003 00:00 - 04:00 4.00 REMCM-C INn WOC. \ Rig Maint. - Cut and slip drilling line. Chg out valves and seats on both mud pumps. 04:00 - 04:30 0.50 REMCM-C INT1 RIH to 3500' 04:30 - 05: 15 0.75 REMcM-C INT1 Continue RIH washing down at 350 gpm @ 620 psi. Tag cement at 3698'. , 05: 15 - 06:30 1.25 REMCM-C INT1 Circulate and condition mud to prior to laying cement kick-off plug #3. 06:30 - 06:45 0.25 REMCM-C INT1 PJSM with cementers, rig crew, truck drivers on laying cement plug. Switch lines over to cementers. @ 06:45 - 07: 15 0.50 REMCM-C INT1 Test lines to 3500 psi. Pump 11.5 bbl water followed 8 bl (495 sx) Class 'G' densified slurry at 17.0 ppg. Plug len . calculated from 3698'-2750'. Pump 1.5 bbl water behind and displace with 20 bbl mud. 07:15 - 08:30 1.25 REMCM-C INT1 POH above calc top of plug slow 12 stands to 2570'. Circ and clear cement from hole and pipe. Printed: 11/24/2003 8:32:44 AM ) '} Page 9_ BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours Task Code NPT Phase 1 0/30/2003 08:30 - 09:30 1.00 REMCM-C INT1 09:30 - 10:00 0.50 REMcM-C INT1 10:00 - 13:30 3.50 REMCM-C INT1 13:30 - 14:00 0.50 REMCM-C INT1 14:00 - 15:00 1.00 BOPSURP INT1 15:00 - 17:30 2.50 BOPSUR P INT1 17:30 - 18:00 0.50 BOPSUR P INT1 18:00 - 19:00 1.00 STKOH P INT1 19:00 - 20:00 1.00 STKOH P INT1 20:00 - 00:00 4.00 STKOH P INT1 10/31/2003 00:00 - 01 :00 1.00 STKOH P INT1 01 :00 - 01 :30 0.50 STKOH P INT1 01 :30 - 02:30 1.00 STKOH P INT1 02:30 - 02:45 0.25 STKOH P INT1 02:45 - 03:30 0.75 STKOH P INT1 03:30 - 04:00 0.50 STKOH P INT1 04:00 - 05:30 1.50 STKOH P INT1 05:30 - 06:00 0.50 STKOH P INT1 06:00 - 06:30 0.50 STKOH P INT1 06:30 - 08:00 1.50 STKOH P INT1 08:00 - 08:30 0.50 STKOH P INT1 08:30 - 00:00 15.50 STKOH P INT1 Start: 10/20/2003 Rig Release: 11/22/2003 Rig Number: 9ES Spud Date: 10/22/2003 End: 11/22/2003 DescriptiOn of Operations Circulate 2 X DP volume at 500 gpm to clean cement from DP and stinger. Drop wiper dart and pump to catcher at 300 gpm. POH to cement stringer. RU 3-1/2" tbg equipment. LD 3-1/2" tbg stinger. Retrieve wiper dart. RD tbg equipment. Clean and clear rig floor. Flush stack with ported sub. RU BOPE test equipment. Test BOPE 250 psi low, 4000 psi high. Test Annular preventer to 250 psi low, 3500 psi high. Witness of BOP test waived by Chuck Scheve AOGCC. RD test equipment. Install wear bushing. Blow down all lines MU BHA #5, 8-3/4" cleanout assembly RIH to 2517' é§?";;-; MU top drive and wash down from 2517'. Tag cement 2583' Drill cement from 2583' to 2796'...... WOB = 15-20k RPM = 80 Torque off Btm = 2-4k FtLb, Torque on Btm = 3-4k FtLb GPM = 500 @ 1650 psi 90 klbs up, 75 klbs down, 83 klbs rotate Drill cement from 2796' to 2983'. ROP increased appeared to have sidetracked off of kick-off plug. WOB = 15-20k RPM = 80 Torque off Btm = 2.4k FtLb, Torque on Btm = 3.5-4k FtLb GPM = 500 @ 1660 psi 92 klbs up, 96 klbs down, 80 klbs rotate CBU, 600 gpm, 2175 psi, 100 rpm Pump 30 bbl viscosified spacer then displace to new 9.7 ppg LSND mud. 400 gpm @ 995 psi Monitor well - static POH to PU directional BHA. Monitor well prior to pulling DC's into BOP stack. Stand back HWDP and DC's. LD Jars. Break out bit. PU 8-3/4" directional BHA. PJSM with AnadriJI and all rig personnel on loading RA source. Load RA source. Continue MU BHA #6. Shallow test MWD. RIH to 2902" MU top drive and wash down to 2983'. Establish basline ECD's Drill 8-314" directional hole from 2983' to 5919'. Slide as required to maintain inclination & azimuth. WOB = 10-20k RPM = 80 Torque off - - k FtLb, Torque on Btm = 8.5k FtLb = 590 @ 3545 psi wI 280-300 psi Diff. P/U 150k S/O 103k ROT 122k Backream every stand at 590 gpm and 80 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Printed: 11/24/2003 8:32:44 AM SCHLUMBERGER Survey report Client...................: BP Exploration (AK) Inc. Field. . . . . . . . . . . . . . . . . . . .: Borealis Well. . . . . . . . . . . . _ . . . . . . . .: V-114 API number...............: 50-029-23178-00 Engineer. . . . . . . . . . . . . . . . .: M. St Amour Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 53.30 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 81.80 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: 204.16 degrees 28-0ct-2003 12:10:36 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 4 22-0ct-03 28-0ct-03 90 0.00 ft 8340.00 ft ----- Geomagnetic data ---------------------- - Magnetic model.........._: Magnetic date....... .....: Magnetic field strength..: Magnetic dec (+E/W-).....: Magnetic dip.............: ----- MWD survey Reference Reference G..... .... .....: Reference H..............: Reference Dip.. ..... .....: Tolerance of G...........: Tolerance of H...... .....: Tolerance of Dip.........: BGGM version 2003 22-0ct-2003 1150.99 HCNT 25.22 degrees 80.81 degrees Criteria --------- 1002.68 mGal 1,150.99 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/~) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+EjW-).....: 25.22 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.22 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 Cdrrection D=Dmag Magnetic Correction ' ,~ SCHLUMBERGER Survey Report 28-0ct-2003 12:10:36 Page 2 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 Carr (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 0.00 TIP None 2 257.92 0.66 188.16 257.92 257.91 1.43 -1.47 -0.21 1.49 188.16 0.26 MWD IFR MSA 3 287.55 0.77 186.67 29.63 287.54 1.78 -1.84 -0.26 1.86 188.00 0.38 MWD IFR MSA 4 381.25 2.32 208.52 93.70 381.21 4.27 -4.13 -1.24 4.31 196.68 1.74 MWD IFR MSA 5 473.70 4.74 210.44 92.45 473.47 9.94 -9.07 -4.07 9.94 204.15 2.62 MWD IFR MSA 6 565.46 7.84 212.40 91.76 564.67 19.90 -17.62 -9.34 19.94 207.93 3.39 MWD IFR MSA 7 657.43 10.67 215.33 91.97 655.43 34.47 -29.87 -17.63 34.68 210.55 3.12 MWD IFR.MSA 8 749.24 13.99 214.36 91.81 745.11 53.73 -45.97 -28.81 54.25 212.08 3.62 MWD IFR MSA .- 9 841.20 15.77 215.34 91.96 833.99 76.93 -65.34 -42.31 77.84 212.93 1.95 MWD IFR MSA 10 936.17 18.04 214.56 94.97 924.85 104.06 -87.98 -58.12 105.44 213.45 2.40 MWD IFR MSA 11 1029.75 22.17 212.33 93.58 1012.71 135.80 -114.84 -75.79 137.60 213.4Û 4.49 MWD IFR MSA 12 1120.79 25.06 211.25 91.04 1096.11 171.95 -145.85 -94.98 174.05 213.07 3.21 MWD IFR MSA 13 1214.58 27.00 211.29 93.79 1180.39 212.79 -181.03 -116.35 215.19 212.13 2.07 MWD IFR MSA 14 1309.05 27.89 211.55 94.47 1264.22 255.98 -218.18 -139.05 258.72 212.51 0.95 MWD IFR MSA 15 1402.90 28.41 211.94 93.85 1346.97 299.87 -255.83 -162.34 302.99 212.40 0.59 MWD IFR MSA 16 1494.98 29.78 212.38 92.08 1427.43 344.21 -293.73 -186.18 347.77 212.3:7 1.51 MWD IFR MSA 17 1591.68 30.29 212.11 96.70 1511.15 392.13 -334.67 -212.00 396.17 212.35 0.55 MWD IFR MSA 18 1684.09 29.77 212.49 92.41 1591.15 437.91 -373.76 -236.71 442.42 212.35 0.60 MWD IFR MSA 19 1778.40 29.19 212.69 94.31 1673.25 483.82 -412.87 -261.71 488.83 212.37 0.62 MWD IFR MSA 20 1870.19 28.53 213.23 91.79 1753.64 527.60 -450.04 -285.81 533.13 212.42 0.77 MWD IFR MSA 21 1961.11 29.87 213.90 90.92 1833.00 571.36 -487.00 -310.34 577.47 212.91 1.52 MWD IFR MSA 22 2054.48 29.79 214.49 93.37 1914.00 617.09 -~25.41 -336.44 623.90 212.63 0.33 MWD IFR MSA ~ 23 2148.61 31.01 212.33 94.13 1995.19 664.10 -565.18 -362.65 671.52 212.69 1.74 MWD IFR MSA 24 2241.64 30.74 211.67 93.03 2075.04 711.39 -605.66 -387.95 719.26 212.64 0.47 MWD IFR MSA 25 2335.80 30.20 211.30 94.16 2156.20 758.75 -646.38 -412.89 766.99 212.57 0.61 MWD IFR MSA 26 2429.70 29.60 212.08 93.90 2237.60 805.15 -686.21 -437.48 813.80 212.52 0.76 MWD IFR MSA 27 2523.88 29.24 211.72 94.18 2319.63 850.99 -725.48 -461.92 860.06 212.419 0.43 MWD IFR MSA 28 2617.94 29.48 212.09 94.06 2401.61 896.69 -764.63 -486.30 906.17 212.46 0.32 MWD IFR MSA 29 2711.16 29.07 211.75 93.22 2482.92 941.86 -803.32 -510.40 951.75 212.413 0.47 MWD IFR MSA 30 2804.57 29.90 212.28 93.41 2564.24 987.40 -842.30 -534.77 997.73 212.41 0.93 MWD IFR MSA SCHLUMBERGER Survey Report 28-0ct-2003 12:10:36 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 Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) ( deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- ==============;:= ------ -------- ------ ------- ------ -------- -------- ---------------- ------ 31 2897.91 30.20 213.95 93.34 2645.03 1033.56 -881.45 -560.31 1044.46 212.44 0.95 MWD IFR MSA 32 3013.85 28.73 214.11 115.94 2745.97 1089.75 -928.71 -592.22 1101.47 212.53 1.27 MWD IFR MSA 33 3105.87 29_04 214.58 92_02 2826.54 1133.50 -965.41 -617.30 1145.90 212.60 0.42 MWD IFR MSA 34 3199.12 30.65 214.09 93.25 2907.42 1179.17 -1003.73 -643.47 1192.28 212.6,6 1.75 MWD IFR MSA 35 3292.04 31.17 215.03 92.92 2987.15 1226.12 -1043.04 -670.55 1239.99 212.74 0.76 MWD IFR MSA 36 3386.33 30.99 215.54 94.29 30~7.90 1273.88 -1082.77 -698.67 1288.61 212.83 0.34 MWD IFR MSA 37 3478.86 30.63 214.75 92.53 3147.37 1320.40 -1121.52 -725.95 1335.97 212.9:1 0.59 MWD IFR MSA 38 3572.87 30.65 214.03 94.01 3228.26 1367.55 -1161.06 -753.01 1383.86 212.9'7 0.39 MWD IFR MSA ~ 39 3665.67 30.21 213.11 92.80 3308.28 1413.92 -1200.22 -779.00 1430.86 212.99 0.69 MWD IFR MSA 40 3759.44 29.64 213.34 93.77 3389.54 1460.12 -1239.35 -804.63 1477.64 212.9'9 0.62 MWD IFR MSA 41 3852.78 29.15 213.30 93.34 3470.87 1505.34 -1277.63 -829.80 1523.45 213.0'0 0.53 MWD IFR MSA 42 3946.05 29.10 212.12 93.27 3552.34 1550.23 -1315.83 -854.33 1568.85 212.99 0.62 MWD IFR MSA 43 4039.33 29.00 212.38 93.28 3633.89 1595.08 -1354.13 -878.50 1614.14 212.97 0.17 MWD IFR MSA 44 4132.72 30.54 210.75 93.39 3714.95 1641.06 -1393.65 -902.76 1660.49 212.93 1.86 MWD IFR MSA 45 4226.13 30.67 210.05 93.41 3795.35 1688.33 -1434.67 -926.82 1708.00 212.86 0.41 MWD IFR MSA 46 4318.42 30.43 209.83 92.29 3874.83 1735.00 -1475.32 -950.23 1754.85 212.7'9 0.29 MWD IFR MSA 47 4411.75 30.56 210.10 93.33 3955.25 1782.12 -1516.35 -973.89 1802.15 212.71 0.20 MWD IFR MSA 48 4504.45 30.40 209.98 92.70 4035.14 1828.90 -1557.05 -997.43 1849.13 212.64 0.18 MWD IFR MSA 49 4599.51 31.02 213.60 95.06 4116.88 1876.99 -1598.29 -1023.00 1897.65 212.62 2.05 MWD IFR MSA 50 4693.14 31.47 214.86 93.63 4196.93 1924.80 -1638.44 -1050.32 1946.19 212.6'6 0.85 MWD IFR MSA 51 4785.32 31.94 214.60 92.18 4275.35 1972.43 -1678.25 -1077.92 1994.61 212.7l 0.53 MWD IFR MSA 52 4879.09 30.86 214.48 93.77 4355.39 2020.48 -1718.50 -1105.62 2043.44 212.76 1.15 MWD IFR MSA c--,/· 53 4973.19 30.96 213.89 94-.10 4436.12 2068.08 -1758.48 -1132.78 2091.76 212.79 0.34 MWD IFR MSA 54 5067.15 31.11 213.20 93.96 4516.63 2115.87 -1798.86 -1159.55 2140.20 212.81 0.41 MWD IFR MSA 55 5160.59 31.75 214.02 93.44 4596.36 2163.94 -1839.43 -1186.52 2188.91 212.82 0.82 MWD IFR MSA 56 5253.15 30.84 213.27 92.56 4675.45 2211.36 -1879.45 -1213.16 2236.99 212.8~ 1.07 MWD IFR MSA 57 5346.29 30.54 214.06 93.14 4755.55 2258.24 -1919.02 -1239.51 2284.52 212.86 0.54 MWD IFR MSA 58 5438.48 30.42 213.91 92.19 4835.00 2304.32 -1957.79 -1265.65 2331.27 212.88 0.15 MWD IFR MSA 59 5532.52 30.42 213.51 94.04 4916.09 2351.27 -1997.40 -1292.08 2378.88 212.90 0.22 MWD IFR MSA 60 5625.71 30.37 213.52 93.19 4996.47 2397.80 -2036.72 -1318.11 2426.03 212.91 0.05 MWD IFR MSA SCHLUMBERGER Survey Report 28-0ct-2003 12:10:36 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 Azitn (deg/ tool Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) ( ft) ( deg!) 100f) type ( deg ) -------- ------ ------- ------ -------- -------- ---------------- -------------"'-- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5718.54 30.43 213.19 92.83 5076.54 2444.17 -2075.95 -1343.94 2473.01 212.92 0.19 MWD IFR MSA 62 5812.25 30.62 212.73 93.71 5157.26 2491.20 -2115.89 -1369.84 2520.60 212.912 0.32 MWD IFR MSA 63 5906.46 29.57 213.80 94.21 5238.77 2537.85 -2155.39 -1395.74 2567.84 212.93 1.25 MWD IFR MSA 64 5999.45 28.91 213.81 92.99 5319.92 2582.63 -2193.13 -1421.01 2613.26 212.94 0.71 MWD IFR MSA 65 6092.86 28.60 213.50 93.41 5401.81 2626.95 -2230.54 -1445.92 2658.19 212.95 0.37 MWD IFR MSA 66 6186.84 28.02 213.17 93.98 5484.54 2670.95 -2267.77 -1470.41 2702.76 212.96 0.64 MWD IFR MSA 67 6280.88 27.33 212.50 94.04 5567.83 2714.12 -2304.47 -1494.09 2746.43 212.96 0.80 MWD IFR MSA 68 6374.19 27.09 212.45 93.31 5650.81 2756.34 -2340.46 -1517.00 2789.10 212.95 0.26 MWD IFR MSA ~ 69 6467.90 30.52 209.77 93.71 5732.92 2801.15 -2379.14 -1540.27 2834.21 212.9:2 3.91 MWD IFR MSA 70 6561.42 32.87 202.75 93.52 5812.51 2850.18 -2423.17 -1561.89 2882.93 212.8ú 4.67 MWD IFR MSA 71 6654.21 34.53 199.05 92.79 5889.71 2901.55 -2471.26 -1580.21 2933.29 212.60 2.84 MWD IFR MSA 72 6747.36 36.57 192.91 93.15 5965.52 2955.09 -2523.29 -1595.04 2985.15 212.30 4.41 MWD IFR MSA 73 6840.95 38.29 188.23 93.59 6039.85 3010.33 -2579.18 -1605.42 3038.01 211.90 3.55 MWD IFR MSA 74 6934.59 41.10 184.86 93.64 6111.91 3067.30 -2638.58 -1612.18 3092.12 211.413 3.78 MWD IFR MSA 75 7027.57 48.23 181.27 92.98 6178.00 3128.17 -2703.79 -1615.54 3149.67 210.86 8.13 MWD IFR MSA 76 7121.47 51.99 178.07 93.90 6238.22 3193.69 -2775.80 -1615.07 3211.47 210.19 4.78 MWD IFR MSA 77 7215.41 53.63 175.48 93.94 6295.01 3260.12 -2850.51 -1610.85 3274.17 209.47 2.81 MWD IFR MSA 78 7309.18 55.35 174.94 93.77 6349.47 3326.90 -2926.57 -1604.47 3337.53 208.7"(; 1.89 MWD IFR MSA 79 7403.00 56.87 172.92 93.82 6401.79 3394.18 -3004.00 -1596.22 3401.76 207.9B 2.41 MWD IFR MSA 80 7496.15 59.63 171.06 93.15 6450.80 3461.21 -3082.42 -1585.17 3466.13 207.21 3.41 MWD IFR MSA 81 7588.91 59.38 170.70 92.76 6497.88 3528.03 -3161.34 -1572.50 3530.84 206.45 0.43 MWD IFR MSA 82 7681.40 59.09 169.69 92.49 6545.19 3593.94 -3239.65 -1558.97 3595.24 205.70 0.99 MWD IFR MSA J - 83 7774.83 57.90 170.81 93.43 6594.01 3660.05 -3318.16 -1545.47 3660.42 204.97 1.63 MWD IFR MSA 84 7868.75 57.55 169.10 93.92 6644.17 3725.72 -3396.34 -1531.62 3725.72 204.27 1.58 MWD IFR MSA 85 7962.64 61.00 169.82 93.89 6692.13 3792.07 -3475.68 -1516.87 3792.26 203.58 3.73 MWD IFR MSA 86 8055.90 60.74 167.89 93.26 6737.53 3858.54 -3555.60 -1501.13 3859.49 202.89 1.83 MWD IFR MSA 87 8150.18 60.87 168.04 94.28 6783.52 3924.96 -3636.10 -1483.97 3927.26 202.20 0.20 MWD IFR MSA 88 8243.25 60.81 167.62 93.07 6828.87 3990.44 -3715.54 -1466.83 3994.61 201.54 0.40 MWD IFR MSA 89 8266.19 60.75 167.79 22.94 6840.07 4006.54 -3735.11 -1462.57 4011.25 201.38 0.70 MWD IFR MSA 90 8340.00 60.75 167.79 73.81 6876.13 4058.40 -3798.05 -1448.95 4065.05 200.88 0.00 Projected to TD [(c)2003 IDEAL ID8 1C_01J ) ) bp V-114 Survey Report Schlumberuer Report Date: 28-0ct·03 Survey f DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 204.160° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 It Structure f Slot: V-Pad / V·114 (S-G) TVD Relerence Datum: KB Well: V-114 TVD Relerence Elevation: 81.80 ft relative to MSL Borehole: V-114 Sea Bed f Ground Level Elevation: 53.30 ft relative to MSL UWlfAPI#: 500292317800 Magnetic Declination: 25.237° Survey Name f Date: V-114/ October 28,2003 Total Field Strength: 57546.983 nT Tort f AHD fOOl f ERD ratio: 116.784° /4280.72 ft /5.783/ 0.623 Magnetic Dip: 80.807° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 08, 2003 Location LatfLong: N 701938.972, W 149 1557.365 Magnetic Declination Model: BGGM 2003 Location Grid NfE Y IX: N 5969895.720 ftUS, E 590514.780 ItUS North Relerence: True North Grid Convergence Ang Ie: +0.69122375° Total Corr Mag North .> True North: +25.237° Grid Scale Factor: 0.99990931 Local Coordinates Relerenced To: Well Head Measured Inclination Azimuth TVD Sub-Sea TVD Vertical NS EW DLS Build Rate Walk Rate Tool Face Northing Easting Latitude Longitude Depth Section (It) ( deg) (deg) (It) (It) (It) (It) (It) ( degf1 00 It ) ( degf100 It ) (degf100 It) (deg) (ItUS) (ltUS) 0.00 0.00 0.00 0.00 -81.80 0.00 0.00 0.00 0.00 0.00 0.00 ·171.84M 5969895.72 590514.78 N 70 19 38.972 W 149 15 57.365 257.92 0.66 188.16 257.91 176.11 1.43 -1.47 -0.21 0.26 0.26 0.00 -173.33M 5969894.25 590514.59 N 70 19 38.957 W 149 15 57.371 287.55 0.77 186.67 287.54 205.74 1.78 -1.84 -0.26 0.38 0.37 -5.03 -151.48M 5969893.88 590514.54 N 70 19 38.954 W 149 15 57.373 381.25 2.32 208.52 381.21 299.41 4.27 -4.13 -1.24 1.74 1.65 23.32 -149.56M 5969891.58 590513.59 N 70 19 38.931 W 149 15 57.401 473.70 4.74 210.44 473.47 391.67 9.94 -9.07 ·4.07 2.62 2.62 2.08 -147.60M 5969886.61 590510.82 N 70 19 38.883 W 149 15 57.484 565.46 7.84 212.40 564.67 482.87 19.90 -17.62 -9.34 3.39 3.38 2.14 10.90G 5969877.99 590505.65 N 70 1938.799 W 149 1557.638 657.43 10.67 215.33 655.43 573.63 34.47 -29.87 -17.63 3.12 3.08 3.19 ·4.04G 5969865.65 590497.52 N 70 19 38.678 W 149 1557.880 749.24 13.99 214.36 745.11 663.31 53.73 -45.97 -28.81 3.62 3.62 -1.06 8.52G 5969849.41 590486.53 N 70 19 38.520 W 149 1558.206 841 .20 15.77 215.34 833.99 752.19 76.93 -65.34 -42.31 1.95 1.94 1.07 -6.08G 5969829.88 590473.26 N 70 19 38.329 W 149 1558.600 936.17 18.04 214.56 924.85 843.05 104.06 ·87.98 -58.12 2.40 2.39 -0.82 -11.57G 5969807.05 590457.73 N 70 19 38.107 W 149 15 59.062 1029.75 22.17 212.33 1012.71 930.91 135.80 -114.84 -75.79 4.49 4.41 -2.38 -9.01G 5969779.98 590440.39 N 70 19 37.842 W 149 15 59.578 1120.79 25.06 211.25 1096.11 1014.31 171.95 -145.85 -94.98 3.21 3.17 -1.19 0.54G 5969748.75 590421.57 N 70 19 37.537 W 149 160.138 1214.58 27.00 211.29 1180.39 1098.59 212.79 -181.03 -116.35 2.07 2.07 0.04 7.78G 5969713.32 590400.63 N 701937.191 W 149 160.761 1309.05 27.89 211.55 1264.22 1182.42 255.98 -218.18 -139.05 0.95 0.94 0.28 19.66G 5969675.90 590378.39 N 70 19 36.826 W 149 16 1.424 1402.90 28.41 211.94 1346.97 1265.17 299.87 -255.83 -162.34 0.59 0.55 0.42 9.07G 5969637.97 590355.55 N 70 19 36.456 W 149 162.104 1494.98 29.78 212.38 1427.43 1345.63 344.21 -293.73 -186.18 1.51 1.49 0.48 -14.96G 5969599.79 590332.17 N 70 19 36.083 W 149 162.800 1591.68 30.29 212.11 1511.15 1429.35 392.13 -334.67 -212.00 0.55 0.53 -0.28 160.08G 5969558.55 590306.85 N 70 19 35.680 W 149 163.554 1684.09 29.77 212.49 1591.15 1509.35 437.91 -373.76 -236.71 0.60 ·0.56 0.41 170.46G 5969519.16 590282.61 N 70 19 35.296 W 149 164.275 1778.40 29.19 212.69 1673.25 1591.45 483.82 -412.87 ·261.71 0.62 -0.61 0.21 158.69G 5969479.77 590258.09 N 70 19 34.911 W 149 165.005 1870.19 28.53 213.23 1753.64 1671.84 527.60 -450.04 -285.81 0.77 -0.72 0.59 14.00G 5969442.31 590234.44 N 70 19 34.546 W 149 165.708 1961.11 29.87 213.90 1833.00 1751.20 571.36 -487.00 -310.34 1.52 1.47 0.74 105.50G 5969405.06 590210.37 N 701934.182 W 149 16 6.424 2054.48 29.79 214.49 1914.00 1832.20 617.09 -525.41 ·336.44 0.33 -0.09 0.63 -42.79G 5969366.34 590184.73 N 70 19 33.804 W 149 16 7.186 2148.61 31.01 212.33 1995.19 1913.39 664.10 -565.18 -362.65 1.74 1.30 -2.29 -128.84G 5969326.26 590159.01 N 70 19 33.413 W 149 16 7.951 2241 .64 30.74 211.67 2075.04 1993.24 711.39 -605.66 -387.95 0.47 -0.29 -0.71 -161.00G 5969285.48 590134.20 N 70 19 33.015 W 149 168.689 2335.80 30.20 211.30 2156.20 2074.40 758.75 -646.38 -412.89 0.61 -0.57 ·0.39 147.39G 5969244.47 590109.76 N 70 19 32.615 W 149169.417 2429.70 29.60 212.08 2237.60 2155.80 805.15 -686.21 -437.48 0.76 -0.64 0.83 -154.00G 5969204.35 590085.65 N 70 1932.223 W 149 16 10.135 2523.88 29.24 211.72 2319.63 2237.83 850.99 -725.48 -461.92 0.43 -0.38 -0.38 37.25G 5969164.79 590061.69 N 70 1931.837 W 149 16 10.848 2617.94 29.48 212.09 2401.61 2319.81 896.69 -764.63 -486.30 0.32 0.26 0.39 -158.08G 5969125.35 590037.79 N 70 1 9 31 .452 W 1491611.560 2711.16 29.07 211.75 2482.92 2401.12 941.86 -803.32 -510.40 0.47 -0.44 -0.36 17.68G 5969086.37 590014.16 N 701931.071 W 149 16 12.263 2804.57 29.90 212.28 2564.24 2482.44 987.40 ·842.30 -534.77 0.93 0.89 0.57 70.99G 5969047.10 589990.25 N 70 19 30.688 W 14916 12.975 2897.91 30.20 213.95 2645.03 2563.23 1033.56 -881.45 -560.31 0.95 0.32 1.79 177.00G 5969007.66 589965.19 N 70 19 30.303 W 149 16 13.720 3013.85 28.73 214.11 2745.97 2664.17 1089.75 -928.71 -592.22 1.27 -1.27 0.14 36.42G 5968960.02 589933.86 N 70 19 29.838 W 149 16 14.651 3105.87 29.04 214.58 2826.54 2744.74 1133.50 ·965.41 -617.30 0.42 0.34 0.51 -8.83G 5968923.02 589909.23 N 701929.477 W 149 16 15.383 3199.12 30.65 214.09 2907.42 2825.62 1179.17 -1003.73 -643.47 1.75 1.73 -0.53 43.28G 5968884.39 589883.52 N 701929.100 W 149 16 16.147 3292.04 31.17 215.03 2987.15 2905.35 1226.12 -1043.04 -670.55 0.76 0.56 1.01 124.58G 5968844.77 589856.92 N 701928.713 W 149 16 16.937 3386.33 30.99 215.54 3067.90 2986.10 1273.88 -1082.77 -698.67 0.34 -0.19 0.54 -132.00G 5968804.70 589829.29 N 70 19 28.323 W 1491617.758 3478.86 30.63 214.75 3147.37 3065.57 1320.40 -1121.52 -725.95 0.59 -0.39 -0.85 -87.19G 5968765.63 589802.48 N 70 1927.941 W 149 16 18.554 3572.87 30.65 214.03 3228.26 3146.46 1367.55 -1161.06 ·753.01 0.39 0.02 -0.77 -133.75G 5968725.77 589775.90 N 70 19 27.553 W 149 1619.344 3665.67 30.21 213.11 3308.28 3226.48 1413.92 -1200.22 -779.00 0.69 -0.47 -0.99 168.72G 5968686.30 589750.39 N 701927.167 W 149 1620.102 3759.44 29.64 213.34 3389.54 3307.74 1460.12 -1239.35 -804.63 0.62 -0.61 0.25 -177.72G 5968646.87 589725.23 N 701926.783 W 149 1620.850 3852.78 29.15 213.30 3470.87 3389.07 1505.35 -1277.63 -829.80 0.53 -0.52 -0.04 -95.49G 5968608.29 589700.53 N 70 19 26.406 W 149 1621.584 3946.05 29.10 212.12 3552.34 3470.54 1550.23 -1315.83 -854.33 0.62 -0.05 -1.27 128.49G 5968569.80 589676.46 N 70 19 26.030 W 149 1622.300 4039.33 29.00 212.38 3633.89 3552.09 1595.08 -1354.13 -878.50 0.17 -0.11 0.28 -28.43G 5968531 .21 589652.76 N 70 19 25.654 W 149 1623.006 4132.72 30.54 210.75 3714.95 3633.15 164106 -1393.65 -902.76 1.86 1.65 -1.75 -70.26G 5968491.41 589628.99 N 70 19 25.265 W 149 1623.713 4226.13 30.67 210.05 3795.35 3713.55 1688.33 -1434.67 -926.82 0.41 0.14 -0.75 -155.11G 5968450.11 589605.42 N 701924.862 W 149 1624.416 4318.42 30.43 209.83 3874.83 3793.03 1735.00 -1475.32 -950.23 0.29 -0.26 -0.24 46.62G 5968409.19 589582.50 N 70 19 24.462 W 149 1625.099 4411.75 30.56 210.10 3955.25 3873.45 1782.12 -1516.35 -973.89 0.20 0.14 0.29 -159.22G 5968367.88 589559.34 N 70 19 24.058 W 149 1625.789 4504.45 30.40 209.98 4035.14 3953.34 1828.90 -1557.05 -997.43 0.18 -0.17 -0.13 73.02G 5968326.90 589536.30 N 70 19 23.658 W 149 1626.476 4599.51 31.02 213.60 4116.88 4035.08 1876.99 -1598.29 -1023.00 2.05 0.65 3.81 55.99G 5968285.35 589511 .23 N 701923.252 W 149 1627.222 4693.14 31.47 214.86 4196.93 4115.13 1924.81 -1638.44 -1050.32 0.85 0.48 1.35 -16.32G 5968244.88 589484.39 N 701922.857 W 1491628.019 SurveyEditor Ver 3.1 RT-SP3.03-HF1.2 Bld( d031 rt-546 ) Plan V-114 (S-G)\V-114\V-114\V-114 Generated 11/25/20034:45 PM Page 1 of 2 Generated 11/25/20034:45 PM Page 2 of 2 Plan V-114 (S-G)\V-114\V-114\V-114 SurveyEditor Ver 3.1 RT-SP3.03-HF1.2 Bld( do31 rt-546 ) ') ) 4785.32 31.94 214.60 4275.35 4193.55 1972.43 -1678.25 -1077.92 0.53 0.51 -0.28 -176.74G 5968204.74 589457.28 N 701922.466 W 149 1628.825 4879.09 30.86 214.48 4355.39 4273.59 2020.48 -1718.50 -1105.62 1.15 -1.15 -0.13 -71.99G 5968164.17 589430.07 N 70 1922.070 W 149 1629.633 4973.19 30.96 213.89 4436.12 4354.32 2068.08 -1758.48 -1132.78 0.34 0.11 -0.63 -67.43G 5968123.86 589403.40 N 70 1921.677 W 149 1630.426 5067.15 31.11 213.20 4516.63 4434.83 2115.88 -1798.86 -1159.55 0.41 0.16 -0.73 34.10G 5968083.17 589377.12 N 70 1921.279 W 149 1631.207 5160.59 31.75 214.02 4596.36 4.514.56 2163.94 -1839.43 -1186.52 0.82 0.68 0.88 -157.14G 5968042.28 589350.64 N 70 1920.880 W 149 1631.994 5253.15 30.84 213.27 4675.45 4593.65 2211.36 -1879.46 -1213.16 1.07 -0.98 -0.81 126.99G 5968001.94 589324.49 N 701920.487 W 149 1632.771 5346.29 30.54 214.06 4755.55 4673.75 2258.24 -1919.02 -1239.51 0.54 -0.32 0.85 -147.69G 5967962.06 589298.62 N 701920.097 W 149 1633.540 5438.48 30.42 213.91 4835.00 4753.20 2304.32 -1957.80 -1265.65 0.15 -0.13 -0.16 -90.00G 5967922.98 589272.95 N 701919,716 W 149 16 34.302 5532.52 30.42 213.51 4916.09 4834.29 2351.27 -1997.40 -1292.08 0.22 0.00 -0.43 174.22G 5967883.06 589247.01 N 70 19 19.327 W 149 1635.073 5625.71 30.37 213.52 4996.47 4914.67 2397.80 -2036.72 -1318.11 0.05 -0.05 0.01 -70.38G 5967843.44 589221 .45 N 70 19 18.940 W 149 1635.833 5718.54 30.43 213.19 5076.54 4994.74 2444.17 -2075.95 -1343.94 0.19 0.06 -0.36 -51.08G 5967803.90 589196.10 N 70 19 18.554 W 149 1636.587 5812.25 30.62 212.73 5157.26 5075.46 2491.20 -2115.89 -1369.84 0.32 0.20 -0.49 153.40G 5967763.66 589170.69 N 70 19 18.161 W 149 1637.342 5906.46 29.57 213.80 5238.77 5156.97 2537.85 -2155.39 -1395.74 1.25 -1.11 1.14 179.58G 5967723.85 589145.27 N 701917.773 W 149 1638.098 5999.45 28.91 213.81 5319.92 5238.12 2582.63 -2193.13 -1421.01 0.71 -0.71 0.01 -154.45G 5967685.81 589120.46 N 701917.401 W 149 1638.835 6092.86 28.60 213.50 5401.81 5320.01 2626.95 -2230.54 -1445.92 0.37 -0.33 -0.33 -165.04G 5967648.11 589096.01 N 70 19 17.033 W 149 1639.562 6186.84 28.02 213.17 5484.55 5402.75 2670.95 -2267.77 -1470.41 0.64 -0.62 -0.35 -156.02G 5967610.59 589071.97 N 70 19 16.667 W 149 1640.276 6280.88 27.33 212.50 5567.83 5486.03 2714.12 -2304.47 -1494.09 0.80 -0.73 -0.71 -174.58G 5967573.61 589048.73 N 70 19 16.306 W 149 1640.967 6374.19 27.09 212.45 5650.81 5569.01 2756.34 -2340.46 -1517.00 0.26 -0.26 -0.05 -21.81G 5967537.34 589026.26 N701915.952 W1491641.636 6467.90 30.52 209.77 5732.92 5651.12 2801.15 -2379.14 -1540.27 3.91 3.66 -2.86 -60.52G 5967498.40 589003.46 N 70 19 15.572 W 149 1642.315 6561 .42 32.87 202.75 5812.51 5730.71 2850.18 -2423.18 -1561.89 4.67 2.51 -7.51 -52.59G 5967454.10 588982.38 N 70 19 15.139 W 1491642.945 6654.21 34.53 199.05 5889.71 5807.91 2901.56 -2471.26 -1580.21 2.84 1.79 -3.99 -62.78G 5967405.80 588964.64 N 70 19 14.666 W 149 1643.480 6747.36 36.57 192.91 5965.52 5883.72 2955.09 -2523.29 -1595.04 4.41 2.19 -6.59 -60.71 G 5967353.61 588950.45 N 701914.154 W 149 1643.912 6840.95 38.29 188.23 6039.85 5958.05 3010.33 -2579.18 -1605.42 3.55 1.84 -5.00 -38.76G 5967297.60 588940.74 N 70 19 13.604 W 149 1644.214 6934.59 41.10 184.86 6111.91 6030.11 3067.30 -2638.58 -1612.18 3.78 3.00 -3.60 -20.79G 5967238.13 588934.69 N 70 19 13.020 W 149 1644.411 7027.57 48.23 181.27 6178.00 6096.20 3128.17 -2703.79 -1615.54 8.13 7.67 -3.86 -34.18G 5967172.89 588932.12 N 70 19 12.379 W 149 1644.509 7121.47 51.99 178.07 6238.22 6156.42 3193.69 -2775.80 -1615.07 4.78 4.00 -3.41 -52.31G 5967100.89 588933.46 N 70 19 11.670 W 149 1644.495 7215.41 53.63 175.48 6295.01 6213.21 3260.12 -2850.51 -1610.85 2.81 1.75 -2.76 -14.49G 5967026.25 588938.58 N 70 19 10.936 W 149 1644.371 7309.18 55.35 174.94 6349.47 6267.67 3326.90 -2926.57 -1604.47 1.89 1.83 -0.58 -48.38G 5966950.28 588945.88 N 70 19 10.188 W 149 1644.185 7403.00 56.87 172.92 6401.79 6319.99 3394.18 -3004.00 -1596.22 2.41 1.62 -2.15 -30.31G 5966872.96 588955.06 N 70 199.426 W 149 1643.943 7496.15 59.63 171.06 6450.80 6369.00 3461.21 -3082.42 -1585.17 3.41 2.96 -2.00 -128.96G 5966794.69 588967.06 N 70 198.655 W 149 1643.620 7588.91 59.38 170.70 6497.88 6416.08 3528.03 -3161.34 -1572.50 0.43 -0.27 -0.39 -108.74G 5966715.93 588980.68 N 70 197.879 W 149 1643.250 7681 .40 59.09 169.69 6545.19 6463.39 3593.94 -3239.65 -1558.97 0.99 -0.31 -1.09 141.55G 5966637.80 588995.15 N 70 197.109 W 149 1642.855 7774.83 57.90 170.81 6594.01 6512.21 3660.05 -3318.16 -1545.47 1.63 -1.27 1.20 -104.06G 5966559.47 589009.59 N 70196.337 W 149 1642.461 7868.75 57.55 169.10 6644.17 6562.37 3725.72 -3396.34 -1531.62 1.58 -0.37 -1.82 10.36G 5966481 .46 589024.38 N 70195.568 W 149 1642.056 7962.64 61.00 169.82 6692.13 6610.33 3792.07 -3475.68 -1516.87 3.73 3.67 0.77 -99.24G 5966402.32 589040.09 N 70 194.787 W 149 1641.625 8055.90 60.74 167.89 6737.53 6655.73 3858.55 -3555.60 -1501.13 1.83 -0.28 -2.07 45.24G 5966322.60 589056.79 N 70 194.001 W 149 1641.165 8150.18 60.87 168.04 6783.52 6701.72 3924.96 -3636.10 -1483.97 0.20 0.14 0.16 -99.39G 5966242.32 589074.92 N 70 193.210 W 149 1640.664 8243.25 60.81 167.62 6828.87 6747.07 3990.44 -3715.55 -1466.83 0.40 -0.06 -0.45 112.06G 5966163.10 589093.01 N 70192.428 W 149 1640.164 8266.19 60.75 167.79 6840.07 6758.27 4006.54 -3735.11 -1462.57 0.70 -0.26 0.74 O.OOG 5966143.59 589097.51 N 70 192.236 W 149 1640.039 8340.00 60.75 167.79 6876.13 6794.33 4058.40 -3798.05 -1448.95 0.00 0.00 0.00 O.OOG 5966080.82 589111.88 N 70 19 1.617 W 149 1639.641 LeQal Description: Northing eV) [ftUS] EastinQ eX) [ftUS] Surface: 4649 FSL 1789 FEL S11 T11N R11E UM 5969895.72 590514.78 BHL: 850 FSL 3241 FEL S11 T11N R11E UM 5966080.82 589111.88 ) ) Q103'-)Sa MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-114 Date Dispatched: 29-0ct-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 RECI:I~JE1) DEC 01 2003 Alaska on & Ga.s Con&.. COmmi~on Anchomg~ _ ~... Please sign and return to: James H. Johnson Received By: ~O ~.t. ,V'\... ~l. (, C"Q...':" 'â JY"'...- BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1 Dec '97 ·K~D VV\.éb vuC?A- ,ð 17- 'ì ( W'~5 ') STATE OF ALASKA') ALASKA 011_ 'AND GAS CONSERVATION COMI"....,SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: 181 Abandon o Alter Casing o ChanQe Approved ProQram 2. Operator Name: BP Exploration (Alaska) Inc. ,3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): o Suspend o Repair Well o Pull TubinQ o Operation Shutdown 0 Perforate o Plug Perforations 0 Stimulate o Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: IBI Development D Exploratory D Stratigraphic D Service o Variance o Time Extension ______ o Annular Disposal 5. Permit To Drill Number. 203-152 ,/ 6. API Number: / 50- 029-23178-00-00 o Other 99519-6612 Plan RKB = 82.3 9. Well Name and Number: PBU V-114 / 8. Property Designation: 10. Field I Pool(s): ADL 028245 Prudhoe Bay Field 1 Borealis Pool Total Depth MD (ft): 8340 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 6876 8340 6876 Length Plugs (measured): N/A Burst . Junk (measured): N/A Collapse 108' 2946' 20" 9-5/8" 108' 2946' 108' 2699 5750 3090 Perforation Depth MD (ft): N/A Packers and SSSV Type: None Perforation Depth TVD (ft): N/A Tubing Size: N/A Tubing Grade: N/A Packers and SSSV MD (ft): None Tubing MD (ft): N/A '12. Attachments: IBI Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: October 28,2003 16. Verbal Approval: ~ate: 10/28/20~ Commission Representative: Winton Aubert 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Nam¿;tLOW Crane Title Senior Drilling Engineer ,ç / Prepared By Name/Number: Signature .... ( ,_~~ /~,,_ P-h. _ one 564-4089 Date j'::::>-d-'1- 0') Terrie Hubble, 564-4628 I Commission Use Only I 13. Well Class after proposed work: D Exploratory IBI Development D Service 15. Well Status after proposed work: DOil DGas D WAG D GINJ D Plugged DWINJ IBI Abandoned D WDSPL Contact Neil Magee, 564-5119 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 3 () 3 - 3;}"-..b o Plug Integrity D BOP Test o Mechanical Integrity Test D Location Clearance ~:IL; .. . 'lii: . , " '. ::'::' .. ~ It..l.1.:l::; c: ~= ~ i~~ Other: OCT 2~ 9 Subsequent form required 10- 4-0 7 ~P¡.J Oil 8t Gas COrls. Ä.nci'¡Of2'1:;,a Approved By: ~ Form 10-403 Revised 2/2003 / ~~ BY ORDER OF COMMISSIONER THE COMMISSION ~Bft ORIGINAL Date /0/2)/2Y< slm~ Infoup~te t'tt'Tð.. " bp ) ') To: Winton Aubert - AOGCC Date: October 28, 2003 From: Neil Magee - BPXA GPB Drilling & Wells Subject: Reference: V-114 Abandonment Abandonment of Well and Preparation for Sidetrack Operations to V-114A API # 50-029-23178 Dear Mr. Aubert, Borealis Well V-114 (Permit #203-152) encountered an OWC significantly higher than anticipated. difficulty which will require abandonment of the intermediate hole. The top Kuparuk came in 22 feet low to prognosis at 6622 tvdss. In addition, the amount of D shale, which is the seismic reflector for the Kuparuk, was 27 feet thick versus 10 feet in the prognosis. This had the cumulative effect of pushing the top Kuparuk C4 (reservoir) down a total of 39 feet to 6650 tvdss, which puts it very close to the Borealis Field oil-water contact, which is typically 6650-6660 tvdss. Only 4 feet of pay could be confirmed in the V-114 pilot hole and an absolute maximum of 10 to 15 feet of pay could be projected in the horizontal section. Thus the horizontal portion of V-114 was deemed to be extremely high risk and the decision was made to plug back and sidetrack to the V-114A horizontal injector Plans are now underway to abandon the intermediate section of this wellbore and sidetrack the well to a new Kuparuk target location some 2100' away. Below is an outline of the proposed abandonment of V- 114. Also enclosed is a schematic of the proposed plug-back. The abandonment operations are expected to take 48 hours to complete. I will be submitting a outline V- 114A Permit to Drill by tomorrow close of business, however I have included our directional prognosis to this new location as an attachment. /~ If you have any questions or require any additional information, please contact me at 564-5119. Scope Abandonment Operations: · RIH to 8340' with 1800' 3-1/2" cement stinger on 4" DP cementing assembly. (Cement stinger to have bull-nosed perforated joint on bottom to catch Baker Drill Pipe Wiper Plug.) Circulate and condition mud and wellbore until the hole is clean and mud is properly conditioned (reciprocate to help clean hole and break mud gels). · Condition mud as required to ensure uniform weight prior to setting abandonment plug. Circulate one hole volume minimum. · Spot a balanced 15.8 ppg 'G' cement P&A plug from TD to ' to -7,893' (approximately 100' above the Top Kuparuk). Plug volume should be based upon gauge hole plus 300/0. (BHST=158 F Static) Pull DP above top cement plug (at rate as per RP) and circulate hole clean the long way immediately above the planned top of plug. Displace with Baker Drill Pipe Wiper Plug. POOH to -5,775' and circulate and condition mud. NOTE: The AOGCC is requested a variance from tagging this bottom plug as long ..,./' as no losses are seen while spotting the plug or circulating (to be confirmed) Spot a balanced 10.5 ppg Form-A-Plug pill from 5,775' to -5,500' to act as a base for cement plug #2. Plug volume should be based upon gauge hole plus 30% through this section. Pill / · · /' V-114 Abandonment ') ) thickening time should be based upon a BHST at Top of Plug = 100 deg F. Pump a 10.5 ppg viscosified spacer ahead and behind the Form-A-Plug pill (to be confirmed). Rotate pipe while spotting the pill. Pump at 300 gpm (higher if achievable) while displacing pill and slow pump rates to -6 bpm as Form-A-Plug is spotted around the pipe. Pull DP up to -5200' and circulate minimum volume required to get any remaining Form-A-Plug out of DP. Wait on Form-A- Plug to set for 4 hrs from the time the plug was spotted. · RIH to -5,200' and start to wash down looking for top of plug. Verify presence of plug with weight or pump pressure increase or surtace samples. Exercise caution to not plug the drill string. Wash to a maximum depth of 5600' MD, PU -50' and circulate bottoms up looking for signs of Form-A- Plug. · Condition mud as required for spotting the abandonment plug No.2. Circulate one hole volume at a minimum, and be sure mud weight is uniform throughout well before spotting plug. · Position DP immediately above the Form-A-Plug plug and spot a balanced 15.8 ppg 'G' cement plug from 5,500' to 4000' (500' above Schrader Ma sand). Plug volume should be based upon / gauge hole plus 300/0 excess. (BHST at TOC =80 deg F). Pull DP -300' above top cement plug (at rate as per RP) and drop Baker Drill Pipe Wiper to clean cementing string. · POOH and retrieve Baker Dart. RIH while WOC for 5 hours. RIH to 3500 and begin washing down to 4000'. Do not allow DP stinger to approach TOC without circulation. Circulate and condition mud prior to pumping cement plug No.3. · Spot a balanced 17.0 ppg 'G' cement P&A plug from 4,000' to -2,750' (approximately 200' inside , 9-5/8" casing.) Plug volume should be based upon gauge hole plus 300/0 excess. (BHST=58 /' F Static) Pull DP above top cement plug (at rate as per RP) and circulate hole clean the long way immediately above the planned top of plug. Displace Baker Drill Pipe Wiper Plug. · POOH and lay down cement stinger. Test BOP's and flush BOP stack V-114 Abandonment TREE: N/A WELLHEAD: 135/8" - 5M FMC SH 9-5/8",40.0 #Ift, L-80, BTC ~:' I 2946' I TD of 8-314" hole 18,340' I ) V-114 Proposed Abandonment 10.2 PPG ppg WBM .'. .,", . .., Top of 17.0 ppg Kick-Off Plug at I 2,750' I (0% Excess) t ", <.c'Ú:O:'P¡;g:cerriini<:'-''- . Kfck-off.Plug· . . .30%:~C~, ' . . . Top of 15.8 ppg P&A Plug at I 4,000' I (30% Excess) Top Schrader Me @ -4,502' MD Base Schrader ObI @ -5,406' MD Top of Form-A-Plug pill at 5,506' I 10.5 ppg Form-A-Plug Bottom of Form-A-Plug pill at I I 5,706' Top of 10.2 ppg WBM at 10.2 ppg Water Base Mud , Top of 15.8 ppg P&A Plug at I 7,893' Top HRZ @ -6.549' 15.8 ppg Çemé.nt " Top Kuparuk Reservoir at 7,993' I "- - Date 1 0/28/03 Rev By Comments NM Proposed Abandonment Borealis WELL: V-114 API NO: 50-029-23178 . ) GL Elevation = 44.1 ' Nabors ges KB = 28.5' KBE = 76.4' BP Alaska Drilling & Wells . ) .]l[L if ~ ®~rl7 ® l-/ f J\\ LS Lr\\ ~ u \\ Lr\\ } A.ItA.~1iA OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit V-114 BP Exploration (Alaska), Inc. Permit No: 203-152 Surface Location: 4649' NSL, 1789' WEL, Sec. 11, T11N, RIlE, UM Bottomhole Location: 1753' SNL, 4667' WEL, Sec. 14, T11N, RIlE, UM Dear Mr.Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit 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 permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~;..-v¿ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this--ª- day of September, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~..¡ Glr ~'3(¿"l'J , STATE OF ALASKA \ ALASKA\_,.¿ AND GAS CONSERVATION COtv..AISSION PERMIT TO DRILL 20 MC 25.005 II 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: 4649' NSL, 1789' WEL, SEC. 11, T11N, R11E, UM Top of Productive Horizon: 1207' NSL, 3318' WEL, SEC. 11, T11N, R11E, UM Total Depth: 1753' SNL, 4667' WEL, SEC. 14, T11 N. R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-590515 y-5969896 Zone-ASP4 16. Deviated Wells: Kickoff Depth 1 ~'~ '"q~,$¡hg,pr()gr~lril~, I:::,'" ¡".. ·"1,':1" :Size;'I' II" ':. ~ II: Hole Casing 30" 20" 12-1/4" 9-518" 8-3/4" 7" 6-1/8" 4-1/2" 1 b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: a Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 12379' TVD 6726' 7. Property Designation: ADL 028245 II Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU V-114 12. Field 1 Pool(s): Prudhoe Bay Field I Borealis Pool 8. Land Use Permit: 13. Approximate Spud Date: 10/15/03 14. Distance to Nearest Property: 3400' 9. Acres in Property: 2560 Weight 91.5# 40# 26# 12.6# Grade H-40 L-80 L-80 L-80 CouplinQ Weld BTC BTC-M IBT-M Length 80' 2965' 8290' 4429' 10. KB Elevation Plan RKB 15. Distance to Nearest Well Within Pool (Height aboveGL): = 82.3 feet V-117 is 3089' away at 7951' 17. Anticipated pressure (see 20 MC 25.035) Max. Downhole Pressure: 3464 psig. Max. Surface Pressure: 2796 psig 'l'II::';'~;¡':':::.I:' ";:I:IØ"ª~~'~Ylp~"1 C,åmèht,I;',' '\. ".1,; ':....I,I,'.:··~,~,::,":,.:,.~I:.:,,:.'::,I,II.·'II:::(6'~f!:::oh:sa~ks)I:'.:':··:,·1 '1: ,I, .... ' ' (including staQe data) 260 sx Arctic Set (Approx.) 506 sx AS Lite, 290 sx Class 'G' 240 sx Class 'G', 157 sx Class 'G' 24-i'-sx Class 'G' 'lIP'! iLlt1A- 400 ft Maximum Hole Angle 96° MD TVD Surface Surface Surface Surface Surface Surface 7950' 6682' MD 110' 2965' 8290' 12379' TVD 110' 2706' 6860' 6726' 1'9." ,1···PR.Ês'gNíW,E:U~,.'ctÓ.NÐ' 'rlàl~$Øtt.1~~~¥,äb',b~i"qØrri.P,l~t~.~:':fHbl~~ijrii'l;;~N'~:'R~f~~trYIPp'~~~ti9n~)I·.:'I! ,',... ...:. Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing, Structural Conductor Surface Intermediate Production liner Léngth '··Size' . :CemeAfVölUme . .MD' TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments a Filing Fee 0 BOP Sketch a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Property Plat 0 Diverter Sketch 0 Seabed Report a Drilling Fluid Program a 20 AAC 25.050 Requirements Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed N~me . L ell Crane Title Senior Drilling Engineer Signatur~ ~ ¡U Phone 564-4089 Date 8·2,f, O~ l Commission Use Only Permit To Drill API Number: Permit APpro0val 0 I r- ~ I -~ (7 <:: Number:.:.2d3 - ~ Z. 50- 02·9-- ;? J I / G' Date: / ~ 03 Conditions of Approval: Samples Required DYes ,g¡ No Mud Log Require Hydrogen Sulfide Measures D Yes ~ No Directional Survey Required Other: ',€si- Eo r E -f·e I-{.oC{) pSi. Contact Neil Magee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564-4628 See cover letter for other requirements DYes ~No BYes DNo Approved Bv: ~ Form 10-401 Re~ised 3/2~ ~~ ~~O R ~~~lîSjO~ E~ , ~ ~ I't ,_ BY ORDER OF THE COMMISSION Date o 103d:>.7 Submit In Duplicate ) ) IWell Name: IV-114 Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): I Producer Surface Location: As-Built (Slot S-G) Target Location: Kuparuk Bottom Hole Location: x = 590,514.78' Y = 5,969,895.72' / 46481 FSL, 1788IFEL,Sec. 11,T11N,R11E X = 589,029.54' Y = 5,966,436.56' /" 1201' FSL, 33181 FEL, Sec. 11, T11N, R11E - X = 587,720.00' Y = 5,963,460.00' ~- 35261 FSL,4666IFEL,Sec. 14,T11N,R11E Top of productive interval in V-114 is 3089 ft away from V-117 the nearest wellbore/ The well aproaches to within 3400' ft of the nearest Prudhoe Bay property line. 1 AFE Number: I BRD5M???? I I Estimated Start Date: 110/15/2003 1 1 MD: 112379' I /-", TVD: 16726' I RiQ: I Nabors 9ES ./ I OperatinQ days to complete: 128.0 1 RT/GL: 128.5' I I RKB: 182.3' I Well DesiQn (conventional, slim hole, etc.): 13 String Horizontal Producer I Objective: 1 Cemented liner completion into the Kuparuk formation. Casing /Tubing Program: Hole Csgl WtlFt Grade Co~ Length Top Btm Size TbQ O.D. / MDITVD MDITVD bkb 30" 20" 91.5# H-40 WLD 80' GL 11 0/11 0 12 %" 9 5/8"* 40# L-80 BTC 2965' GL 2965/2706' 83Jt 711 ** 26# L-80 BTC-m 8290' GL 8290'/6860' 6-1/8" 4-1 /2" 12.6# L-80 IBT-M 4429' 7950' 12379'/6726' Tubing 3 Y211 9.2# L-80 IBT-M 7850' GL 7850'/6630' * 9-5/8" Burst 5,750 psi, collapse 3,090 psi / ** 7" Burst 7,240 psi, collapse 5,410 psi V-114 Drilling Program- AOGCC Page 1 ) ) Mud Program: 12 'IA" Surface Hole (0-2965'): Densitv (ppg) 8.5 - 9.2 9.0 - 9.5 9.5 max / Initial Base PF to top SV SV toTO Viscosity (seconds) 250-300 200-200 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100ft:¿) (mls/30min) 45 - 70 NC 35 - 45 < 8 25 - 35 < 8 9.0- 9.5 9.0- 9.5 9.0- 9.5 8 %" Intermediate Hole (2965' - 8290'): LSND Interval Density Tau 0 YP PV pH API (ppg) Fi It rate Upper 9.7 4-7 25-30 1 0-15 9.0-9.5 6-8 Interval Top of HRZ 10.1 / 3-7 22-28 1 0-15 9.0-9.5 4-6 to Kup 6-1/8 " Production Hole (7950' - 12379'): Interval Density Tau 0 YP (ppg) " ToTO 10.1 /' 4-7 30 PV pH FloPro API Fi It rate 4-6 10 9.0-9.5 Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1888' 600 4" 17.5# 90 1800 10.0 N/A 18,18,18,16 .942 1888'-2965' 680 4" 17.5# 110 3200 10.2 N/A 18,18,18,16 .942 Intermediate Hole: 8 3/4" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2965' - 8290' 580 4" 17.5# 240 4200 11.1 N/A 3x14,3x15 .969 Production Hole: 6 1/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 7950' - 12379' 300 4" 17.5# 200 3200 10.8 N/A 6x10 .460 V-114 Drilling Program- AOGCC Page 2 Directional: Ver. Anadrill(P5/P11 )(Slot SG) KOP: 400' Maximum Hole Angle: Close Approach Wells: Logging Program: Surface Intermediate Hole Production Hole Formation Markers: Formation Tops SV6 SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 Na WS1 Oa Obf Base CM2 (Colville) Fault THRZ BHRZ (Kalubik) K-1 TKUP V-114 Drilling Program- AOGCC ) ) 96 deg at 8,340' MD All wells pass 1/200 minor risk criteria. V-109 - 29' @ 650' 1 /' V-113-58' @750' S Gyro surveys required for kick-off due to proximity of V-1 09. IFR-MS corrected surveys will be used for survey validation. Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: TVDss 895 1555 1670 1700 2045 2225 2525 2875 3225 3685 3970 4190 4345 4710 5075 6160 6330 6530 6560 6600 MWD 1 GR None None MWD/GR/AZM DEN/NEU/RES/PWD(Real Time) MWD/PWD/GR/RES/NEU/AZM DENS/AIM(Real Time) None None Estimated pore pressure, PPG Q,7 Hydrocarbon bearing, 8.7 ppg EMW Hydrocarbon bearing, 8.6 ppg EMW ./ Hydrocarbon bearing, 8.5 ppg EMW Hydrocarbon bearing, 8.3 ppg EMW 1°- \ Page 3 ) ) Kuparuk C LCU (Kuparuk B) Kuparuk A TD Criteria 6610 6680 N/A Hydrocarbon Bearing, 3441 psi, 9.9 ppg EMW Hydrocarbon Bearing, 3464 psi 9.9 ppg EMW Obtain logs across entire KupC interval Inte~rity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe 20' min from 7" shoe Test Type LOT Intermediate Casing Shoe FIT EMW 12.6 ppg EMW Target 12.0 ppg EMW Target based on 10.1 ppg MW and a worst case 11.5 ppg drilling ECO. / /' 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. CasinÇ[ Size 19-5/8" Surface I Basis: Lead: Based on conductor set at 110', 1778' of annulus in the permafrost @ 2500/0 excess and 327' of open hole from top of tail slurry to base permafrost @ 300/0 excess. Lead TOC: To surface Tail: Based on 750' MO(>500'TVO) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2215' MD Total Cement Volume: Lead 400 bbl I 2244 ft~'J I 506 sks of Dowell ARTICSET Lite at 10.7 ppg and 4,44 disk. Tail 60 bbl / 336 ft~; / 290 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 disk. ~. The 7" production casing will be cemented as follows: Casinq Size 17" Production Longstring I Basis: Tail: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 7,450' MD Lead: Based on TOC 500' above top of Schrader Ma +30% excess volume Cement Placement: From 7,450' MD to 4030' MD (500' above Schrader Ma sand) Total Cement Volume: Lead 119 bbls / 667 ff I 240 sks of Dowell Premium "G" at 12.5 ppg and 2.79 disk Tail 32 bbls /180 ff> I 157 sks of Dowell G at 15.8 ppg and 1 .16cf/sk ~. The 4-1/2" production liner will be cemented as follows: Casinq Size 14-1/2" Production Longstring I Basis: Tail: Based on TOe 150' above top of production liner (with 4" DP) + 30% excess + 80' shoe Cement Placement: From shoe to 7,800' MD ....,,-/ V-114 Drilling Program- AOGCe Page 4 Total Cement Volume: V-114 Drilling Program- AOGCC ) ) Lead 45 bbls I 252 ff I 217 sks of Dowell Premium "G" at 15.8 ppg and 1.16 disk /' Page 5 ) ) Well Control: Surface hole will be drilled with a diverter. The intermediate/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 of 3500 psi for casing integrity considerations, 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: · Planned BOP test pressure: · Planned completion fluid: 3464 psi @ 6680' TVDss - Kuparuk B 2796 psi @ su rface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) '-l0oo ~6t\- ..35Ðð psi (The casing and tubing will be tested to 3500) 10.1 ppg filtered brine / 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 08-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to 08- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V -114 Drilling Program- AOGCC Page 6 ') ) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed in May 2003. (Slot S-G) 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and riser. PU 4" OP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWO/LWO (page 5) and directionally drill surface hole to approximately 100' TVD below the SV1 Sands. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the Permafrost. 4. Run and cement the 9-5/8", 40# surface casing back to surface. A Tam port collar will be run as a /' contingency if surface drilling is problematic. 5. NO riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. /,. 6. MU 8-~4" drilling assembly with MWO/LWO (page 5) 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. 8. Drill to +/-100' above the HRl, ensure mud is in condition to 10.1 ppg and perform short trip as / needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRl. 9. Drill ahead to intermediate TO at approximately 90'TVO below top Kuparuk C in order to log entire Kup C interval. (TO estimated at 8290' MO). 10. Run and cement the 7" production casing. Test casing to 3500 psi. ".. 11. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 12. RU e-line. RIH with GR-CCUJunk basket to float collar. MU 7" ElSV and RIH and set on depth such /' that Baker window top is at top Kuparuk C. 13. MU and RIH with 7" whipstock assembly. Set whipstock such that top of window is a top Kuparuk C. /" Displace well to 1 0.1 ppg Flo-Pro mud. Mill window. Perform FIT test to 12.0 ppg EMW. POOH and lay down milling assembly. 14. MU 6-1/8" drilling assembly with MWO/LWO (page 5). //' 15. Drill ahead as per directional plan to proposed TD at 12,379' MD/6726TVD. Short trip as required and condition hole for running 4-1/2" solid liner. 16. Run 4-1/2" solid liner. The liner will extend approximately 150' above the 7" window. Cement liner as /' directed. Set liner top packer. Release from liner and displace well to filtered 10.1 ppg filtered KCL brine and POOH. 17. TCP perforate liner in select Kuparuk C interval. 18. RIH with casing scraper and POOH laying down drill pipe. 19. Run a 3-1/2", 9.2#, Butt, L-80 completion assembly. Set packer and test the tubing to 4000 psi and /,,/ annulus to 3500 psi for 30 minutes. /' 20. Shear OCK valve and install TWC. 21. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 22. RU hot oil truck and freeze protect well by pumping diesel to DCR shear GLM. Allow to equalize. 23. Rig down and move off. /' V -114 Drilling Program- AOGCC Page 7 ) ) V-114 Drilling Programme Job 1: MIRU Hazards and Contingencies / þ> V-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. þ> The cellar area surrounding V-114 (Slot S-G) should be checked to insure level prior to move in. ~ Check the landing ring height on V-114. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ~m~mm~»»~~'mm;!~;¡¡.-"m,I¡'¡¡~",I,! m¡¡¡; ¡ , , ,¡;;¡~;;;;,:,;~mm.-,'-¡'¡¡;¡'~f;ffl;;;;~¡;,;mW#!'!i#W!'1W1Mf,m~~nU'¡Þ;;!¡.¡¡~ Job 2: DrillinQ Surface Hole ~ There are two close approach issues in the surface hole. V-109 approaches with a center to ~ center distance of 29' at 650' and V-113 approaches within 58' at 750'. ~ Hydrates have been observed in wells drilled on V-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. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations (during gyro use) .'~:-'_.._~ ..__u......mc::;-¡!:- -:W#!mm.lI:L.L _:~t~:::~:<-m;~mlll:nll. ..L _~~ ::"'W:::':::':lm.:linu:u. ~m^""'T::::::~,!U_L .:. .¡.~ -:WL!IiI~UI:.I~_m_ .lllmllll:.::IIo'°_:III..1. '~""'."'':'·'··I''«·mil:mWI:LlIIL .U;,:IIIIIIUlIW;W III,U__,I._ .:/II:>(If«W:::::: ,þjoIllIlI :_-II:W~)',:;¡~lmU_ .HI_UCH:'N·..·.. Job 3: Install Surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 2500/0 excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be available as a contingency if surface hole drilling is problematic. If used the port collar will be positioned at ±1 OOO'MD to allow remedial cementing. >- "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" V-114 Drilling Program- AOGCC Page 8 ') ') .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" ~";·,·~··;"··:~I«~~·U¡ I!!I , ,:¡W,DI!lm:: ¡lli :t:·;,,:';,::~UllllmDI:';';", ,'-': :-::I--I~,-~-','- I;"';,J:>a ~a,;,I\., ;:¡-¡::,j-, --.l.::I!I.- -;,I;,;li I:II ;;a,n::~·-"¡~-~'V~:,¡;¡;t;::~DmUlllm-.m ' ,1I,la,II! lm~~IU!I,:,IW~,"'.,.,.¡,H«;,::;,*#I, ,llllt'I,~1 1!,m:al: 1,1m,IIC'::Jla ,mll1(.N !ltl:II'\I:a.C:I:~: -¡'::::::~IC!Ir«~;J m,m,:IW:lI"ICI;,:J!.::a;VI': Job 4: Drillin~ Intermediate Hole Hazards and Contingencies ~ V-114 is expected to cross one fault in the intermediate hole section. The approximate location of the fault is 6160'TVD ss (+/- 250') and has an estimated throw of 90'. Lost circulation is considered a minimum risk however losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. ~ KICK TOLERANCE: In the case scenario of 9.8 ppg pore pressure at the top Kuparuk target depth, gauge hole, a fracture gradient of 12.6 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 25 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 12.6 ppg. ~ V-Pad development wells have "kick tolerances" in the 30-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals >- There are no "close approach" issues with the intermediate hole interval of V-114. >- LWD data is critical in the lower interval of the intermediate hole section (Kuparuk interval). ROP restrictions/Mad passes are not anticipated in the Schrader/Ugnu interval for data collection. >- If the "pilot hole into the Kuparuk C has less than 15' of pay, there is a possibility that the well will be sidetracked back to the V-116 target location. 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 6: Case & Cement Intermediate Hole Hazards and Contingencies ~ The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 500' above the Kuparuk to 500' above the Schrader Ma and the tail will cover from the shoe to 500' above the top of Kuparuk interval. ~ 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 "G Seal" may be placed across the Schrader and Ugnu to help arrest mud dehydration if losses were experienced while drilling this interval. V-114 Drilling Program- AOGCC Page 9 ) ) ~ Ensure a minimum hydrostatic equivalent of 10.1 ppg on the HRZ 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. þ;> Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 63 bbls of dead crude (2200' MD, 1931 'TVD), the hydrostatic pressure will be 7.7 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 110 psi underbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" m¡;~;ß¡¡~ mm¡mmmmmmmmmffll'ìi/fIPffl¡¡ Job 7: Set Whipstock and Drill 6-1/8" Horizontal Production Hole Hazards and Contingencies þ;> A whipstock will be set in the 7" intermediate casing to facilitate kicking off the horizontal production hole. Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have accumulated there. ~ There are no "close approach" issues with the production hole interval of V-117. ~ Mud losses of 10-80 bph have been encountered in offset horizontal sections. In particular V-117 lost 5400 barrels of mud while drilling this interval. Contingency LCM material and mud product should be available at the rigsite/mud plant. ~ Under no circumstances add any LCM (including Walnut sweeps, cellulose material) other than calcium carbonate for losses < 50 BPH without prior discussions with the Drilling Engineer/Asset Production Engineer. Significant mud losses> 50 BPH may include the use of cellulose material to arrest losses. See LCM discussion in MI Mud Program. ~ Expect a certain amount of geo-steering , but significant changes to the planned directional profile should be discussed with the Drilling Manager/Operations Drilling Engineer. ~ There are no restrictions concerning adding lubricants to the mud whilst drilling the horizontal hole. ~ If the horizontal section has less than 15' of pay in the Kuparuk C consideration will be given to suspend drilling in the horizontal section and completing the well in the pilot hole section and perhaps the heel of the horizontal interval. Reference RPs .:. "Standard Operating Procedure for Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" V-114 Drilling Program- AOGCC Page 1 0 ) ) .:. "Lubricants for Torque and Drag Management" .:. Whipstock Sidetracks- RP ·:I.:,uaml~::::··""'NA:I"':"~,·<::r"~'~Jf:",:~'llm:,:::I~,~MI,II#!~:::·~~I:I:,:ml,"'·:::-.-:rl,~--t,~:¡~~....,wr''''''}~'''-~-.',''''¡,W:¡,:,::;::··:·,...N....N't.~,,·:"·,,:.~~.·~:+:_\....·""','-'~..· ::;:;~:·,··~,II!~ Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem. The mud system will be approximately 120 psi over balance to the Kuparuk formation. Minimize the time the pipe is left stationary while running the liner. ~ In the event additional weight is required to get the liner to TD, have 6 stands of weight pipe in the derrick. ~ A liner inner string should not be required to help convey the liner to bottom. An inner string contingency however is included should open hole conditions be poor. ~ Keep in mind that the Kuparuk interval will be open prior during swap to completion brine. Avoid introducing lighter than 9.8 ppg completion brines during swap after setting liner hanger. Reference RPs ~_,,=::··n":-,-,.:«......:-.-'~x.«:::::»!_""'>"""""''''·''''''''',·,wM,':::__»:::::·":-',.'w_,.......·.....w"¢'M.*W:tf4;::::""""<'-:..·..:-v'+....,.........~::..~:,.,,,NoI:-.'ffi::r............w"V'I".....~:~,:ir4-:::: ",.":.....<...¡.-.....-..x~«+I O'~_·«...,.w....>"....w~"."^~..,:~:::::>K:____........._, . ····..·....·,...w_·..........N..~.~..··~:·:::·__ Job 10: Perforate Well Hazards and Contingencies ~ The Kuparuk interval of the well will be TCP perforated prior to running the completion. After placing a KCL brine perf pill weighted to 10.1 ppg the well will be perforated across a 9.8 ppg EMW reservoir for an overbalance of 100 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. ~ The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach depth due to cement/fill. Reference RPs .:. See attached Initial Perforating Procedures 'I~ ..IIU:TI 'I':!+>::'.U ,\u:u. J. I ·-111. .~ >'1_ --II" ¡I Job 12: Run Completion Hazards and Contingencies ~ Keep in mind that the Kuparuk interval will be open during the running of the completion. Watch hole fill closely, verify no light fluids are introduced down hole and verify proper safety valves are on the rig floor while running this completion. V-114 Drilling Program- AOGCC Page 11 ) ) ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential. 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 . Freeze protect well by circulating diesel to GLM with DCK shear valve and allowing to equalize. . Install BPV, test to 2700 psi from below. ~:lmmml:~:I:I_ -:1-;:::11::1:_ t ~ ~:111:'1_r:-:\::I~I\I:mmll::Þn-H::!-:-::I::K>~:......:+IoIo!>MI:::1\111111:1::-1::1:1: 1:- .1 I_I: _1::_:ml:;:::m:mt:.l~I'_ :lm:-III:~:m~nal:':_ ':I-¡/IC-;-m ~-:I:III::m:mm:m'I': 11;':-',I::H).¡lml'::I- :1: ~1--lllm:!If.:.omI~II::IWI ::+1:!:ml'~lm:~:I--a-I-11 1!::III!lmm (oM(»'-...·J....~........A:I\: :mIDmum:::ml~rl:III_II'-:lnlIrlll Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus I:. .....v·mlll.I..!. .1. -r::mlllllll:.<lIH+:: .'IBmll:111111I11mnIlW:. .t _......u~-.w...«w:'W;;;;·~m;;·..::~,m~ V-114 Drilling Program- AOGCC Page 12 TREE = 4-1/16" crvv WELLHEAD = FMC .,........'.'."....'.'-.,.,.,.,.,..'...'........."".,........'.,...,'..'.',...'.·.w,'.'.'... ACTUA TOR = N/A 'KEi~"E[EV·;w"'''^''...''.W..'M'^"··'^'''''^''''''''·ã3:ãi' B'r::-··ECE\J; .w..... n"'5S:'S; KÖp·;;····..···· ······400' ^Max"'Ãñgle^';""^"·"w.,,'^,,'~....?:?~^~~':?^?;' Datum MD = '5atum··'nT5H;W'.^."^."w,..~""'..'^'w,w"?;"ŠS ) V -114 /' SA~ JNOTES: I 9-5/8" CSG, 40#, L-80, ID= 8.835" Ii 2965' ~ I I 2200' 1-13-1/2" HES X Nippple, ID= 2.813" ~ ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 6200 MMG Dum RK 2 5700 MMG Dum RK 3 5100 MMG DCK RKP 4 4200 MMG Dum RK 5 3300 MMG Dum RK 6 2600 MMG Dum RK I 3 1/2" 9.2 # L-80 2.992 ID W L Minimum 10 = 2.813" @ 2200' :g: ~I J~ 1--17"X 4 1 /2 8-3 Saker Packer I H"X nipple with 2.813 10 t-I"X" nipple with 2.813 10 11 Baker HMC Liner Hanger with ZXP 8290' I . ~ I-iPUPJTWI RA TAG I-iPUPJTWI RA TAG 7" Baker Whipstock (TOW) ~I 7950" I 1 9-5/8" HES 'EZSV' ~ 7" CSG, 26#,L-80,0.0383 bpf, ID=6.276'1-i . ~ -- PUPJTWI RA TAG Perforation intervals: Gun Type: 1 PBTD l-i 12299' I 4-1/2" Solid Liner, 12.6 #, L-80 (Top @ 10,378') l-i 12379' DA TE REV BY COMMENTS DA TE REV BY 08/27/03 nm HORtz COMPlETION (P5/P11) COMMENTS PRUDHOE SA Y UNIT WELL: V-114 ÆRMIT No: API No: BP Exploration (Alaska) ) ) V-114 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 1888' MD and near the TD hole section as well. · 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. Intermediate Hole Section: · A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. · The intermediate hole section will be drilled with a recommended mud weight of 10.1 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.8 ppg pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices and close monitoring of PWD data will contribute to favorable hole conditions. · V-114 is expected to cross one fault in the intermediate hole section. The approximate location of the fault is 6160'TVD ss (+/- 250') and has an estimated throw of 90'. Lost circulation is considered a minimum risk however losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. Production Hole Section: · Mud losses of 10-80 bph have been encountered in offset horizontal sections. In particular V-117 lost 5400 barrels of mud while drilling this interval. Contingency LCM material and mud product should be available at the rigsite/mud plant. / HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies bp V-114PB1 (P5) Proposal Schlumberuer Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPI#: Survey Name I Date: Tort I AHD I 0011 ERD ratio: Grid Coordinate System: location latllong: location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: August 18. 2003 BP Exploration Alaska Prudhoe Bay Unit - WOA V-Pad I Plan V-114 (S-G) Plan V-114 (S-G) F V-114PB1 50029 V-114PB 1 (P5) I August 15. 2003 70.406° 14211.70 ft 15.554/0.614 NAD27 Alaska State Planes, Zone 04, US Feet N 70.32749219. W 149.26593476 N 5969895.720 ftUS, E 590514.780 ftUS +0.69122375° 0.99990931 Ø!iI 51 Iii tud Survey I DlS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: local Coordinates Referenced To: Minimum Curvature I Lubinski 204.160° N 0.000 ft. E 0.000 ft KB 81.8 ft relative to MSL 54.000 ft relative to MSL 25.229° 57547.562 nT 80.80r October 15, 2003 BGGM 2003 True North +25.229° Well Head "- Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical NS EW DlS Tool Face Northing Easting latitude longitude Depth Section (ft) (deg) ( deg ) (ft) (ft ) (ft ) (ft) (ft) ( deg/100 ft ) ( deg ) ( fillS ) ( ftUS ) KBE 0.00 0.00 217.05 0.00 -81.80 0.00 0.00 0.00 0.00 -142.95M 5969895.72 590514.78 N 70.32749219 W 149.26593476 G1 326.80 0.00 217.05 326.80 245.00 0.00 0.00 0.00 0.00 -142.95M 5969895.72 590514.78 N 70.32749219 W 149.26593476 KOP Bid 1.5/100 400.00 0.00 217.05 400.00 318.20 0.00 0.00 0.00 0.00 -142.95M 5969895.72 590514.78 N 70.32749219 W 149.26593476 Crv 3/100 500.00 1.50 217.05 499.99 418.19 1.28 -1.04 -0.79 1.50 -145.70M 5969894.67 590514.00 N 70.32748933 W 149.26594115 600.00 4.50 214.30 599.84 518.04 6.41 -5.33 -3.79 3.00 -146.25M 5969890.35 590511.06 N 70.32747763 W 149.26596547 700.00 7.50 213.75 699.28 617.48 16.71 -13.99 -9.62 3.00 -0.83G 5969881.61 590505.33 N 70.32745396 W 149.26601278 800.00 10.50 213.51 798.04 716.24 32.13 -27.02 -18.28 3.00 -0.59G 5969868.49 590496.83 N 70.32741838 W 149.26608297 900.00 13.50 213.38 895.84 814.04 52.64 -44.36 -29.73 3.00 -0.46G 5969851.01 590485.59 N 70.32737100 W 149.26617583 SV6 983.72 16.01 213.31 976.80 895.00 73.69 -62.17 -41.44 3.00 -0.39G 5969833.06 590474.09 N 70.32732235 W 149.26627083 1000.00 16.50 213.29 992.43 910.63 78.18 -65.98 -43.95 / 3.00 -0.38G 5969829.22 590471.64 N 70.32731194 W 149.2667" <1 c~ 1100.00 19.50 213.23 1087.52 1005.72 108.69 -91.81 -60.89 3.00 O.OOG 5969803.19 590455.01 N 70.32724137 W 149.26642849 1200.00 22.50 213.19 1180.87 1099.07 144.07 -121.78 -80.51 3.00 O.OOG 5969772.99 590435.75 N 70.32715948 W 149.26658761 1300.00 25.50 213.16 1272.22 1190.42 184.23 -155.82 -102.76 3.00 O.OOG 5969738.69 590413.92 N 70.32706650 W 149.26676801 1400.00 28.50 213.13 1361.31 1279.51 229.06 -193.82 -127.57 3.00 O.OOG 5969700.39 590389.56 N 70.32696267 W 149.26696922 End Crv 1476.01 30.78 213.11 1427.37 1345.57 266.18 -225.30 -148.11 3.00 O.OOG 5969668.67 590369.41 N 70.32687668 W 149.26713571 SV5 1719.76 30.78 213. 11 1636.80 1555.00 389.39 -329.77 -216.24 0.00 O.OOG 5969563.39 590302.55 N 70.32659126 W 149.26768815 SV4 1853.61 30.78 213. 11 1751.80 1670.00 457.05 -387.14 -253.65 0.00 O.OOG 5969505.58 590265.84 N 70.32643453 W 149.26799150 Base Perm 1888.53 30.78 213. 11 1781.80 1700.00 474.70 -402.11 -263.41 0.00 O.OOG 5969490.50 590256.26 N 70.32639365 W 149.26807063 SV3 2290.08 30.78 213.11 2126.80 2045.00 677.67 -574.21 -375.65 0.00 O.OOG 5969317.07 590146.12 N 70.32592346 W 149.26898064 SV2 2499.58 30.78 213.11 2306.80 2225.00 783.56 -664.01 -434.21 0.00 O.OOG 5969226.58 590088.65 N 70.32567814 W 149.26945541 SV1 2848.76 30.78 213.11 2606.80 2525.00 960.05 -813.67 -531.81 0.00 O.OOG 5969075.77 589992.87 N 70.32526927 W 149.27024667 Version DO 3.1RT (d031rt_546) 3.1RT-SP3.03 Plan V-114 (S-G)\Plan V-114 (S-G)\V-114PB1\V-114PB1 (P5) Generated 8/18/2003 10: 12 AM Page 1 of 2 Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical NS EW DLS Tool Face Northing Easting Latitude Longitude Depth Section (ft) ( deg ) ( deg ) (ft) (ft ) (ft ) (ft) (ft ) ( deg/100 ft ) ( deg ) ( ftUS ) (ftUS ) 9-518" Csg pt 2965. 15 30.78 213. 11 2706.80 2625.00 1018.89 -863.55 -564.34 0.00 O.OOG 5969025.50 589960.95 N 70.32513298 W 149.27051041 UG4A 3256.13 30.78 213.11 2956.80 2875.00 1165.96 -988.26 -645.67 0.00 O.OOG 5968899.83 589881.13 N 70.32479226 W 149.27116976 UG3 3663.50 30.78 213.11 3306.80 3225.00 1371.87 -1162.86 -759.54 0.00 O.OOG 5968723.89 589769.39 N 70.32431523 W 149.27209282 UG1 4198.90 30.78 213.11 3766.80 3685.00 1642.50 -1392.34 -909.19 0.00 O.OOG 5968492.65 589622.54 N 70.32368829 W 149.27330590 Ma 4530.61 30.78 213.11 4051.80 3970.00 1810.16 -1534.51 -1001.91 0.00 O.OOG 5968349.38 589531.55 N 70.32329985 W 149.27405745 Na 4786.67 30.78 213. 11 4271.80 4190.00 1939.59 -1644.26 -1073.48 0.00 O.OOG 5968238.78 589461.31 N 70.32300000 W 149.27463758 OA 4967.08 30.78 213. 11 4426.80 4345.00 2030.78 -1721.58 -1123.90 0.00 O.OOG 5968160.86 589411.83 N 70.32278874 W 149.27504629 OBf Base 5391.91 30.78 213.11 4791.80 4710.00 2245.51 -1903.66 -1242.65 0.00 O.OOG 5967977.38 589295.30 N 70.32229125 W 149.27600871 CM2 5816.74 30.78 213. 11 5156.80 5075.00 2460.25 -2085.75 -1361.39 0.00 O.OOG 5967793.90 589178.77 N 70.32179376 W 149.27697109 Crv 4/100 6440.20 30.78 213.11 5692.46 5610.66 2775.38 -2352.96 -1535.66 0.00 -65.60G 5967524.62 589007.76 N 70.32106365 W 149.2783'" -') 6500.00 31.83 208.98 5743.56 5661.76 2806.22 -2379.58 -1551.66 4.00 -62.07G 5967497.82 588992.08 N 70.32099093 W 149.2785_, 6600.00 33.87 202.63 5827.59 5745.79 2860.37 -2428.39 -1575.17 4.00 -56.73G 5967448.73 588969.17 N 70.32085758 W 149.27870348 6700.00 36.20 196.96 5909.48 5827.68 2917.55 -2482.38 -1594.51 4.00 -52.09G 5967394.52 588950.48 N 70.32071007 W 149.27886020 CM1 6734.03 37.05 195.18 5936.80 5855.00 2937.65 -2501.89 -1600.13 /4.00 -50.66G 5967374.94 588945.10 N 70.32065677 W 149.27890569 6800.00 38.77 191.92 5988.85 5907.05 2977.47 -2541.28 -1609.60 4.00 -48.09G 5967335.44 588936.10 N 70.32054914 W 149.27898239 6900.00 41.53 187.43 6065.29 5983.49 3039.84 -2604.82 -1620.35 4.00 -44.65G 5967271.79 588926.12 N 70.32037556 W 149.27906947 7000.00 44.45 183.41 6138.45 6056.65 3104.36 -2672.67 -1626.73 4.00 -41.72G 5967203.87 588920.56 N 70.32019019 W 149.27912102 7100.00 47.49 179.80 6207.95 6126.15 3170.71 -2744.51 -1628.69 4.00 -39.21G 5967132.02 588919.47 N 70.31999393 W 149.27913677 Fault Target 7135.67 48.61 178.60 6231.80 6150.00 3194.76 -2771.04 -1628.31 4.00 -38.40G 5967105.50 588920.16 N 70.31992146 W 149.27913371 7200.00 50.64 176.53 6273.47 6191.67 3238.57 -2819.99 -1626.22 4.00 -37.06G 5967056.58 588922.84 N 70.31978773 W 149.27911666 7300.00 53.87 173.55 6334.68 6252.88 3307.60 -2898.74 -1619.34 4.00 -35.24G 5966977.93 588930.67 N 70.31957259 W 149.27906078 7400.00 57.17 170.81 6391.29 6309.49 3377 .48 -2980.38 -1608.09 4.00 -33.68G 5966896.44 588942.91 N 70.31934957 W 149.27896941 End Crv 7430.85 58.20 170.00 6407.78 6325.98 3399.16 -3006.08 -1603.74 4.00 O.OOG 5966870.79 588947.56 N 70.31927936 W 149.27893413 THRZ 7438.47 58.20 170.00 6411.80 6330.00 3404.52 -3012.46 -1602.62 0.00 O.OOG 5966864.43 588948.77 N 70.31926193 W 149.27892500 BHRZ 7818.01 58.20 170.00 6611.80 6530.00 3671.43 -3330.13 -1546.60 0.00 O.OOG 5966547.49 589008.60 N 70.31839412 W 149.27847044 K-1 7874.94 58.20 170.00 6641.80 6560.00 3711.47 -3377.78 -1538.20 0.00 O.OOG 5966499.95 589017.58 N 70.31826395 W 149.27840226 Target 7950.85 58.20 170.00 6681.80 6600.00 3764.85 -3441.31 -1527.00 0.00 O.OOG 5966436.56 589029.54 N 70.31809039 W 149.27831136 Top Kup 7950.87 58.20 170.00 6681.81 6600.01 3764.87 -3441.33 -1527.00 0.00 O.OOG 5966436.54 589029.55 N 70.31809034 W 149.278~ Kup C 7969.82 58.20 170.00 6691.80 6610.00 3778.20 -3457. 19 -1524.20 0.00 O.OOG 5966420.71 589032.54 N 70.31804700 W 149.2782~ OWC 8064.71 58.20 170.00 6741.80 6660.00 3844.93 -3536.61 -1510.20 0.00 O.OOG 5966341.48 589047.49 N 70.31783005 W 149.27817500 LCU I Kup B 8102.66 58.20 170.00 6761.80 6680.00 3871.62 -3568.38 -1504.59 0.00 O.OOG 5966309.78 589053.48 N 70.31774327 W 149.27812955 FWL 8121.64 58.20 170.00 6771.80 6690.00 3884.96 -3584.26 -1501.79 0.00 O.OOG 5966293.94 589056.47 N 70.31769987 W 149.27810682 TO / 7" Csg Pt 8290.85 58.20 170.00 6860.96 6779.16 4003.96 -3725.88 -1476.82 0.00 O.OOG 5966152.64 589083.15 N 70.31731299 W 149.27790420 leqal Description: Northinq (Y) rftUSl Eastinq eX} rftUSl Surface : 4649 FSL 1789 FEL S11 T11 N R11E UM 5969895.72 590514.78 Fault Target: 1877 FSL 3419 FEL S11 T11N R11E UM 5967105.50 588920.16 Target: 1207 FSL 3319 FEL S11 T11N R11E UM 5966436.56 589029.54 BHL: 922 FSl 3269 FEL S11 T11N R11E UM 5966152.64 589083.15 Version DO 3.1RT (d031rt_546) 3.1RT-SP3.03 Plan V-114 (S-G)\Plan V-114 (S-G)\V-114PB1\V-114PB1 (P5) Generated 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'."."-' M2°o··· ···-"r··· .....-.. - ........ -. ··'''i·· -.. ...... _.. _... . , . . ~ . . . . . · . . . . · . . . . , . . . . · . . . . · . .. . . · . . . . 7::.7::.7:r::.7::.7::.7::.7::.7.: '.7::.7::.7:.: t:. 7:.:7:.:7::.7::.7:.:7::.7::.7::.7.".7::.7::.7.:: 7::.7::.:::.7::.7::.. " C:.7. ::7::. 7::.7::.~~::~:·. é:: 7::.7.:'.7:.:7::.7:.:7 ~.:~::~:¡~:.~.:~;;~:;~:.:;:;~:.~:..~;.!.:~.:.~.:.~:.~.:~·:;:;~··;.:·~E~~:~~~;~~~.ifi.~M~!.,~~~~~'.;; o 1000 2000 3000 4000 Vertical Section (ft) Azim = 204.16°, Scale = 1(in):1000(ft) Origin = 0 N/-S, 0 EI-W 7000 6000 5000 4000 3000 2000 1000 o 4000 3000 2000 1000 /' MlscollaneoU3 Slol: PlanV·114(S·G) Plan: V·114PB1 (P5) NAD27 Alaska Slota Pinnas, Zone 04. US Foot NoI1hlng: 5969895.72 ftUS Grid Conv: +0.69122375' Ea.tlng: 590514.78 ftUS Scela Facl: 0.999909307 Surface Location Lat: N70 19 38.972 Lon: W1491557.365 Cate: October 15, 2003 FS: 57547.6 nT STRUCTURE V-Pad Prudhoe Bay Unit - WOA I FIELC Schlumberger ) ) 7000 6000 5000 4000 3000 2000 1000 o Clp: 80.807' Ma9 Coo: +25.229' V-114PB1 (P5) II ( ) m o en o ~ ;£ õ o o ~ ê c ~ Magnotlc Parometol'B Modal: BGGM 2003 I WELL WELL Magnetic Paramotors Modal: BGGM 2003 · . . . .·····...········................h......... KOP Bid 1.5/100 · . ............................................................-......... · . · . · . · . · . · . · , · . · . · . · . · . · . · . · . · . · . · . · . , . · . · . · . · . · . · . · . · . · . · . · . · . · , , . · . · . . .....·....1'..,..................................0..'.............................................. · . . · . . · . . · . . · . . · . . · . . · . . · , . · . . · . . o 0 . · . . · . . · . . · . . · . . · . . · . . · . . , . . · . . · . . · . . · . . · . . · . . · . . · . . o . . · . . · . . · . . · , . · . . · . . · . . .......................-.........................................................................,...............,........ o . . · . . · . . · . . · . . · . . · . . · . . · . . · . , · . . o . . · . . · . . · . . · . . · . . · . . · . . · . . · . , · , . o . . · . . · . . · . . · . . · . . · . . · . . · . . · . . , , . · . . · , . . . .. " C~ ~100'' .........,................. T..············ ..... r ................'1 .... V-114PB1 Fit Tgt' · . . . .. " · . . . . . · . . . . . · " " ... .. · . . · . . · . . · . . · . . · . . · . . · . . · . . · . . · . . · . · . · . · . · . · . · . · . : " ~ Target ¡ r ..... ........... ........... -r........... .......... .. ..........-t... ......... ...................... .~......... ................ ........... r....·..·.... ................. ......1··.. ..... ...... ............ .........¡... ...... V..114PB1 (P5) Dip: 60.607' MoO Doc: +26.220' o -500 .............................. -1 000 ^ ^ ^ z 2 Õ o If:! ~ T'" -1 500 II Q) ëii () Cf) Cf) V V V -2000 -2500 -3000 -3500 Data: Dctobor 15. 2003 FS: 57547.6 nT -2000 N "....... ...."",,... ) ) SchlulDberuer FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Surlaco Location Lat: N70 1036.972 Lon: W140 15 57.365 NAD27 Alaska Stato Pianos. Zono 04, US Foot Northing: 5060605.72 nus Grid Cony: +0.60122375' Ea.llng: 590514.76 nus Scala Fact: 0.009900307 Mlscollaneous Slot: Plan V-114 (S-G) Plan: V-114PB, (P5) TVD R"': KB (61.60 n oboYO MSL) S"'y Data: Aug...'16. 2003 -1500 -1000 -500 o 500 o -500 -1 000 -1500 -2000 -2500 -3000 -3500 V-114PB1 (P5) . TO /7" Csg pt ~V -2000 -1 500 -1000 -500 <<< W Scale = 1 (in):500(ft) E >>> o 500 tJp V-114 (P11) Proposal Schlumberler Report Date: August 18, 2003 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 204.160° Field: Prudhoe Bay Unit - WOA t Y Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: V-Pad I Plan V-114 (S-G) illt)' TVD Reference Datum: KB 11II Well: Plan V-114 (S-G) F a51 TVD Reference Elevation: 81.8 ft relative to MSL Borehole: V-114 Sea Bed I Ground Level Elevation: 54.000 ft relative to MSL UWUAPI#: 50029 Magnetic Declination: 25.215° Survey Name I Date: V-114 (P11) I August 15, 2003 Total Field Strength: 57548.554 nT Torti AHD I DDII ERD ratio: 230.244° 119959.39 ft 16.924/2.948 Magnetic Dip: 80.807° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 27, 2003 ~ Location Lat/Long: N 70.32749219, W 149.26593476 Magnetic Declination Model: BGGM 2003 Location Grid NfE Y/x: N 5969895.720 ftUS, E 590514.780 ftUS North Reference: True North Grid Convergence Angle: .¡{).69122375° Total Corr Mag North·> True North: +25.215° Grid Scale Factor: 0.99990931 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth TVD Sub·Sea TVD Vertical NS EW DLS Tool Face Northing Easting Latitude Longitude Depth Section (ft ) (deg) ( deg ) (ft ) (ft ) (ft) (ft) (ft ) ( deg/100 ft) ( deg ) (ftUS ) ( ftUS ) Top Whipstock 7950.00 58.20 170.00 6681.35 6599.55 3764.26 -3440.60 -1527.12 0.00 -14.00G 5966437.27 589029.41 N 70.31809232 W 149.27831237 Base Whipstock 7962.00 60.06 169.46 6687.51 6605.71 3772.75 -3450.74 -1525.29 16.00 O.OOG 5966427.16 589031.37 N 70.31806464 W 149.27829747 KOP Bid 10/100 7975.00 60.06 169.46 6694.00 6612.20 3782.01 -3461.81 -1523.23 0.00 -10.43G 5966416.11 589033.56 N 70.31803438 W 149.27828075 8000.00 62.52 168.95 6706.00 6624.20 3799.99 -3483.35 -1519.12 / 10.00 -10.18G 5966394.62 589037.93 N 70.31797554 W 149.27824744 8100.00 72.38 167.11 6744.31 6662.51 3874.45 -3573.57 -1499.94 10.00 -9.47G 5966304.65 589058.19 N 70.31772908 W 149.27809184 8200.00 82.25 165.46 6766.25 6684.45 3951.34 -3668.22 -1476.81 10.00 -9.11 G 5966210.29 589082.46 N 70.31747052 W 149.27790420 90° Pi 8278.50 90.00 164.22 6771.55 6689.75 4011.88 -3743.75 -1456.34 10.00 -9.02G 5966135.02 589103.84 N 70.31726418 W 149.27773814 8300.00 92.12 163.88 6771.15 6689.35 4028.32 -3764.42 -1450.43 10.00 -9.03G 5966114.43 589110.00 N 70.31720772 W 149.27769023 End Crv 8340.09 96.08 163.25 6768.28 6686.48 4058.68 -3802.77 -1439.12 10.00 O.OOG 5966076.22 589121.77 N 70.31710296 W 149.27759R49 Crv 6/100 8715.89 96.08 163.25 6728.46 6646.66 4341.08 -4160.59 -1331 .41 0.00 143.69G 5965719.76 589233.78 N 70.31612547 W 149.276' 2 ~ 8800.00 92.01 166.24 6722.53 6640.73 4405.87 -4241.51 -1309.34 6.00 143.90G 5965639.12 589256.82 N 70.31590442 W 149.27654607 V-114Tgt20p2 8841 .44 90.00 167.70 6721.80 6640.00 4438.88 -4281.87 -1300.00 6.00 101.14G 5965598.87 589266.65 N 70.31579416 W 149.27647029 8900.00 89.32 171.15 6722.15 6640.35 4486.99 -4339.43 -1289.25 6.00 101.12G 5965541.46 589278.08 N 70.31563693 W 149.27638312 End Crv 8914.56 89.15 172.00 6722.34 6640.54 4499.26 -4353.82 -1287.12 6.00 O.OOG 5965527.09 589280.39 N 70.31559760 W 149.27636582 Crv 6/100 9834.31 89.15 172.00 6735.93 6654.13 5277.84 -5264.53 -1159.20 0.00 83.13G 5964618.07 589419.27 N 70.31310967 W 149.27532800 9900.00 89.63 175.92 6736.63 6654.83 5334.60 -5329.85 -1152.29 6.00 83.09G 5964552.86 589426.97 N 70.31293124 W 149.27527193 V-114Tgt30p2 9951.74 90.00 179.00 6736.80 6655.00 5380.82 -5381.53 -1150.00 6.00 83.25G 5964501.21 589429.89 N 70.31279004 W 149.27525328 10000.00 90.34 181.88 6736.66 6654.86 5425.00 -5429.78 -1150.37 6.00 83.26G 5964452.96 589430.10 N 70.31265823 W 149.27525621 10100.00 91.04 187.83 6735.45 6653.65 5519.32 -5529.37 -1158.83 6.00 83.33G 5964353.29 589422.84 N 70.31238615 W 149.27532462 End Crv 10156.27 91.43 191.19 6734.24 6652.44 5573.75 -5584.85 -1168.12 6.00 O.OOG 5964297.70 589414.22 N 70.31223458 W 149.27539988 Version DO 3.1RT (d031rt_546) 3.1RT-SP3.03 Plan V-114 (S-G)\Plan V-114 (S-G)\V-114\V-114 (P11) Generated 8/18/2003 10:27 AM Page 1 of 2 Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical NS EW DLS Tool Face Northing Easting Latitude Longitude Depth Section (ft) (deg) ( deg ) (ft) (ft) (ft) (ft) (ft) ( degl100 ft ) ( deg ) ( ftUS ) (ftUS ) Crv 6.5/100 10337.86 91.43 191.19 6729.70 6647.90 5750.64 -5762.93 -1203.35 0.00 95.34G 5964119.23 589381.15 N 70.31174808 W 149.27568507 10400.00 91.05 195.21 6728.36 6646.56 5811.63 -5823.40 -1217.53 6.50 95.43G 5964058.60 589367.69 N 70.31158286 W 149.27579993 10500.00 90.43 201.68 6727.06 6645.26 5911.07 -5918.20 -1249.16 6.50 95.51 G 5963963.43 589337.22 N 70.31132386 W 149.27605604 V-114Tgt40p2 10569.05 90.00 206.15 6726.80 6645.00 5980.09 -5981.30 -1277.14 6.50 93.34G 5963900.00 589310.00 N 70.31115146 W 149.27628269 10600.00 89.88 208.16 6726.83 6645.03 6011.00 -6008.84 -1291.27 6.50 93.34G 5963872.29 589296.21 N 70.31107621 W 149.27639711 10700.00 89.51 214.65 6727.37 6645.57 6110.15 -6094.15 -1343.35 6.50 93.30G 5963786.37 589245.17 N 70.31084314 W 149.27681893 10800.00 89.14 221 . 14 6728.55 6646.75 6207.23 -6173.02 -1404.73 6.50 93.23G 5963706.78 589184.75 N 70.31062765 W 149.27731614 10900.00 88.78 227.63 6730.38 6648.58 6301.00 -6244.44 -1474.62 6.50 93.11 G 5963634.53 589115.73 N 70.31043250 W 149.27788234 End Crv 10911.72 88.74 228.39 6730.63 6648.83 6311.72 -6252.27 -1483.33 6.50 O.OOG 5963626.59 589107.12 N 70.31041109 W 149.27795286 Orp 6.5/100 10923.96 88.74 228.39 6730.90 6649.10 6322.88 -6260.40 -1492.48 0.00 76.56G 5963618.35 589098.06 N 70.31038887 W 149.27802701 V-114 Tgt 5 op 2 10985.83 89.60 232.00 6731.80 6650.00 6378.46 -6300.00 -1540.00 6.00 73.63G 5963578.19 589051.03 N 70.31028067 W 149.2784__5 11000.00 89.84 232.82 6731.87 6650.07 6390.94 -6308.64 -1551.23 6.00 73.62G 5963569.41 589039.91 N 70.31025705 W 149.27850288 11100.00 91.53 238.57 6730.67 6648.87 6476.13 -6364.97 -1633.79 6.00 73.69G 5963512.09 588958.04 N 70.31010311 W 149.27917169 End Crv 11101.18 91.55 238.64 6730.64 6648.84 6477.10 -6365.59 -1634.79 6.00 O.OOG 5963511.47 588957.05 N 70.31010144 W 149.27917983 Crv 6/100 11130.74 91.55 238.64 6729.84 6648.04 6501.46 -6380.97 -1660.03 0.00 96.49G 5963495.78 588932.00 N 70.31005940 W 149.27938429 11200.00 91.08 242.77 6728.26 6646.46 6557.07 -6414.84 -1720.40 6.00 96.59G 5963461.19 588872.05 N 70.30996684 W 149.27987334 11300.00 90.38 248.73 6726.98 6645.18 6631.82 -6455.89 -1811.53 6.00 96.66G 5963419.05 588781.43 N 70.30985464 W 149.28061158 V-114Tgt60p2 11354.86 90.00 252.00 6726.80 6645.00 6669.78 -6474.32 -1863.19 6.00 90.00G 5963400.00 588730.00 N 70.30980425 W 149.28103008 11400.00 90.00 254.71 6726.80 6645.00 6699.28 -6487.25 -1906.43 6.00 90.00G 5963386.55 588686.92 N 70.30976890 W 149.28138044 11500.00 90.00 260.71 6726.80 6645.00 6758.67 -6508.52 -2004.10 6.00 90.00G 5963364.10 588589.53 N 70.30971070 W 149.28217165 11600.00 90.00 266.71 6726.80 6645.00 6809.32 -6519.48 -2103.45 6.00 90.00G 5963351.95 588490.32 N 70.30968070 W 149.28297657 11700.00 90.00 272.71 6726.80 6645.00 6850.70 -6519.99 -2203.40 6.00 90.00G 5963350.23 588390.39 N 70.30967923 W 149.28378637 11800.00 90.00 278.71 6726.80 6645.00 6882.33 -6510.04 -2302.86 6.00 90.00G 5963358.97 588290.83 N 70.30970631 W 149.28459220 End Crv 11834.69 90.00 280.79 6726.80 6645.00 6890.97 -6504.17 -2337.04 6.00 O.OOG 5963364.43 588256.58 N 70.30972233 W 149.28486916 TO 14-1/2" Lnr Pt 12379.76 90.00 280.79 6726.80 6645.00 7017.01 -6402.13 -2872.48 0.00 O.OOG 5963460.00 587720.00 N 70.31000059 W 149.28920753 LeQal Description: Northinq (Y) rftUSl Eastinq (X) rftUSl Surface : 4649 FSL 1789 FEL S11 T11 N R11E UM 5969895.72 590514.78 V-114 Tgt 2: 367 FSL 3093 FEL S11 T11N R11E UM 5965598.87 589266.65 ,-,' V-114 Tgt 3: 4547 FSL 2944 FEL S14 T11 N R11 E UM 5964501.21 589429.89 V-114 Tgt4: 3947 FSL 3071 FEL S14 T11N R11E UM 5963900.00 589310.00 V-114 Tgt 5: 3628 FSL 3334 FEL S14 T11N R11E UM 5963578.19 589051.03 V-114 Tgt 6: 3454 FSL 3658 FEL S14 T11 N R11E UM 5963400.00 588730.00 TO I BHL : 3526 FSL4667 FELS14 T11N R11E UM 5963460.00 587720.00 Version DO 3.1RT (d031rL546) 3.1RT-SP3.03 Plan V-114 (S-G)\Plan V-114 (S-G)\V-114\V-114 (P11) Generated 8/18/2003 10:27 AM Page 2 of 2 - .- 7000 4500 5000 5500 6000 Vertical Section (ft) Azim = 204.16°, Scale = 1 (in):500(ft) Origin = 0 N/-S, 0 E/-W 4000 3500 6500 7500 7500 , KOP~ld10/100 V-114Tgt20P2 j Crv6/100 Endqrv j EndCrv Drp6.5/10Q V-114Tgt60P~ ;~: ~,l~~;J~i~~j:¡:;1:K:;";::;':;";';';';;,!:::,:::'I:t~';;;~;::;;;'f:-;;T~]';:';':;::;,~';;:7r~:;;:~':;';;:¡::;:jCi~,';;~::;: u. _ _~ 90° pt Cry 6/100 ¡ End Cry ¡ V-114 Tgt 3 op 2 ¡ Cry 6.5/100 ¡ V·114 Tgt 5 op 2 End frv Cry 6/100 End Cry 13:> /4-112" Lnr pt 7000 7000 II Q) (ij u Cf) o ¡:: "'" 6500 6500 4? Õ o ~ ;§ ~ 6000 6000 7000 6500 5500 5000 4500 4000 3500 6000 TVD Rei: KB (81.80 fi abcwe MSl) Srvy Dale: Augusll5. 2003 I FIElD Prudhoe Bay Unit - WOA I Strface LocaÜCW1 NAD27 Alaska State P1anes. Zone 04. us Feet Date: 0d0be0-27.2OO3 lat N70 19 38.972 Nortting: 5969895.72 ftUS Grid Coov: +0.69122375' FS: 57548_6 nT Lon: W149 1557.365 Easting: 590514.78 ftUS Scale Fac:t: 0.999909307 I MLL I MagoWc Pa"..,..,ters Model BGGM 2003 MisœIaneous ~ PlanV-114(S-G) V-114(P11} 80.807' +25.215& D"· /.lag DoGe S1RUCTURE V-Pad V-114 (P11) Schlumberger t)P -6500 -6000 -5500 -5000 -4500 -4000 WD Rof: KB (81.80 n obovo MSL) Srvy Dolo: Augu.t 15. 2003 -1 000 -2500 -2000 -1500 <<< W Scale = 1 (in):500(ft) E >>> -3000 Cry 6/100 V-114 Tgt 6 op 2 End Cry V-114 (P11) ¡/ .......................\.......................... TD f,4-112" Lnr Pt ..................... ..... .......,..... · . End frY I ! CN 6.'"- ! ! V0114T9t4opr ............... ......... .... ..........- -. .............. .~.......... .............. ............ ·1··········· ............... ......... ..:.... ...... .... '4114 Tgt 5 op 2 ~ j j---- ¡ ¡ V-114 Tgt 3 oPj2 · . · . · ' · ' · . · ' . ' : End cr-- ! Cry 6/100 TD I 7" Csg Pt_ i ~ 90. Pt ýt \ End Cry V-114PB1 (P5) ¡ -3500 -3000 -2500 -2000 -1500 -1000 · " · " · " ......mr········m·······················..r~!~~!\(~L........m·l···m......... 1 ¡ ~- ¡ ; :N' j / ....Top Whipstock ¡ ¡ .::Â;,:..... .................,y ßaseWhlPstocj : 11II. V,1141 .¡y : -3000 MIscellanoous Slot: Plan V-114 (S-G) Plan: V-114 (PII) I FIELD Prudhoe Bay Unit - WOA I $urfaco Locallon NAC27 Alaska Stoto PIanos, Zone 04. US Foot Dato: October 27, 2003 Lot: N70 1938.972 Northing: 5969895.72 nus Gnd Conv: ..0.69122375' FS: 57548.6 nT Lon: WI491557.365 Eo.tin9: 590514.78 nus Sealo Foct: 0.999909307 I WELL V-114 (P11) MagnoUc Paromotora Modol: BGGM 2003 Dip: 80.807' Mag: Doc: +25.215" STRUCTURE V _ Pa d / Schlumberger ') ) -6500 -6000 -5500 -5000 -4500 -4000 -3500 -3000 ^ ^ ^ z E' e:;- O LO ~ ..- II (l) m (.) (/) (/) V V V Comp~ny: Field: . Rëference Site: RderenceWeU: . Referen~eW ellpath: ) BPX AK Anticollision Report ) . BP AmOco Prudho~ Bay PB V Pad PlimV~114(S~G) . PlanV"114 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 12379.76 ft Maximum Radius: 3000.00 ft Survey Program for Definitive Wellpath Date: 8/15/2003 Validated: No Planned From To Survey ft ft 28.50 7950.00 Planned: Plan #5 V1 (0) 7950.00 12379.76 Planned: Plan #11 V1 Casing Points MD TVD Diarneter Hole Size Name· ft ft in . in 2965.15 2706.80 9.625 12.250 95/8" 7950.00 6681.35 7.000 8.750 7" 12379.76 6726.80 4.500 6.125 41/2" Summary <";"~7---------------"0ffset W ellpath --------7--~~~-----> Site Well WeUpath PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad Plan V-01 (S-N) Plan V-01 (S-N) Plan V-02 (N-I) Plan V-11 0 (N-X) Plan V-112 (S-H) Plan V-112 (S-H) Plan V-114 (S-G) Plan V-115 (S-B) Plan V-116 (S-L) Plan V-116 (S-L) Plan V-2-08i (N-C) Plan V-203 (N-A) Plan V-204 (S-O) Plan V-205 (S-P) Plan V-206 (S-S) Plan V-207i (N-E) Plan V-211i (S-Q) Plan V-212i (S-D) Plan V-213i (S-W) Plan V-214i (N-R) Plan V-216i (N-T) Plan V-2a06i (N-M) Plan V-2a09i (N-G) Plan V-3a06 (S-U) Plan V-Pi (S-A) V-03 V-100 V-101 V-102 V-103 V-104 V-105 V -106 V-107 V-108 V-109 V-109 V -109 V-111 V-111 V-111 V-111 Plan V-01 ST OP (V-116 Plan V-01 V10 Plan: PI Plan V-02 V5 Plan: Pia Plan V-110 V2 Plan: PI Plan V-112 Lat V1 Plan Plan V-112 V7 Plan: PI Plan V-114PB1 V3 Plan: Plan V-115 V1 Plan: PI Plan V-116 V1 Plan: PI Plan V-116PB1 V3 Plan: Plan V-208i V1 Plan: V Plan V-203 VO Plan: V Plan V (2-04HAW) VO PI Plan V-205 V2 Plan: PI Plan V-206 V1 Plan: PI Plan V-207i V1 Plan: V Plan V-211 i V1 Plan: P Plan V-212i VO Plan: V Plan V-213i V1 Plan: P Plan V-214i V3 Plan: V Plan V-216i V1 Plan: V Plan V-2a06i VO Plan: Plan V-209i V1 Plan: V Plan V-3a06 V1 Plan: P Plan V-Pi V1 Plan: Pia V-03 V7 V-100 V7 V-101 V7 V-102 V5 V-103 V6 V-104 V13 V-105 V13 V-106 V10 V-107 V5 V-108 V7 V-109 V2 V-109PB1 V5 V-109PB2 V2 V-111 V23 Plan: Plan # V-111PB1 V7 V-111PB2 V1 V-111 PB3 V4 Plan: Plan Dat,e: 8/18/2003 C~-ordinate(NE) ){eference: Vettlcål (TVD)Reference: W~ I: l'lan Y:·114 (S-G), True NOrth V-114 Plán81:8 . ·>Db: . Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Reference: Error Model: Scan Method: Error Surface: Version: 7 Toolcode Tool Name MWD+IFR+MS MWD+IFR+MS MWD + IFR + Multi Station MWD + IFR + Multi Station Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance' Area Deviation Warninv' ft ft ft ft ft 447.86 450.00 144.97 7.33 137.64 Pass: Major Risk 447.86 450.00 144.97 7.33 137.64 Pass: Major Risk 774.72 800.00 174.43 11.63 162.80 Pass: Major Risk 445.69 450.00 346.38 8.03 338.36 Pass: Major Risk 648.98 650.00 1.97 12.55 -10.58 FAIL: Major Risk 648.98 650.00 1.97 10.49 -8.52 FAIL: Major Risk 6650.00 6650.00 0.87 138.92 -138.05 FAIL: Major Risk 349.30 350.00 75.45 6.17 69.28 Pass: Major Risk 497.77 500.00 76.14 8.54 67.61 Pass: Major Risk 497.77 500.00 76.14 8.54 67.61 Pass: Major Risk 399.79 400.00 191.21 8.59 182.62 Pass: Major Risk 349.80 350.00 201.91 7.59 194.32 Pass: Major Risk 399.79 400.00 160.51 8.49 152.03 Pass: Major Risk 730.39 750.00 172.42 11.50 160.92 Pass: Major Risk 541.09 550.00 220.62 9.95 210.67 Pass: Major Risk 349.80 350.00 183.04 7.64 175.40 Pass: Major Risk 399.28 400.00 190.96 7.24 183.72 Pass: Major Risk 801.83 800.00 30.25 16.13 14.12 Pass: Major Risk 446.57 450.00 280.23 8.22 272.01 Pass: Major Risk 537.30 550.00 270.62 10.21 260.40 Pass: Major Risk 349.80 350.00 296.45 7.63 288.82 Pass: Major Risk 399.79 400.00 223.14 8.79 214.35 Pass: Major Risk 349.80 350.00 180.55 7.65 172.91 Pass: Major Risk 399.79 400.00 250.97 8.56 242.41 Pass: Major Risk 349.30 350.00 90.35 6.16 84.20 Pass: Major Risk 399.79 400.00 335.21 6.10 329.11 Pass: Major Risk 493.18 500.00 265.03 7.90 257.13 Pass: Major Risk 349.48 350.00 186.18 5.81 180.37 Pass: Major Risk 447.54 450.00 193.41 8.45 184.95 Pass: Major Risk 299.29 300.00 286.26 5.04 281.22 Pass: Major Risk 496.33 500.00 184.15 7.89 176.26 Pass: Major Risk 538.92 550.00 227.57 8.82 218.75 Pass: Major Risk 348.98 350.00 262.64 5.50 257.14 Pass: Major Risk 634.54 650.00 178.70 10.04 168.66 Pass: Major Risk 249.48 250.00 197.51 4.23 193.28 Pass: Major Risk 651.22 650.00 29.39 10.28 19.11 Pass: Major Risk 651.22 650.00 29.39 10.28 19.11 Pass: Major Risk 651.22 650.00 29.39 10.28 19.11 Pass: Major Risk 492.55 500.00 306.4 7 7.85 298.62 Pass: Major Risk 446.21 450.00 311.19 7.83 303.36 Pass: Major Risk 446.21 450.00 311.19 7.83 303.36 Pass: Major Risk 492.55 500.00 306.4 7 7.96 298.51 Pass: Major Risk COlDp~nY: Field: . Reference Site: ReferenceWelJ : ReferenceWellpath: Summary .BP Amoco Prudhoe Bay PBV Pad . Plan V~114($-G) Plan V~114 ) BPX AK Anticollision Report \) ; Cò:"ordinatê(NE) Reference: "ertical (TV!» Reference: . 8/18/2003 Well: PlanY:"114 (S-G), True North V~114Plah81.8· . -~~-- OffsetWellpath---':'':'''-'';'7-~-~-:-~~~ WelÏ ... . . Wellpath PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad V-113 V-117 V-117 V-117 V-201 V-202 Reference Offset Ctr~ctr . No~Go AlJòwablê MD MD Distance· Area Deviation ft ft ft ft ft 754.37 750.00 58.95 11.64 47.31 Pass: Major Risk 397.97 400.00 234.60 6.65 227.96 Pass: Major Risk 397.97 400.00 234.60 6.65 227.96 Pass: Major Risk 397.97 400.00 234.60 6.65 227.96 Pass: Major Risk 348.29 350.00 190.50 5.63 184.87 Pass: Major Risk 638.79 650.00 172.72 10.87 161.85 Pass: Major Risk V-113 V6 V-117 V9 V-117PB1 V6 V-117PB2 V6 V-201 V8 V-202 V9 Field: Prudhoe Bay Site: PB V Pad Well: Plan V-114 (S-G) Wellpath: Plan V-114 -294 Plan V:2J1!)2iŒ~GliPlan v~~ (V-IOf1-201 (V\liìÖl¡(Yðªq:iJ-I02) Plan V-207i (N-E) (~f.IlO'IIiIP») . 8 V~M~twrNHrdap-6'2fa06i) Plan V-2-08î (N-C) (plan V-208i) j. .1 I· j ~ . \í>MWV\2I~Pl!'ßy) (plan V-212i) 1: . VV%~¡V9(5) V. JOR.!.\!..J(8) 3' V-I03 (V-I03) . Plan V-203 (N-A) (PMfV:LU5[ I· Plan V-214i (N-R) (plan V-2141) Plan V-112 (S-H) (Plan V-112 Lat) -- ·200 100 \}~Yo'6-({}?fJo1-U) (plan V-3a06) t P'rMvíYrW~~WJ(Plan V-213i) -0 27() 90 Plan V-OI (S-N) (Plan V-OI) I ¡Plan V-206 (S-S) (plan V-206) 100 200 -294 180 294 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] V-114 Permit to Drill (Production Cement Volume Correction) ) Subject: V-114 Permit to Drill (Production Cement Volume Correction) Date: Tue, 2 Sep 2003 16:29:55 -0500 From: "Magee, D Neil" <MageeDN@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> Winton, I see a mistake was made in the production cement volume submitted in the Permit to Drill. The correct volume (100bls) is shown below in red. Regards, Neil 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 9-5/8" Surface Basis: Lead: Based on conductor set at 1101, 1778' of annulus in the permafrost @ 250% excess and 3271 of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 7501 MD(>500'TVD) open hole volume + 30% excess + 801 shoe track volume. Tail TOC: At -22151 MD Total Cement Volume: Lead 400 bbl / 2244 ft3 / 506 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.45 cf/sk. Tail 60 bbl / 336 ft3 / 290 sks of Dowell Premium 18' at 15.8 ppg and 1.17 cf/sk. The 7" production casing will be cemented as follows: Casing Size 7" Production Longstring Basis: Tail: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 7,4501 MD Lead: Based on TOC 500' above top of Schrader Ma +30% excess volume Cement Placement: From 7,450' MD to 40301 MD (500' above Schrader Ma sand) Total Cement Volume: Lead 119 bbls / 667 ft3 / 240 sks of Dowell Premium "G" at 12.5 ppg and 2.79 cf/sk Tail 32 bbls / 180 ft3 / 157 sks of Dowell G at 15.8 ppg and 1.16cf/sk The 4-1/2" production liner will be cemented as follows: Casing Size 4-1/2" Production Longstring Basis: Tail: Based on TOC 150' above top of production liner (with 4" DP) + 30% excess + 801 shoe Cement Placement: From shoe to 7,800' MD Total Cement Volume: Lead 100 bbls / 561 ft3 / 469 sks of Dowell Premium "G" at 15.8 ppg and 1.20 cf/sk Neil Magee Alaska Drilling & Wells 907 564-5119 Office 907 564-4040 Fax 907 240-8038 Cell II· 0 5 5 ¡ 2 ~ ". 1:0.... 2 0 j a '1 5 I: o. 27 8'11; ,,~ -" AL~$KA QIL &<3ÁS 333 W 7TtH A \,:,E~WEi SUITE 10(»iii . ....... ANCHORAc.sE,ÃK 9ß501~3539 TO THE ORDER OF: PAY: No~....P 05·51_21 BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. "-/ v ~ \ \ Lf'? H PERMIT TO DRILL FEE 7/14/2003 INV# PR071003K NET VENDOR DISCOUNT GROSS DESCRIPTION INVOICE / CREDIT MEMO DATE CHECK NO. 055121 DATE 7/14/2003 P055121 ) ') . TRANSMlTAL LETTER CHECK· LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production. should continue to be reported as a function 'of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject ·to fuD compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. PTD#: 2031520 Administration :WEL~ P.ERM~T ·C.H.~CK:~ISr; Company ~,;..".....:,.,'.' ",,,.~_,~~,_,,,, . _ .~~',_~Jy..'---......,~~,_.~"r ",.". J~I?.E~I?J.Q88IIº~_.(8LA$J~8)J.NÇ___.______.__.__._.__._ _ [] [J Appr RPC Date 9/3/2003 Engineering Appr Date WGA 9/3/2003 -_...~.._,_.._--_.._.~_._-_.."-- ,-""----".,._~ Geology Appr Date RPC 9/3/2003 Geologic Commissioner: 11 12 13 14 15 16 17 '8 9 10 11 12 13 14 15 16 17 Well Name: EBJJJltLO_E-';~8YJJ.~B_QB!;___V..:Jj4 _. Program _QE\{..___ ..__._....._._. Well bore seg Field & Pool ____.__._______ Initial ClasslType _D.E~LJ.:.QJ1____ GeoArea Unit ____..____ On/Off Shore .Qo___.._ Annular Disposal Permitfee attache.d. . . . . . . . Yes. Lease .number .appropriate Yes. .U.nlq!,.J~ w~lI. n.arne _and ou.mb.er . . _ . . _ _ _ . . _ . . _ . _ . . . . . _ _ . . . . . . . . . . . . . . . Yes. . . . . . . . _ . . . _ . _ . . _ _ . . . . . _ _ . _ _ _ . . . . . . . _ . . . _ . . _ . . . _ . . . . . . . . . . . . . . . . . . . . . _ _ _ . _ .We.II.located ina. d.efine.dppol. . . . . . . . . . Yes .. .We.lllocated proper .distancefrom drilling unitb.oundalY- Yes .We.II.located pr.oper .distance from othe.r wells Yes. _S.uffjcient.acreage.ayailable in_driUiog unjt. Yes Jf.deviated, is. weJlbore platincJu.ded . Yes _Qper.ator only- affect~d Party. . . . . . . . . . . _ . . _ . . . _ . . Yes _ _ _ . _ _ . _ _ . . . _ . .. ...... _Qp~rator I)as.apprppr[ate. b.ond i.n .force. . . _ _ . . _ . _ _ . . . . . . . . . . _ _ . _ . _ . . . . . . . .Yes . . _ _ _ . . . . . _ _ . . _ _ _ . _ . _ . . . . . . _ _ . _ _ . _ _ _ _ _ . _ . _ _ . . _ . . . . . _ _ . . . . . _ _ . . _ _ _ . . _ . . . _ . . . Permit. c.an be i.ssued without cQnserva.tion order. . . . . . . . . Yes.. . . . . . _ . . . . . . . _ . . Permit c.an be issu.ed wjthQut ad.mil')i~tr:ati'v'e_apprpvaJ _ _ . . _ _ _ _ .. _ . . . . . Yes. . . . . _ . _ _ _ . . . . . . . . Can permit be approved before 15-day wait Yes .We.IUocated within area and.strata _authorized by.lojectioo Order # (put 10# in.c.ol)1(11.eots). (For_ NA . . . . _ . . . . . . . . . . . . _ . . . . . _ . _ . . _ . . . _ . . . . . . . . . . . . . . . . . . . . _AJI welJs. within .1l4.llJite .are.a_ of reyiew jdeot[fied (Fpr: ~ervjc.e .well only). _ _ . _ . _ _ . . _ . . . _ NA. _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ . _ . _ _ _ _ . . . . . _ . _ . _ . _ . _ . . . _ . _ _ . _ . . . . . . . . . . . . _ . . _ . _ . . _ _ . . . . . _ _ p.re.-produ.ced. injector: puratiQn.of pre-propuQtion tess. than. ~ months. (For.ser.vice well_ only) . _ _NA. _ . _ . . _ .. . . _ . . . _ . _ . _ . . _ . _ . . . . . . . . . . . . . . . _ _ . _ _ _ _ . . . _ . . . . . . _ . . . . . . . . . . _ _ . . . . ACMP_ ~inding .of Con.si.stency. h.as bee.n .i~sued. fprJbis proJect. _ . NA. _ . . . _ _ .. _ . . . . . . . . . . . . _ _ . _ . . . . . . . (' - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - ~ ~ . ------- 18 .C_oodu.ctor $tril1g.PJQv[ded _ _ . . _ .. . . _ . __ . . . . . . . _ . . . . . . _ . _ _ . . _ . . . . . . . . Yes. . . . _ . . _ _ . _ . . . . . . . . _ . . . . . . _ . . . . . . . . . _ _ . . . . . . . _ . . . . . . . . . _ _ . . _ _ _ . . _ . _ . . . . . . . 19 _S.ur:face .cas.ing. pJotec.ts. alLknown. USDWs . . . . _ . . . _ . . . _ . . _ _ .. . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . _ . . _ _ . . . . 20 .CMT. v.ol. adequ.ate.to circ_utate.o.n _cond.uctor. & SUJf.C$g . . . . _ . . . . . _ . . . . . . . . . . . . . Ye$ . _ . . . . . Ade~uate ~x.ce~s, . . . . . . _ . . . . . . . . . . . . . _ . _ . . . _ _ . . _ . . . 21 .CMT. v_ol. a.dequ.ate.to tie-in Jong .string to.S!..u:.f ç~g. . . . . . . . . . . . . . . . . . _ . . _ _ . . . . . No. . . . . . . _ . . _ _ . . . . . . . . . . . . . . . . . . _ . . . . . . . . _ . . _ . . . . . . . . . . . . . . _ . . . _ . . . . . . . . . . 22 .CMT.will coyer_all KIJO.w.n.PfO.ductiYe bori~on.s. . _ . . . . _ . . . . . _ . . . ._ . . . _ _ . .Yes . . . _ _ . _ _ . . _ . _ . _ . _ __ .. _ . _ _ . . . . . . . . . . . . . _ . _ . . _ . . . . . ._ . . . . ._ . . 23 .C.asiog de.sign$ adequat~ fpf C,.T, ß.&_perruafr.ost. . .. . _ . _ _ . . . . . . . . ._ . . . _ . . . .Yes. . . . . _ . . .. . _ . . . _ . . . . . . _ . . . . . __ . . . . . . . . . _ . . _ .. . . . . . . . . . _ _ . . . . _ 24 .Apequpte.tan.kage.oJ re.serye pit. _ . ._ . . . . . . . . . . . . . . . . . _ . . . _ .. ....... Yes. _ . . . . . Nab.ors.9.E$.. _ . . . . . . . . . . . . . ._ . . . . _ . . . . . . . _ . . . _ . . _ . . . . .. . . _ _ 25 Jf.a.re-prill., bas. a_ 1.0:-403 fQr _abandon.ment beeo apPJoved . . . . . . . . . . . . . . . . . . . . . . NA _ . . . . . . New well, . . . . . . _ . . . . . . . . . . . . . . _ . . . . . _ . . _ . . . .. . . . . . . _ . . . . . _ . . _ . . . . . . . . 26 _Apequpte .we[l~ore_ ~epªratjo.n _propo~ep _ _ _ _ . _ . _ _ _ . . _ . . . . . . . _ . _ _ . . . _ . . . . . .Y ~$ . _ _ _ . _ . All we.lI$ paS$ Ji$k criteJia.. . . . . _ . _ _ _ . . _ _ _ _ _ _ _ _ _ . . _ _ . _ _ . _ _ . _ _ . _ . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ 27 Jf.djver:t~r Jeq.uire.d, dQe~ ..it meet reguJa.tions. . . . . . _. _ . . _ . . _ . . . _ _ _ . _ _ . . _. .. Yes __ . . . . . . . . . . . . _ . . . . . . . . . . . .. . . . _ _ . . . . . . .. . . . . . _ . . . . . . . . . . . _ 28 .DJiLliog fJu.id. prQgram sc.h~matic_& eq.uip Jist.adequate. . . . . . . . . . .. . . . . . . . . . . . . . . Yes. . . . . . . Max MW.1.0J .ppg.. . . . . . . . . . . . . _ . . . . . . . . . . . . _ . . . . . . . _ . . . . . . _ _ . . . . 29 .BOP.Es,.d_o .they J11e~tr~guJa.tion _ . _ . . . . . . . . . . . . . . . _ .. . . . . . . . . . . . .Yes. __ . . . .. . . . . _ . _ . . . . _ . .. . . . . . . . . . _ ._ _ . . . . . . . . . . . . . _ _ . . . . . . . . . . _ . . 30 .BOPE.pre.ss ratiog appropriate;.test to.(pu.t p$ig tn.comments). . . .. _ . _ . ._ . .__ . . . . _ . Yes .. . Te.st to.40QO.psi_. .I\lIS~ 27.96 psi.. . . . . . . . . . . . _ . .. _ . . . . . . . . . .. . . _ . . . . . . . _ . . . 31 .C.hoke. rua.njfold compJi~s. w/API. R~-5~ (May 84). . . . . . . . . . . _ . . _ _ . . . _ . . . . . . . . Ye$ . . . . . _ . . . _ . . . . . . _ ._ . . . . . . . _ . . . . . . . . . . . . . . . . . . ._ . . . . . . . . . _ . . . . . . . . . . . . . . . . . . 32 .WQrk wi!1 occ_ur withput.operatio.n .sbutdo.wn. _ . . . . _ . _ _ . . . _ . . . . . . .. Yes. _ _ . . . . _ _ _ ._....... .. __ . . . _ . . . _ . .. .. _ . . . . . . . _ . . . . . . . . _ _ . .. _ . _ . 33 J~ pre~ençe. Qf .H2S gas. prob.able _ _ . . . . _ . . . _ _ . . . . . . . . . . . . . . . . . . . . ._ No _ . . . . . _ _ _ . _ . . _ _ . _ . _ _ _ . . . . . . . . . . . _ ._ . . . . . . .. . . . _ . . . . . _ . . . . . . . _. 34 Meçba.n[cal.cpodjtio[1 pf we.lIs within AOR Yerifi~d. (for.s.ervjce w~1J onJy). . . . . _ . . _ . . . . . NA . . . . _ _ . . _ . . .. ....... _ . . . _ _ . . . . . . . . . . _ . . . . . . . . _ . . . . . . . .. . _ . . . . . . . . . . _ . . . . . . . ( _.~-~._------_...__._...- '"'-'-~'----'-'---'-- --.-.----.--.--- .-.-.----- 35 P~rlTJit c.ao be Lssu.ed w!o. hydrogen. s.utfide lJleaS.!Jre~. . . . __ . _ _ _ . . . . . _ . . . . . __ . .Ye$ _ _ . . _ . . . . _ . _ _ . _ . . . . . . . .. . . _ _ . . . . . . . _ . . . _ _ . . . .. .............. _ . . . . . . . . .. . . . . . 36 .D_ata.PJeseoted on. pote.ntial pveJpre~s!..lre _z9I'1e$. . . . . _ _ . . . . . . . .. . . . _ . . . . . . . . . NA_ . . _ . _ . . . . . . . . . . . . . _ . . . . . . _ _ _ . . . . . _ . . . . . . _ .. . _ . . . . . . . _ . . . . . . _ . _ . . _ . . . . . . . . 37 .SeLsmic_a.nalys.is. Qf $ba.llow gas.zPo~s. . _ . _ . _ . _ _ . _ . . .. _ . . . . . . . . . . .. NA. . _ _ . . _ . . . _ . . ._ . _ . __ _ . _ . . . _ . . . . . . . . . . . . . . . . . . .. . . _ ._ . . . _ . . . . . . . _ .. 38 .Seabep .col'1djtipo survey .(if Off-$hpre) . . . . _ . . _ . _ . . . . _ _ _ _ _ . _ _ _ _. . _ . . . . . _ . _ NA. . . . .. . . . . . . . . . . . . . . _ . . . . . . . _ . . ._ _ . . . .. _ . _ . _ . . . . ._ _ _ . . . . _ . . . _ . _ . . . 39 . CQnta.ct nam.elphc)Il.e.for_week.ly prpgre$s.reports [e2<pIQratpry .only]. . . . . . . _ . . _ _ . . .. . . NA. . _ . . . . _ _ . _ . . _ . . _ . _ . . . . . . . . . . . . .. . . . . . . . _ . . . . _ _ . . . . . . . . . . . _ _ _ _ _ . . _ _ . . . . . Engineering Public <;(J::/ 0/ / :< Date: Commissioner: Date commis~ioner VI I/Dart'e
