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Home My WebLink About203-013 MICROFILMED 03/01/2008 DO NOT PLACE x.~'4. ~, .~;.... ~~ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc II ~ p(-~ ã)- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030130 Well Name/No. PRUDHOE BAY UN BORE L-121 Operator BP EXPLORATION (ALASKA) INC .5~ L¿J.. ~'2 hJ, ~ J API No. 50-029-23138-00-00 MD 13411 ----- TVD 6813 i/' Completion Date 3/11 /2003 ~mPletion Status ----- ---- --~--- .-------- ------- REQUIRED INFORMATION --- ----." ----- Mud Log No Samples DATA INFORMATION Types Electric or Other Logs Run: MWD, GR Well Log Information: "t.' D : :~. ¥Óg I -t: I ~ ~ :::. I I~ ! 11;D C Tf I j2229 Neutron ~ ED ç Pds .......~2229 Neutron V L-__ Log/ Data Digital ~~~rmt I ~ Rpt Electr Dataset Number Name Directional Survey Directional Survey Log Log Scale Media ~229 Sonic V229 Sonic 5 5 Col Sonic C Tf ,~2229 Induction/Resistivity C Pds '-112229 Induction/Resistivity 25 25 Blu I nd uction/Resistivity . 172229 Density ~ 2229 Density Density 25 25 Blu Neutron 25 25 Blu Well Cores/Samples Information: Name Interval Start Stop Sent No Run No 1 4-5 4-5 4-5 1-5 1-5 1-5 4-5 4-5 4-5 4-5 4-5 4-5 Received P&A Current Status P&A UIC N Directional Survey ~ (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop o 13411 -' OH/ CH Received Open 3/24/2003 Comments o 13411 Open 3/24/2003 3640 13293 Open 10/31/2003 LDWG Open Hole Edit of ARC/ADN/GRllsonic 3640 13293 Open 10/31/2003 ISONIC - BHC Format 3640 13293 Open 10/31/2003 ISONIC - BHC Format 108 13373 Open 10/31/2003 LDWG Open Hole Edit of ARC/ADN/GRllsonic 108 13373 Open 10/31/2003 Vision Resistivity 108 13373 Open 10/31/2003 See Vision Service Log, individual Log CULLED 3640 13293 Open 10/31/2003 LDWG Open Hole edit of ARC/ADN/GRllsonic 3640 13293 Open 10/31/2003 Vision Density Neutron 3640 13293 Open 10/31/2003 See Vision Service Log, individual Log CULLED 3640 13293 Open 10/31/2003 LDWG Open Hole edit of ARC/ADN/GRllsonic 3640 13293 Open 10/31/2003 Vision Density Neutron 3640 13293 Open 10/31/2003 See Vision Service Log, individual Log CULLED Sample Set Number Comments Permit to Drill 2030130 MD 13411 TVD 6813 ADDITIONAL INFORMATION Well Cored? y Ifl:b Chips Received? . Y / N Analysis Received? ~ Comments: ---------- ----------- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Well Name/No. PRUDHOE BAY UN BORE L-121 Operator BP EXPLORATION (ALASKA) INC Completion Date 3/11/2003 Completion Status P&A Current Status P&A Daily History Received? @/N .~ &)IN Formation Tops J-o Date: API No. 50-029-23138-00-00 UIC N -" là- ~~, -~ J Schlumbepgep NO. 3008 10/30/2003 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Well Job# Log Description Date Color BL t-121 40008753 OH EDIT ARC/ADN/GRlISONIC DATA 03/10/03 ~-o0 L-121 40008753 MD VISION RESISTIVITY 03/10/03 1 L-121 40008753 TVD VISION RESISTIVITY 03/10/03 1 L-121 40008753 MD VISION DEN/NEUTRON 03/10/03 1 L-121 40008753 TVD VISION DEN/NEUTRON 03/10/03 1 L-121 40008753 MD VISION SERVICE 03/10/03 1 L-121 40008753 TVD VISION SERVICE 03/10/03 1 -121 40008753 MD ISONIC BHC FORMAT 03/10/03 1 L-121A 40008753-01 OH EDIT MWD DATA 03/17/03 ~L_121A 40008753-01 MD VISION RESISTIVITY 03/17/03 1 L-121A 40008753-01 TVD VISION RESISTIVITY 03/17/03 1 ~ 03 -()3c¿ L-121A 40008753-01 MD VISION DEN/NEUTRON 03/17/03 1 - L-121A 40008753-01 TVD VISION DEN/NEUTRON 03/17/03 1 L-121A 40008753-01 MD VISION SERVICE 03/17/03 1 L-121A 40008753-01 TVD VISION SERVICE 03/17/03 1 '-- 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 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth ~::EIVED CD '~ 1 J!9fJ/J-{ 1 J!}ó2~ -- Date Delivered: Or·-ro '2 '" r¡p¡","- L ,) i c. Vv Received ~ b-..Qo!~ .~ c-- <t::::. ~~ \" ~ C:::::-. .. . ~- -' ;~~.~1.~:r~&~_jl··¡-6.- -..... t -~<',rn (":¡.:O'I:- -- - - _ :~0;¡S. (;0:¡;.¡:b:Ú:m .!:.'¡J1C11OiSt!S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) Plugged Back for Sidetrack 1. Status of Well o Oil 0 Gas 0 Suspended a Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2357' NSL, 3801' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval N/A At total depth 1633' SNL, 4234' WEL, SEC. 09, T11 N, R11 E, UM X = 577524, Y = 5968748 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Borealis Pool RKB = 76.4' ADL 028241 (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 2/27/2003 3/10/2003 3/11/2003 NIA MSL Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13411 6813 FT 6050 3641 FT a Yes 0 No NIA MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, Classification of Service Well 7. Permit Number 203-013 303-084 8. API Number 50- 029-23138-00 9. Unit or Lease Name X = 583116, Y = 5978078 Prudhoe Bay Unit 10. Well Number L-121 23. CASING SIZE 20" 10-3/4" WT. PER FT. 91.5# 45.5# GRADE H-40 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 108' 42" 260 sx Arctic Set (Approx.) 29' 3645' 13-1/2" 744 sx PF 'L', 537 sx Class 'G' AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) None SIZE None TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 25. MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12990' P&A wI 52 Bbls Class 'G' /" vJ6A 8850' Set 2nd Plug w/1 01 Bbls Class 'G' r' ";}/tul. (Not Tagged) Set 3rd Plug wI 100 Bbls Class 'G' / 6050' Set 4th Plug wI 117 Bbls Class 'G' /' 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oll-BBl TEST PERIOD GAs-McF WATER-Bsl CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. sut( ~~i~ I V I:: U Oll-BBL GAs-McF WATER-BsL Oil GRAVITY-API (CORR) ~l~FL G ¡<- _19.' MAY 1 5 2003 Alaska Oil & Gas Cons. Commission Anchorage No core samples were taken. lJ ~-\ ¡ ........ ¡ \ \j r~\ I.- form 1 0-407 Rev. 07-01-80 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ugnu 4115' 2790' Ugnu M 6626' 3868' Schrader Bluff N 7271' 4112' Schrader Bluff 0 7828' Base Schrader I Top Colville 8665' HRZ 12493' Kalubik 12974' Kuparuk D 13172' Kuparuk C 13212' 4318' 4663' 6299' 6520' 6644' 6671' '31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ _ ~ Title Technical Assistant Date OS "IS .c::t ~ L-121 Well Number 203-013 303-084 Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: L-121 Common Name: L-121 Test Date 3/4/2003 Test Type LOT Test Depth (TMD) 3,645.0 (ft) BP . EXPLORATION Leak-OffTestSurnmaß' . Test Depth (TVD) 2,611.0 (ft) AMW 9.70 (ppg) Surface Pressure Leak Off Pressure (BHP) 580 (psi) 1,896 (psi) Page 1 of 1 EMW 13.98 (ppg) - Printed: 3/24/2003 9:15:03 AM ') >1 ) BP EXPLORATION Operations Summary Report Page 1 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From- To Hours Task Code NPT Phase Description of Operations 2/25/2003 21 :00 - 00:00 3.00 MOB P PRE Move rig to L-121 2/26/2003 00:00 - 01 :00 1.00 MOB P PRE Check derrick & lines. Layover derrick 01 :00 - 02:30 1.50 MOB P PRE Jack up sub, move off S-117. Clean up location 02:30 . 08:00 5.50 MOB P PRE Move rig to L-Pad 08:00 - 10:00 2.00 RIGU P PRE Lay rig mats. RU diverter. Layout pit liner 10:00 - 14:00 4.00 RIGU P PRE Position sub over L-121 14:00 - 23:00 9.00 DRILL P SURF Take on water, build spud mud. Warm Hyd rill , riser and conductor. NU same, install valves. Change out top drive quill for 5" DP. Load pipeshed with 5" DP and BHA #1_ RIG ACCEPTED AT 14:00 23:00 - 00:00 1.00 DRILL P SURF Clean and prep rig for spud 2/27/2003 00:00 - 01 :30 1.50 DRILL P SURF Load BHA #1 in pipe shed and strap same. Continue mix spud mud 01 :30 - 02:00 0.50 DIVRTR P SURF Function test diverter 02:00 - 03:30 1.50 DRILL P SURF Drill out ice plug in conductor. Blow down conductor 03:30 - 07:00 3.50 DRILL P SURF Pick up DP singles. MU stands and stand back 07:00 - 08:30 1.50 DRILL P SURF PU 5" HWDP, make up stands and stand back in derrick 08:30 - 10:00 1.50 DRILL P SURF Pre-spud meeting NAD, BP, Anadrill, Baroid 10:00 - 10:30 0.50 DRILL P SURF Dril out conductor with 13-1/2" bit to 108' to MU BHA #1 10:30 - 12:00 1.50 DRILL P SURF Make up BHA #1 12:00 - 13:00 1.00 DRILL P SURF Drill from 108" to 262'· KOP. 50 klbs up, 49 klbs down, 50 klbs rotate. 660 GPM, 1300 Ibs torque 13:00 - 14:00 1.00 DRILL P SURF Circulate hole clean. Pump survey. POH 2 stands. MU collar and jar stand. RIH 14:00 . 16:00 2.00 DRILL P SURF Directional drill from 262' to 636'. Sliding -50%71 klbs up, 71 klbs down, 73 klbs rotate. ART Run #1 = 1.05 hrs AST Run #1 = 1.55 hrs ADT = 2.6 hrs 16:00 - 18:00 2.00 DRILL N DPRB SURF Circulate the hole clean. POH due to erratic MWD surveys, Gravity readings on MWD surveys were out of tolerance due to X-axis readings being outside of total gravitational reference numbers. Resulting survey inclination calculations were questionable. Change out MOW tools 18:00 - 19:00 1.00 DRILL N DPRB SURF RIH to 197'. Shallow test MWD - OK. Reshoot surveys every stand to TO @ 636". First two surveys in tolerance, the last three were questinable due to X-axis problem 19:00 - 22:00 3_00 DRILL P SURF Directional drill from 636' to 916'. Sliding -50%.76 klbs up, 76 klbs down, 83 klbs rotate. WOB 35 klbs. Survey at 671' was in tolerence, surveys from 765' and on were outside of gravitational reference values due to the previous X-axis problem. The most probable cause is downhole vibration in the tool string causing erratic X-axis readings. Increased inclination may reduce or eliminate the downhole vibration 22:00 - 23:00 1.00 DRILL N DPRB SURF Pump Survey. Rig team in consulation with town engineering staff decided to drill ahead to base of the pell11afrost manually calculating X-axis gravitational correction. On the planned bit trip at -1660' pick up a new mud motor and MWD tools. Then reshoot the surveys on the trip in the hole to confill11 the inclination and azimuth. 23:00 - 00:00 1.00 DRILL P SURF Directional drill from 916' to 931'. Sliding -50%. Printed: 3/24/2003 9: 15: 1 0 AM ) ) BP EXPLORATION Operations Summary Report Page 2 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/27/2003 23:00 - 00:00 1.00 DRILL P SURF ADT = 4.75 hrs 2/28/2003 00:00 - 07:00 7.00 DRILL P SURF Directional drill from 931' to 1668'. Manually calculating X-axis gravitational correction. All surveys are within expected values based on drilling parameters. At 1099' sliding 30'- 75' a stand. The angle is on directional plan, the build is slightly ahead and above plan, rotating to hold angle and intersect the plan line. Azimuth is on directional plan. 88 klbs up, 71 klbs down, 79 klbs rotate. 640 GPm, 1720 psi. ART = 2.41 hrs AST = 3.78 hrs 07:00 - 07:30 0.50 DRILL P SURF Circulate hole clean. Monitor well - No Flow. 07:30 - 10:00 2.50 DRILL P SURF POH for planned bit trip at base of permafrost. CO motor, MWD, drop top string stabilizer, 100 klbs up, 69 klbs down. 10:00 - 10:30 0.50 DRILL P SURF Clean and clear rig floor 10:30 - 12:30 2.00 DRILL P SURF PU and MU BHA #3. PU Collar/jar stand RIH 12:30 - 15:00 2.50 DRILL P SURF RIH reshooting surveys every stand to 1663'. Survey data has the same X-axis vibrational problem as the previous two MWD tools. Decision made by rig team and town engineering staff to run a Sperry Electric Multishot survey tool to confirm MWD survey data. If the surveys match continue drilling to TO, manually calculating the X-axis gravitational correction. Then run Sperry EMS again on the way out of the hole to verify and correct bottomhole location. 15:00 - 16:30 1.50 DRILL P SURF Wash down last stand to 1668'. Circulate bottoms up, while reciprocationg DP @ 50 RPM. 620 GPM, 1320 psi. Reduce pump rate and circulate highside while rigging up Sperry multishot. 16:30 - 18:30 2.00 DRILL N DPRB SURF Drop multishot. POH Surveying every stand. Wipe through tight spots at 1560' and 1137'. Backream through tight spot from 1099' to 1004, 18:30 - 19:00 0.50 DRILL N DPRB SURF Stand back jars and collars. Retrieve multishot 19:00 - 19:30 0.50 DRILL N DPRB SURF Clean and clear rig floor. Download multishot surveys Sperry EMS surveys match MWD data within -.4 degrees inclination over the entire interval and azimuth is within -.6 degrees at bottom hole and with -3 degress over the entire interval. With the exception of one survey through a 7 degree dogleg. EMS will be run again at surface casing TO. 19:30 - 20:00 0.50 DRILL N DPRB SURF Rig service, top drive, blocks and crown 20:00 - 21 :00 1.00 DRILL N DPRB SURF RIH. Work through tight spot at 1108'. Attempt to work through tight spot at 1201', no success 21 :00 - 22:00 1.00 DRILL N DPRB SURF Ream through tight spot at 1208', 300 GPM, 530 psi, 50 RPM. work through and backream above the tight spot, no problem going through the second time. Continue RIH work through intermintent tight spots to 1570'. Wash last stand to bottom. 22:00 - 00:00 2.00 DRILL P SURF Directional drill from 1668' to 1818'. Sliding 40-50%, sliding high side to build 3 degrees per 100' angle. 89 klbs up, 73 klbs down, 79 klbs rotate. 640 GPM, 1516 psi, 35 klbs WOB. ART last 24 hrs. = 2.78 hrs. AST last 24 hrs. = 4.15 hrs. Printed: 3/2412003 9:15:10 AM \ ) ) BP EXPLORATION Operations Summary Report Page 3 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From~ To Hours Task Code NPT Phase Description· of Operations 2/28/2003 22:00 - 00:00 2.00 DRILL P SURF ADT = 11.68 hrs. 3/1/2003 00:00 - 12:00 12.00 DRILL P SURF Directional drill from 1818' to 3658'. Sliding 40-50%, sliding high side to build 3-4 degrees per 100'. 65.2 degrees inclination at TD. 100 klbs up, 76 klbs down, 90 klbs rotate. 650 GPM, 2050 psi, 35-40 klbs WOB. AST last 24 hrs. = 2.57 hrs. ART last 24 hrs = 4.62 hrs. ADT = 18.87 hrs. 12:00 - 12:30 0.50 DRILL P SURF Circulate hole clean. 650 GPM, 1885 psi. Reciprocate DP @ 50 RPM 12:30 - 15:30 3.00 DRILL P SURF POH for wiper trip to HWDP @ 630'. Wipe through tight spots at 3623' and 3000' 15:30 - 17:00 1.50 DRILL P SURF RIH. Work through intermintent tight spots from 2334' to 3565. Wash last stand to TD @ 3658 17:00 - 18:00 1.00 DRILL P SURF Circulate hole clean. 650 GPM, 1885 psi. Reciprocate DP @ 50 RPM. 18:00 - 20:30 2.50 DRILL P SURF Drop Sperry EMS survey tool. POH. Pulled 20 klbs ove at 2334' and 540'. Wipe through tight spots, no problems second time trhough. Survey every stand on POH 20:30 - 21 :00 0.50 DRILL P SURF Stand back HWDP. retrieve EMS tool. Stand back collars 21 :00 - 23:00 2.00 DRILL P SURF Break bit. LD MWD, stabilizer, motor 23:00 - 00:00 1.00 DRILL P SURF Clean and clear rig floor 3/2/2003 00:00 - 00:30 0.50 CASE P SURF PU casing hanger and landing joint. Make dummy run with casing hanger 00:30 - 02:00 1.50 CASE P SURF RU 10-3/4" casing equipment. RU Franks tool 02:00 - 02:30 0.50 CASE P SURF PJSM with BP, NAD, Nabors Casing, PES on running 10-3/4" casing 02:30 - 08:00 5.50 CASE P SURF Fill and check float equip. Run 10-3/4" 45.5# L-80 casing to TD. Shoe @ 3645'. Taking on weight intermintentlyfrom 1900' to TD. Land casing on hanger- OK 08:00 - 08:30 0.50 CEMT P SURF Rig down fill up tool. Blow down top drive, MU cement head 08:30 - 10:30 2.00 CEMT P SURF Circulate and condition hole prior to cement csg. Reciprocate pipe no problems - 170 klbs up, 103 klbs down 10:30 - 10:45 0.25 CEMT P SURF PJSM for cement job with crew & service companies 10:45 - 12:30 1.75 CEMT P SURF Pump 10 bbl water. Test lines to 3500 psi. Pump 10 bbl more water. Pump 75 bbl alpha spacer at 10.2 ppg - 5 bpm @ 200 psi. Release bottom plug. Mix and pump 551 bbl (745 sxs) Permafrost L lead slurry at 10.7 ppg - 5 bpm @ 250 psi increasing to 390 psi at the end. Swith to tail slurry. Mix and pump 112 bbls (542 sxs) Class G at 15.8 ppg. 5.5 bpm @ 500 psi. Pipe started sticking with 200 bbl lead around the shoe, casing landed 12:30 - 13:45 1.25 CEMT P SURF Release top plug HOWCO kick out with 10 bbl water to clear lines. Switch to rig pump and displace with mud at 8 bpm @ 600 psi initial increasing to 950 psi. At -150 bbl pumps cement returns back, divert to outside tank. Finish displacement and bump plug with 1450 psi as calculated. 185 bbls cement returns. Bleed off pressure - floats holding. CIP @ 13:30hrs. 13:45 - 15:00 1.25 CEMT P SURF RD cement head. Break out and lay down landing joint. Flush stacie RD casing equipment. Printed: 3/2412003 9: 15: 1 0 AM ') i' ') i BP EXPLORATION Operations Summary Report Page 4 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/2/2003 15:00 - 15:30 0.50 DIVRTR P PROD1 PJSM with crew on NO and setting out surf. riser, Hydrill 15:30 - 19:30 4.00 DIVRTR P PROD1 NO surf. riser I Hydrill. Remove riser and Hydrill from cellar 19:30 - 23:00 3.50 BOPSUR P PROD1 NU speed head, tbg spool and BOPE. Test metal to metal seal to 1000 psi. 23:00 - 23:30 0.50 BOPSUR P PROD1 RU ported sub and flush stack. 23:30 - 00:00 0.50 BOPSURP PROD1 RU BOPE test equipment 3/3/2003 00:00 - 04:00 4.00 BOPSUR P PROD1 Test BOP's and related surface equipment to 250 psi low and 4500 psi high, 5 min each. Test annular preventer to 250 psi low and 3500 psi high, 5 min each. BOP test witnessed by John Crisp AOGCC. 04:00 - 04:30 0.50 BOPSUR P PROD1 RD BOP test equipment. Install wear bushing 04:30 - 17:00 12.50 DRILL P PROD1 PU 5" DP, stand back in derrick 17:00 - 18:30 1.50 DRILL P PROD1 Cut and slip 60' of drilling line. Service top drive, blocks. Function test crown-o-matic. Function test H2S and gas alarms 18:30 - 22:00 3.50 DRILL P PROD1 PU and MU BHA. Shallow test rotary steerable tools, 500 gpm @ 510 psi. RIH with HWDP, shallow test MWD tools. 22:00 - 00:00 2.00 DRILL P PROD1 PU DP from pipe shed, RIH to 1030'. Pressure test TAM port collar to 1000 psi for 10 minutes. 3/4/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Continue PU DP and RIH to 3446'. Fill pipe and break circulation 01 :00 - 01 :30 0.50 DRILL P PROD1 Well kill (05) drill with Tour Pusher and Co. Rep. 01 :30 - 02:30 1.00 CASE P PROD1 Pressure test 10-3/4" casing to 3500 psi for 30 minutes - No losses. 02:30 - 03:00 0.50 DRILL P PROD1 Wash down from 3446'. Tag up at 3554. 03:00 - 05:30 2.50 DRILL P PROD1 Drill float equipment and shoe track. Tag float collar 3558', tag float shoe at 3643' 05:30 - 06:00 0.50 DRILL P PROD1 Drill rat hole and 20' of new hole to 3678' 06:00 - 06:30 0.50 DRILL P PROD1 Swap to new 9.7 ppg LSND mud. 06:30 - 07:00 0.50 DRILL P PROD1 Perform LOT to 14 P.P.G. mud with following: 580 PSI surface pressure 9.7 mud weight 2611 TVD Fluid pumped==2.3 Fluid returned==1.5 07:00 - 07:30 0.50 DRILL P PROD1 Get drilling parameters. Clean hole ECD =10.3 with 600 GPM 130 RPM. 118 up wt., 72 down, 95 rotating. 07:30 - 00:00 16.50 DRILL P PROD1 Drilling 9 7/8 hole from 3,678 to 5,699. Circulate sweeps every 200 ft. drilled. Backream each connection at 600 GPM and 120 to 140 RPM. P/U and circulate as needed to stay within .7 PPG over benchmarked "Clean hole ECD" of 1 0.4. Directionally 80 ft. to the left of the line. 3/5/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drill ahead in 9 7/8 production hole from 5,699 to 7,950. Pump Low-High barofibre sweeps (10 low 20 High) every 200 ft. until " Ghost Reamer" has passed through Ug1 and into Schrader. Reduced frequency to 400 ft. intervals thereafter. ECD's from 5,699 to 6,900 with 180 FPH: 2.5% cuttings load Actual ECD=10.95 average Cal. ECD===10.3 to 10.6. ECD's from 6,900 to 7,840 with 144 FPH 2.1 % cuttings load Actual ECD=10.75 Printed: 3/24/2003 9: 15: 1 0 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ') ) BP EXPLORATION Operations Summary Report Page 5 of 13 L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 3/5/2003 00:00 - 00:00 From - To Hours Task Code NPT Phase PROD1 Cal. ECD===10.5 3/6/2003 00:00 - 00:00 317/2003 00:00 - 21 :00 Description of Operations 24.00 DRILL P Drilled app. 5 ft. from 7,840 to 7,845 @ 5' per hour. Logs showed high resistivity in this section. The top of the "OA" had been picked at 7,830. Drilled with following parameters: GPM====600 to 620 RPM====90-150 TRQ====13,OOO to 20,000 WOB===10-20 Up=====205K Down==80K String==121 K Down== 24.00 DRILL P PROD1 Directional drill in 9 7/8 production hole from 7950 to 9920. Added app. 1 % EP mudlube for torque control while drilling ahead @ 8600. Pumping 25 bbls. high vis., barofibre sweeps every 400 ft. to assist hole cleaning. Very minimal increase of cuttings seen with sweeps. Begin back reaming only bottom 30 ft. starting at 8723. Calculated ECD 10.5 with an actual of 10.8. WOB===15-25 GPM====620 @ 2,700 RPM====80 to 140 TRQ on==17,500 TRQ off==16.500 Rotary steerable settings: 7952 to 8415 Toolface @ 71 20% D.L. per 100' .62 to 2.46 8415 to 8789 Toolface @ 45 40% D.L. per 100' .32 to 3.03 8789 to 9070 Toolface @ 60 60% D.L. per 100' .64 to 2.29 9070 to 9261 Toolface @ 3980% D.L. per 100' .96 to 2.29 9261 to 9356 Toolface @ 18100 D.L. per 100' 2.34 9356 to 9638 Toolface @ 2240% D.L. per 100' .51 to 2.43 9638 to 9827 Toolface @ 31560 D.L. per 100' .63 to .7 9827 to 9920 Toolface @ 29980 D.L per 100' .89 21.00 DRILL P PROD1 Drilling production hole from 9970 to 11,282, pumping 25 bbl. barofibre sweeps every 400. Adding water at 30-40 BPH to control MBT. Unable to control dropping tendency of BHA with 100% manipulation up on rotary steerable. Dropping app. 1.5 degrees per 100. Suspect dull/damaged bit. Drilling parameters: WOB===15-25 RPM==== 140 Printed: 312412003 9: 15: 1 0 AM ) ) BP EXPLORATION Operations Summary Report Page 6 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/7/2003 00:00 - 21 :00 21.00 DRILL P PROD1 GPM====620 @ 2820 TRQ====11,800/14,500 Cal ECD=10.3 Actual ECD 10.84 21 :00 - 22:30 1.50 DRILL P PROD1 Pump 25 bbl. Hi vis. sweep S-S while adding 600 bbl. mud dilution to system. Rotate/Reciprocate string while pumping sweep around at 620 GPM and 140 RPM. No significant increase of cutting with sweep. Pump until hole is clean as per shakers and PWD tool. Observe well. 22:30 - 00:00 1.50 DRILL P PROD1 POH 10 stands with 5 to 10K bumps off bottom. Pump dry job. Continue TOH to 8,884. 3/8/2003 00:00 - 03:30 3.50 DRILL P PROD1 Continue TOH from 8884 to shoe at 3644. Hole began minor swabbing at app. 5,300 ft. Worked pipe out with 10-20K overpulls with hole taking proper displacement. Began pumping out at 4,830 with 325 GPM @ 510 PSI. 03:30 - 05:30 2.00 DRILL P PROD1 Backream out from 4,260 @ 600 GPM and 80 RPM. Wall cake and some cuttings seen at bottoms up. 05:30 - 06:00 0.50 DRILL P PROD1 CBU at 620 GPM while rotating pipe inside casing. Pump dry job. 06:00 - 08:00 2.00 DRILL P PROD1 Continue TOH from casing shoe. 08:00 - 11 :30 3.50 DRILL P PROD1 Stand back HWDP. Remove nuke source. Download BHA. Test bias unit with 580 GPM of mud. Layout remaining BHA. Break and grade bit. Bit Grade: 3 4 WT I X I CT BHA 11 :30 - 12:00 0.50 DRILL P PROD1 Clear floor of all vendors excess equipment and ready rig floor for next operation. 12:00 -13:00 1.00 DRILL P PROD1 Pull wear ring and drain stack. Service Top Drive. 13:00 - 17:30 4.50 BOPSUR P PROD1 Perform weekly BOP test to 250-4500. Witness of test waived by AOGCC representative, "Jeff Jones". 17:30 - 20:30 3.00 DRILL P PROD1 PJSM P/U and M/U BHA # 5 with new rotary steerable system and rebuilt Hycalog 110 HGNV. RIH with HWDP and shallow test BHA. 20:30 - 22:00 1.50 DRILL P PROD1 TIH to casing shoe @ 3644, picking up 27 single from pipeshed. (These 27 singles were required to be layed down on TOH, due to setback capabilities of rig) 22:00 - 00:00 2.00 DRILL P PROD1 Slip and cut drilling line. Adjust brakes. Service topdrive and adjust/test "Crown-o-matic". Bring bottoms up while performing service work to rig @ 100 SPM 500 PSI. 3/9/2003 00:00 - 01 :00 1.00 DRILL P PROD1 RIH to 6,500 with no adverse hole conditions. 01 :00 - 01 :30 0.50 DRILL P PROD1 Break circulation and move 250 bbls. mud uphole. Staged pump up to 525 GPM @ 1780 PSI. Maintain ECD's under 11.2. Final ECD 10.82. @ 525 GPM. 01 :30 - 02:00 0.50 DRILL P PROD1 RIH from 6,500 to 8,700 with no adverse hole conditons. 02:00 - 03:00 1.00 DRILL P PROD1 Circulate bottoms up at 8,700. Stage pumps up to 620 GPM @ 2,200 while rotating/reciprocating string at 40 RPM. No fluids lost to wellbore during circ.. Initial ECD's 11.2 with a final of 10.9. Some cuttings and wall cake seen with bottoms up. 03:00 - 04:00 1.00 DRILL P PROD1 RIH from 8,700 to 11,282 with no adverse hole conditons or fill. Wash last stand to bottom. 04:00 - 06:30 2.50 DRILL P PROD1 Stage pumps up to drilling rate of 610 GPM. Initial ECD @ 420 GPM was 11.2 .. Final ECD prior to sending command to rotary steerable was 10.75. Lots of thick mud and wall cake Printed: 3/2412003 9:15:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/9/2003 3/1 0/2003 3/1112003 ) '') 1 BP EXPLORATION Operations Summary Report Page 7 of 13 L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 From - To Hours Task Code NPT Phase 04:00 - 06:30 06:30 - 20:30 20:30 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 07:00 07:00 - 08:30 08:30 - 14:00 14:00 - 16:30 16:30 - 00:00 00:00 - 03:00 Description of Operations 2.50 DRILL P 14.00 DRILL P PROD1 seen with bottoms up, along with some cuttings. PROD1 Drill ahead in 9 7/8 production hole from 11,282 to 12,500. Pumping sweeps every 400 ft. as needed for hole cleaning. Building angle back up as per program. Backreaming 30 ft. on each stand with pumps at 510 GPM on down stroke. WOB===10 to 25 RPM====110 to 130 TRQ====13,OOO/17,OOO GPM====610 @ 2830 Up=210K DWN=120K ROT=155K PROD1 Add 600 bbls. of 11.7 spike fluid @ 11 BPM 1,650 PSI.. System now weighted to 10.5 with 3 ppb. baratrol and 4 ppb Baranex. Cal. ECD's prior to mud swap were 10.22 with 11.08 after. Perform slow pump rates after new mud is around. PROD1 Drill ahead in 9 7/8 production hole from 12,500 to 12,570. Backreaming 30 ft. per connection at reduced flowrate. Calculated ECD==11.08 Actual ECD==11.43. PROD1 Drill 9 7/8 production hole from 12,570 to 12,839. Began getting Gamma saturation from HRZ. Data questionable. Begin 3 degree per hundred drop at 12,600. PROD1 Pull up to 12,632 and MAD pass to confirm Gamma tool functioning properly and collect missed data. Hole in good shape. PROD1 Drill 9 7/8 production hole from 12,839 to 13,112. Pump sweeps at 400 ft. intervals for hole cleaning. Minumul additional cuttings seen with sweeps. Hole packed off after making a connection, while drilling 10ft. into new stand @ 13,112. Work stand back out and set back in derrick. Lost 20 bbls. to well. Cal. ECD's 11.1 Actual ECD's 11.52. No indicators led up to pack off. ECD's had been consistant at .4 to .45 over calculated. Drilling parameters: WOB====20-25 RPM=====120-140 GPM=====610@2990 TRQ on===18-22,000 TRQ off===13-15,OOO Up===235 Down===127 String==170 PROD1 Stage up pumps to full drilling rate and bring sweep out of hole. Ground up, very fine cutting seen with bottoms up. Geologist confirmed cuttings were 90% HRZ. No large sizes indicating cavings into wellbore. No losses to hole with full drilling rate. Wash back to bottom with no additional pack off symptoms. PROD 1 Drill 9 7/8 production hole from 13,112 to 13,411. Adjust sweep frequency to every 200 ft. and begin reaming full stand after connections. Reduce flowrate to 85% of drilling rate on downreaming. PROD1 Circulate sweep S-S and lower YP of mud in preparation for cement plugs. PROD1 POH with no adverse hole conditons. Hole in good shape. Remove ghost reamer. Reamer had no additonal wear on this run. PROD1 POH laying down BHA. Break and grade bit. 2 1 CT N X I NO TD 2.00 DRILL P 1.50 DRILL P 2.50 DRILL P 1.00 DRILL P 3.50 DRILL P 1.50 DRILL P 5.50 DRILL P 2.50 DRILL P 7.50 DRILL P 3.00 DRILL P Printed: 3/24/2003 9:15:10 AM ) ') BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/11/2003 00:00 - 03:00 3.00 DRILL P PROD1 Clear floor of all vendors excess equipment and ready floor for next operation. 03:00 - 03:30 0.50 BOPSUR P PROD1 Service wear bushing. No problems removing. 03:30 - 05:30 2.00 STKOH C PROD1 RIH with 5" mule shoe on 5" DP. Pick up needed singles from pipeshed 1X1. TIH from derrick to casing shoe. 05:30 - 06:00 0.50 STKOH C PROD1 Break circ. and stage pumps up to 10 bpm @ 300 PSI. 06:00 - 08:00 2.00 STKOH C PROD1 RIH from shoe to 6500, breaking circulation every 20 stands run in hole. Hole in good shape. 08:00 - 08:30 0.50 STKOH C PROD1 Circulate 250 bbls. up hole at 6,500. Stage up from 6 bpm to 10 bpm. 6 BPM @ 284== 8 BPM @ 404==10 BPM @ 565. Up wt. 136K Down wt. 89K 08:30 - 10:00 1.50 STKOH C PROD1 RIH from 6,500 to 8,700. Circulate down every 20 stands. 10:00 - 11 :00 1.00 STKOH C PROD1 Break circulation and stage pumps up to 600 GPM with no losses. Bring bottoms up. Mud coming back beginning to get thick. No increase in cuttings. 4BPM==310 6BPM==380 8BPM==530 11 :00 - 14:00 3.00 STKOH C PROD1 RIH from 8,700 to 13,411 washing down every 20 stands. No adverse hole conditions or fill. 14:00 - 17:30 3.50 STKOH C PROD1 Condition mud for cement job. Lower YP to 16. Stage pumps up to 10 BPM @ 1350 PSI. Slow down rate at bottoms up, shakers running over. Mud very thick. Hole in good shape. Up wt.===230 Down===115 PJSM with Halliburton. 17:30 - 18:30 1.00 STKOH C PROD1 Pump 5 bbls. water and test lines to 3,500. Pump 15 bbls. water 52 bbls. 15.8 ppg. class "G" cement and 5 bbls. water. Chase cement with 213 bbls. mud to balance cement plug. 18:30 - 19:30 1.00 STKOH C PROD1 Pull out of hole to 12,476. 19:30 - 21 :30 2.00 STKOH C PROD1 Drop DP wiper plug and CBU at 600 GPM @ 1,500 PSI with no mud losses. Spot 500 bbls. 10.7 mud in pipe and chase with 133 bbls. to balance for trip. 21 :30 - 23:00 1.50 STKOH C PROD1 POH to 9008 for Form-A-Plug spotting. 23:00 - 00:00 1.00 STKOH C PROD1 Break circulation and stage pumps up to 10 BPM @ 1050. No losses. Hook up lines and prepare for Form-a-plug spotting. 3/1212003 00:00 - 02:00 2.00 STKOH C PROD1 Prepare to spot Form-a-plug from 9000 ft.. Pump 25 Hi-vis spacer, 17 bbls. Form-a-plug, 6 bbls. Hi-Vis spacer. Flush lines with 2 bbls. water and chase with 140 bbls. mud to balance plug. POH with 2 stands at app. 3 minutes a stand while pumping app. 2 bbls. per stand. Pull up one stand with no pump to a depth of 8725. 02:00 - 02:30 0.50 STKOH C PROD1 Flush pipe @ 8725 with 2 DP volumes at 500 GPM @ 820. Up 160K Down 92K. Pump dry job. No fluids lost to wellbore during circulation. 02:30 - 05:00 2.50 STKOH C PROD1 POH from 8725 to shoe to lay down excess DP while waiting on Form-a-plug to set. Recommended waiting period per M I is 6 to 8 hours. 05:00 - 08:00 3.00 STKOH C PROD1 POH from 10 3/4" shoe LD 114 jts excess 5" DP. 08:00 - 09:30 1.50 STKOH C PROD1 Monitor well - stable. MU mule shoe & RIH to shoe. 09:30 - 10:00 0.50 STKOH C PROD1 Service top drive & crown. Printed: 3/2412003 915: 1 0 AM ) ). BP EXPLORATION Operations Summary Report Page 9 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/12/2003 10:00 - 11 :00 1.00 STKOH C PROD1 Slip & cut 98' drilling line - clean under drawworks. 11 :00 - 14:30 3.50 STKOH C PROD1 Cont RIH below shoe to 8720'. Break circ every 20 stands. 14:30 - 17:30 3.00 STKOH C PROD1 Wash down from 8720 to 8850 @ 25 RPM, 45 SPM, 300 PSI. No wt. or pressure increase indicating Form-a-plug. Stage up to 620 GPM with no fluid losses. Seeing large size chunks of Plug with consistency of soft set silicone. 17:30 - 19:00 1.50 STKOH C PROD1 Position mule shoe at 8850. Test lines to 3,500. Pump 20 bbls. water, 101 bbls. class "G" cement and 5 bbls. water behind. Displace with rig pumps to balance point with 8 BPM. No losses to well during cementing operations. CIP @ 18:45. 19:00 - 20:00 1.00 STKOH C PROD1 POH slowly from 8850 to 7793. Up wt. 165. No overpulls while cementing or tripping operations. 20:00 - 21 :00 1.00 STKOH C PROD1 Stage pumps up to 600 GPM at 1000 PSI. No losses and no cement. 21 :00 - 23:00 2.00 STKOH C PROD1 Wash down from 7793 to 8050 at 275 GPM 280 PSI looking for cement. Begin seeing slight pressure increase and 5-7K downdrag at 8002. Bring rate up to 500 GPM and continue down to 8050. Circulate up 100 bbls clabbered mud @ 10.7 ppg. and 11 PH. Clean shakers, trough and auger. Ready pits for plug # 3. 23:00 - 00:00 1.00 STKOH C PROD1 PJSM for plug # 3. Pump 20 bbls. water, 100 bbls. class "G" cement and 5 bbls. water behind. Displace with rig pumps to plug balance point, with 8 bpm 190 to 520 psi. No losses during spotting of plug. CIP @ 00:00 Hrs. 3/13/2003 00:00 - 01 :00 1.00 STKOH C PROD1 Pull slowly out of cement to 7217. Break pipe and install DP wiper plug. 01 :00 - 03:00 2.00 STKOH C PROD1 Drop wiper plug and CBU at 350 to 600 GPM staging up with no losses. App. 75 bbls. cement contaminated mud back, starting at 600 stks. before bottoms up. Dump thick clabbered mud. Clean shakers, possum belly, troughs etc., etc.. PH of mud at bottoms up 12.3 with a 10.7 wt. 03:00 - 04:00 1.00 STKOH C PROD1 PJSM. Pressure test lines on rig to 3,500. Pump 20 bbls. water, 117 bbls. 15.8 class "G" cement and 5 bbls. water. Displace with rig pumps to plug balance point, @ 8 BPM from 190 to 480 PSI. CIP @ 04:00. 04:00 - 05:00 1.00 STKOH C PROD1 Pull up out of cement plug, slowly, to 5960. Pulled off bottom with 140K. 05:00 - 06:30 1.50 STKOH C PROD1 Drop wiper ball and pump down pipe at 300 GPM at 225 psi. Stage pumps up to 600 GPM @ 700 psi to clear backside. 06:30 - 08:00 1.50 STKOH C PROD1 Monitor well. Pump dry job. POH to 10 3/4" shoe at 3643' to WOC. 08:00 - 14:30 6.50 STKOH C PROD1 Perform rig maintenance while WOC at shoe. Chg gear lube oil and filter plus hydraulic oil filter on top drive. Perform annual PM on drawworks. Clean suction screens on mud pumps. Swaco rep adjusted position of counterbalance weights and motor assemblies on shakers to improve performance. 14:30 - 16:00 1.50 STKOH C PROD1 RIH from casing shoe to 6050 and stand on cement plug with 10K. 16:00 - 17:00 1.00 STKOH C PROD1 Circulate bottoms up at 600 GPM 690 PSI. Up wt.==140 Own. wt.==83. 17:00 - 18:00 1.00 STKOH C PROD1 POH to 4000 ft. and prepare for mud swap. 18:00 - 19:00 1.00 STKOH C PROD1 Displace well to new 9.7 LSND mud. 19:00 - 20:30 1.50 STKOH C PROD1 POH. Test choke mainifold on trip out. Printed: 312412003 9:15:10 AM ) ') BP EXPLORATION Operations Summary Report Page 10 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2003 20:30 - 21 :00 0.50 STKOH C PROD1 Pick up ported pup jt. and flush stack. Remove wear ring. 21 :00 - 00:00 3.00 BOPSURC PROD1 Test BOP's as per policy 250-4500. Witness of test waived by AOGCC. 3/14/2003 00:00 - 03:30 3.50 STKOH C PROD1 P/U and orient and shallow test BHA with 8 3/4 bit, 1.15 motor, Dir/GRlPWD/Res realtime, and DENS/NEU recorded. 03:30 - 05:00 1.50 STKOH C PROD1 RIH to 3,832 filling pipe at the shoe. Hole in good shape. Up== 119K Down==76K 05:00 - 00:00 19.00 STKOH C PROD1 Begin trenching hole from 3,832 to 3,848 with 160 Left toolface. Drill from 3,848 to 6,450. WOB==1-15 GPM==600 @ 2050 TRQ on==8-10K TRQ off==8K Calculated ECD==10.80 Actual==11.6. Average slides yeilding 4 to 6 degrees per 100. Backreaming and circulating as needed on connections to control ECD spikes. Pumping sweeps every 200 to 300 ft. as hole dictates. ART==3.69 AST==3.61 ADT==7.3 3/15/2003 00:00 - 00:00 24.00 STKOH C PROD1 Drill 8 3/4 production hole from 6450 to 8888 . Pumping sweeps every 200-300 ft. as hole dictates. Adding lubricants to control TRQ. Backream each connection at 610 GPM on up stroke and 525 on down. Circulate as needed on each connection to keep ECD's within .6 to .9 of calculated. ART==9.38 AST==1.29 GPM==600 @ 2650 off WOB==15-25 RPM==70-100 Up==205 DWN==118 ROT==150. 3/16/2003 00:00 - 14:30 14.50 STKOH C PROD1 Drilling 8 3/4 production hole from 8888 to 10215. Back off sweep intervals from 200 to 400 ft., String in 300 bbls. spike fluid to bring system up from 9.7 to 10.. Spike fluid treated with 3 ppg Baranex and 4 ppg. Barotrol. WOB==15-25 GPM==600 @ 3150 on bottom TRQ==19,OOO on and 17,000 off Cal. ECD==10.9 Actual ECE==11.5 AST==4.32 ART==4.8 14:30 - 17:30 3.00 STKOH C PROD1 Circulate sweep S-S. at 610 GPM 2740 PSI. Rotate at 100 RPM. Calculated ECD ==10.89 Actual ECD==11.23. Up wt.== 255K. Down wt==130 17:30 - 21 :00 3.50 STKOH C PROD1 POH to casing shoe. Hole in good shape. Minor 10-25K overpulls from 5330 to 5300 on TOH. 21 :00 - 22:30 1.50 STKOH C PROD1 Slip and cut drilling line. Perform topdrive service. 22:30 - 00:00 1.50 STKOH C PROD1 RIH from casing shoe to 3840. Set down while going into new hole. 3/17/2003 00:00 - 02:00 2.00 STKOH C PROD1 Work through at 3,840. (open hole sidetrack area) Turn string 90 degrees clockwise. Get into new hole with no problems. RIH with no adverse hole conditons or fill to 10,130. Topdrive up and prepare to precautionary wash and ream to bottom, @ 10,215. Hole in good shape. 02:00 - 04:00 2.00 STKOH C PROD1 Stage pumps up to 600 GPM and pump sweep S-S while rotating/ reciprocating @ 100 RPM. Torque at 21,000 on bottom while rotating. Up wt. 240K Down wt. 130K String 175K. Lower YP to 15 and condition mud to run 7" long string. 04:00 - 07:00 3.00 STKOH P PROD1 Observe well and POH 1 x1 to 9250. Pump dry job and continue POH 1 x1 to base of Schrader @ app. 7.100. 07:00 - 08:30 1.50 STKOH P PROD1 Spot mud treated with 30 ppb "Steel Seal" from 7100 to casing shoe @ 3644. Spot at 330 GPM @ 800 PSI, 80 RPM, 140 string wt. and 13,500 torque. Pump dry job. Observe well. Printed: 3/24/2oo39:15:10AM ') ') BP EXPLORATION Operations Summary Report: Page 11 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/17/2003 08:30 - 15:00 6.50 STKOH P PROD1 POH 1 x 1 with 5" drillpipe. 15:00 - 19:00 4.00 STKOH P PROD1 Layout BHA. PJSM prior to removing nuke source. Break and grade bit. Clear floor of all excess vendors equipment. Bit grade==2 3 CT T X I wT TO 19:00 - 20:00 1.00 CASE P COMP P/U ported "Circ. Joint" for flushing stack. Flush stack and wear ring area. Pull wear ring and install test plug. 20:00 - 21 :30 1.50 BOPSUR P COMP Change top rams to 7" and test door seals to 3,500. 21 :30 - 00:00 2.50 CASE P COMP PJSM. P/U landing joint and perform "Dummy run". RIU long bails, 350 Ton slips/elevators and Franks Tool. 3/18/2003 00:00 - 05:30 5.50 CASE P COMP P/U conventional shoe track set for single stage cement job. Check floats. RIH to 3640 (casing shoe) with 7" L-80 26 #. Fill every 5 jts. Break circ. for 5 minutes on each 15 jts. run. Torque pipe to 8,000. Place 1 ea. RA marker above Kuparuk "B" and "C" Tops. 05:30 - 06:00 0.50 CASE P COMP Break circ slowly and stage up pumps to CBU. Circulate 1.5 times casing capacity - 6 bpm @ 320 psi. 115k up. 80k dn. 06:00 - 08:00 2.00 CASE P COMP Cont running casing to 4956' - 1 min/jt. Break circ every 5 jts. Circ 15 min every 15 jts. Started pushing mud away at -4300'. Slow to 1.5 min/jt. 08:00 - 09:00 1.00 CASE P COMP CBU at 4956'.5 bpm @ 375 psi.132k up. 84k dn. 09:00 - 11 :30 2.50 CASE P COMP Run casing to to 6175' - 150 jts in. Still getting back about 1/2 pipe displacement to jt. #145. Broke circ OK for 15 min at 145 jts in but by jt #150 getting almost no displacement back. Attempt to break circ but unable to circ at 150 jts in. 11 :30 - 12:30 1.00 CASE P COMP Attempt to get circulation while working string. No go. Pipe is free - 175k up 85k dn but no success getting returns. 12:30 - 16:00 3.50 CASE P COMP Pull 5 jts. Try to get circ - no go. Pull 5 jts. Try to get circ - no go. Pull 5 more jts & try to circ - no go. Pull 15 jts up to 4920' - finally able to establish circ at 3.5 bpm but losing about 1.5 bpm. Mud returns very thick with abundant steel seal. 16:00 - 16:30 0.50 CASE P COMP Increase circulation rate to 5 bpm, losing about 0.5 bpm. 16:30 -17:00 0.50 CASE P COMP Increase circulation rate to 6.5 bpm, gaining about 0.5 bpm. Well giving back fluid pumped away attempting to establish circulation. 17:00 - 17:30 0.50 CASE P COMP Circulate and condition mud - levelled out with no loss / no gain. Continue circ and get complete circulation surface to surface @ 6.5 bpm. 17:30 - 00:00 6.50 CASE P COMP Run casing to 6337' - 154 jts in. Stage pumps to 6.5 bpm and . circulate every joint in at approximately 3 minutes per joint. CBU every 10 joints at 6.5 bpm. 3/19/2003 00:00 - 12:30 12.50 CASE P COMP Cont run casing to 9231' - 225 jts in. Stage pumps to 6.5 bpm and circulate every joint in at approximately 3 minutes per joint. CBU every 10 joints at 6.5 bpm. After running casing below the steel seal pill spotted at @ 7100', attempt to CBU every 15 jts. 12:30 - 13:00 0.50 CASE P COMP CBU @ 9231'. Reciprocate casing while circulating, no problems on down stroke casing pulled to 400 klbs on up stroke, pulled free, worked casing. 13:00 - 15:00 2.00 CASE P COMP Cont run casing to 9750' - 237 jts in. Stage pumps to 6.5 bpm and circulate every joint in at approximately 3 minutes per joint. 15:00 - 16:00 1.00 CASE P COMP Casing packed off @ 9750', no returns. Pull 370 klbs to free casing. Work string, regain circulation. Packed off again, no returns. Pull 402 klbs to free casing, regain circulation. Printed: 3/2412003 915: 1 0 AM ) ) .-.. .~ BP EXPLORATION Operations Summary Report Page 12 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/19/2003 16:00 - 16:30 0.50 CASE P COMP CBU @ 7 bpm, 600 psi. while working jt. #238.310 klbs up, 108 klbs down. 16:30 - 18:00 1.50 CASE P COMP Cont run casing to 10198' - 248 jts in. Stage pumps to 6.5 bpm and circulate every joint in at approximately 3 minutes per joint. Packed off @ 9790' and again @ 9910' free casing and regain circ. Continue in to bottom and land casing 18:00 - 18:30 0.50 CEMT P COMP Rig down csg fill up tool. Blow down top drive. Rig up cement head. 18:30 - 21 :00 2.50 CEMT P COMP Stage pumps to 7 bpm, 700 psi, to circulate and condition mud for cement job. Reciprocate casing 15' while circulating. 335 klbs up, 115 klbs down. 21 :00 - 21 :30 0.50 CEMT P COMP PJSM with Co. Rep, TP, HOWCO, Nabors and Baroid personel regarding cementing operations 21 :30 - 21 :45 0.25 CEMT P COMP Pump 5 bbl spacer and test lines to 4500 psi. Casing landed prior to testing lines, unable to reciprocate casing after test. 21 :45 - 21 :50 0.08 CEMT P COMP Pump 35 bbl, 11.5 ppg alpha spacer 21 :50 - 22:20 0.50 CEMT P COMP Drop bottom plug. Pump 150 bbls (360 sxs) Microlite 12.5 ppg lead cement @ 5 bpm. Full returns throughout. 22:20 - 22:30 0.17 CEMT P COMP Pump 33 bbls (160 sxs) Class G 15.8 ppg tail slurry. Full returns throughout. 22:30 - 23:45 1.25 CEMT P COMP Wash down cement lines through T. Drop top plug. Kick out with rig pump and displace with 386.5 bbls seawater @ 7 bpm. Reduce rate to 3 bpm prior to bumping. Bump plugs with 500 psi over final circulating pressure of 1600 psi at calculated strokes. full returns throughout cement job. Cement in placë @ 23:45 hrs 23:45 - 00:00 0.25 CASE P COMP Rig Up test pump to pressure test casing to 4500 psi 3/20/2003 00:00 - 00:30 0.50 CASE P COMP Pressure test casing to 4500 psi for 30 minutes - OK. 00:30 - 01 :30 1.00 CEMT P COMP Bleed off pressure and confirm floats holding - OK. Rig down cement head and equipment. Blow down lines 01 :30 - 02:30 1.00 WHSUR P COMP Install packoff. Pressure test to 5000 psi for 10 minutes 02:30 - 03:00 0.50 WHSUR P COMP Rig up ported sub, flush stack. MU and install test plug 03:00 - 04:00 1.00 BOPSUR P COMP Change out upper pipe rams. Install 3-1/2" X 6" variable rams 04:00 - 05:00 1.00 BOPSURP COMP RU test equipment. test upper pipe rams 250 psi low and 4500 psi high for 10 minutes each. RD test equipment 05:00 - 06:00 1.00 RUNCOM> COMP Cut and slip 90' of drilling line. 06:00 - 08:00 2.00 RUNCOM> COMP Change out top drive bails. Make dummy run with tubing hanger. RU tubing equipment 08:00 - 08:30 0.50 RUNCOM> COMP PJSM with Co. Rep, TP, Nabors Casing, Baker, NAD regarding tubing running procedures and precautions. 08:30 - 18:00 9.50 RUNCOM> COMP Run 3.5" 9.2# tubing and all associated jewelry as per tubing running order. While running tubing established annular injectivity by performing LOT on the 7" X 10-3/4" annulus. Injected 70 bbls of 10.3 ppg mud at the 10-3/4" csg. shoe with a leak off pressure of 500 psi. Calculated equivalent MW of 14.0 ppg 18:00 - 18:30 0.50 RUNCOM> COMP Land tubing - 125 klbs up, 65 klbs down. Run in lock down screws. RU to reverse circulate. 18:30 - 20:30 2.00 RUNCOM> COMP Reverse circulate 260 bbls clean seawater followed by 130 bbls corrosion inhibited seawater @ 3 bpm , 300 psi 20:30 - 21 :30 1.00 RUNCOM=> COMP Drop ball I rod. LD landing joint. Close blind rams and pump to seat ball. Pressure up to set packer and pressure test tubing to 4500 psi for 30 min - OK. Printed: 3124/2003 9: 15: 1 0 AM ) ) Page 13 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date L-121 L-121 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 3/20/2003 3/21/2003 From - To Hours Task Code NPT Phase 21 :30 - 22:30 1.00 RUNCOtItP COMP 22:30 - 23:00 0.50 RUNCOtItP COMP 23:00 - 23:30 0.50 RUNCOtItP COMP 23:30 - 00:00 0.50 BOPSUR P COMP 00:00 - 01 :00 1.00 BOPSURP COMP 01 :00 - 02:00 1.00 WHSUR P COMP 02:00 - 04:00 2.00 WHSUR P COMP 04:00 - 05:00 1.00 WHSUR P COMP 05:00 - 05:30 0.50 WHSUR P COMP 05:30 - 09:00 3.50 WHSUR P COMP 09:00 - 10:00 1.00 WHSUR P COMP 10:00 - 12:00 2.00 WHSUR P COMP Start: 2/25/2003 Rig Release: 3/21/2003 Rig Number: Spud Date: 2/27/2003 End: 3/21/2003 Descri ption of· Operations Bleed tubing pressure to 2000 psi. Pressure test annulus to 4500 psi for 30 min. - OK. Bleed off tubing and annulus pressure. Pressure up on annulus to shear OCK valve. Sheared @ 2900 psi. Set TWC and test to 2800 psi from below - OK. NO BOPE. NO BOPE Move tree and adapter flange into cellar and warm NU tree and adapter flange. Test tree, adapter flange and tubing hanger to 5000 psi for 10 minutes - OK RU OSM, pull TWC with lubricator, RO same PJSM Co. Rep, TP, little Red, NAO on procedures and precautions for freeze protecting Freeze protect 3.5" X 7" annulus - reverse circulate 170 bbl diesel @ 3 bpm, 400 psi ICP, 700 psi FCP, allow to U-tube. Freeze protect 10.75" X 7" annulus - inject 135 bbl129 degree dead crude @ 3 bpm, 700 psi ICP, 1000 psi FCP RU OSM, install BPV with lubricator. Pressure test from below with Little Red to 1000 psi - OK. Secure tree and cellar Rig released @ 12:00 hrs Printed: 3/2412003 9: 15: 1 0 AM ANADRILL SCHLUMBERGER Survey report Client........... ........: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Borealis Well.....................: L-121 API number. . . . . . . . . . . . . . .: 50-029-23138-00 Engineer. . . . . . . . . . . . . . . . .: E. Roux 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.......: 47.90 ft KB above permanent.......: N/A Top Drive DF above permanent.......: 76.40 ft ----- Vertical section origin---------------- La tit ude ( + N / S -) . . . . . . . . . : 0 . 0 0 f t Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.3500805 Departure (+E/W-)........: W 149.3251975 Azimuth from rotary table to target: 211.47 degrees [(c)2003 Anadrill IDEAL ID6 lC_10] 10-Mar-2003 20:54:18 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey... ....: MD of last survey.... ....: Page 1 of 6 27-Feb-03 10-Mar-03 149 0.00 ft 13411.00 ft ----- Geomagnetic data ---------------------- Magnetic model......... ..: BGGM version 2002 Magnetic date..... '" ....: 26-Dec-2002 Magnetic field strength..: 1149.71 HCNT Magnetic dec (+E/W-)... ..: 25.81 degrees Magnetic dip.............: 80.77 degrees ----- MWD survey Reference Reference G....... .......: Reference H..... .........: Reference Dip............: Tolerance of G... ........: Tolerance of H... ........: Tolerance of Dip. ........: Criteria --------- 1002.68 mGal 1150.21 HCNT 80.78 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).. ...: 25.63 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-). ...: 25.63 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ... .....: No degree: 0.00 -,/ ANADRILL SCHLUMBERGER Survey Report 10-Mar-2003 20:54:18 Page 2 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 142.00 0.88 170.54 142.00 141.99 0.82 -1.08 0.18 1.09 170.54 0.62 EMS IFR MSA - 3 207.00 0.94 170.54 65.00 206.99 1.60 -2.09 0.35 2.12 170.54 0.09 EMS IFR MSA - 4 354.70 4.23 170.54 147.70 354.52 6.64 -8.66 1.44 8.78 170.54 2.23 EMS IFR MSA - 5 447.17 6.19 172.17 92.47 446.60 13.07 -16.97 2.68 17.18 171.01 2.13 EMS IFR MSA 6 539.39 7.98 174.72 92.22 538.11 22.05 -28.27 3.95 28.54 172.05 1.97 EMS IFR MSA - 7 633.83 10.99 180.34 94.44 631.25 35.01 -43.80 4.50 44.03 174.13 3.33 EMS IFR MSA - 8 727.65 13.58 188.38 93.82 722.92 52.80 -63.65 2.84 63.71 177.44 3.30 EMS IFR MSA ~ - 9 821.17 15.03 197.34 93.52 813.55 74.66 -86.09 -2.37 86.12 181.58 2.83 EMS IFR MSA - 10 916.13 18.26 199.41 94.96 904.52 101.16 -111.88 -10.99 112.42 185.61 3.46 EMS IFR MSA 11 1008.95 20.68 201.71 92.82 992.03 131.54 -140.83 -21.89 142.52 188.83 2.73 EMS IFR MSA - 12 1042.00 22.61 204.37 33.05 1022.75 143.59 -152.03 -26.67 154.35 189.95 6.52 EMS IFR MSA - 13 1102.58 25.89 206.73 60.58 1077.98 168.33 -174.46 -37.42 178.42 192.11 5.66 EMS IFR MSA - 14 1197.01 28.37 207.51 94.43 1162.01 211.27 -212.77 -57.06 220.29 195.01 2.65 EMS IFR MSA - 15 1291.79 29.96 206.24 94.78 1244.77 257.30 -253.98 -77.93 265.66 197.06 1.80 MWD IFR MSA 16 1385.40 30.60 204.18 93.61 1325.62 304.21 -296.68 -98.02 312.45 198.28 1.30 EMS IFR MSA - 17 1479.53 32.82 202.40 94.13 1405.69 353.17 -342.13 -117.56 361.76 198.96 2.56 EMS IFR MSA - 18 1572.81 37.35 201.11 93.28 1482.00 406.00 -391.92 -137.39 415.30 199.32 4.92 EMS IFR MSA - 19 1665.39 41.70 200.06 92.58 1553.40 463.84 -447.07 -158.08 474.20 199.47 4.75 EMS IFR MSA - 20 1758.08 43.00 201.95 92.69 1621.90 525.24 -505.35 -180.47 536.61 199.65 1.96 MWD IFR MSA 21 1851.21 44.52 203.68 93.13 1689.16 588.91 -564.71 -205.46 600.93 199.99 2.08 EMS IFR MSA - 22 1944.53 46.30 205.22 93.32 1754.68 654.87 -625.20 -232.97 667.20 200.44 2.24 EMS IFR MSA - -~ 23 2038.29 49.07 207.02 93.76 1817.79 723.89 -687.43 -263.51 736.20 200.97 3.28 EMS IFR MSA - 24 2131.95 48.97 207.61 93.66 1879.21 794.41 -750.25 -295.96 806.52 201.53 0.49 EMS IFR MSA - 25 2225.05 49.81 207.74 93.10 1939.81 864.93 -812.84 -328.79 876.82 202.02 0.91 EMS IFR MSA 26 2318.50 51.58 208.60 93.45 1999.01 937.11 -876.58 -362.93 948.74 202.49 2.02 EMS IFR MSA - 27 2412.50 54.96 208.89 94.00 2055.22 1012.36 -942.62 -399.16 1023.65 202.95 3.60 EMS IFR MSA - 28 2504.66 56.37 208.10 92.16 2107.20 1088.35 -1009.50 -435.46 1099.42 203.33 1.69 EMS IFR MSA - 29 2594.36 57.55 208.52 89.70 2156.10 1163.43 -1075.70 -471.12 1174.35 203.65 1.37 EMS IFR MSA - 30 2688.39 60.60 208.47 94.03 2204.42 1243.98 -1146.59 -509.60 1254.73 203.96 3.24 EMS IFR MSA [(c)2003 Anadrill IDEAL ID6 lC_10] ANADRILL SCHLUMBERGER Survey Report 10-Mar-2003 20:54:18 Page 3 of 6 -------- ------ ------- ------ -------- --------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 qual (ft) (deg) (deg) (ft) (ft) (ft) ( ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2782.02 61.20 209.18 93.63 2249.96 1325.70 -1218.26 -549.04 1336.26 204.26 0.92 EMS IFR MSA - 32 2876.50 62.92 210.37 94.48 2294.22 1409.12 -1290.70 -590.49 1419.36 204.58 2.13 EMS IFR MSA - 33 2972.25 63.98 210.82 95.75 2337.02 1494.77 -1364.43 -634.09 1504.57 204.93 1.18 EMS IFR MSA - 34 3067.17 66.18 210.98 94.92 2377.01 1580.84 -1438.29 -678.29 1590.20 205.25 2.32 EMS IFR MSA - 35 3159.89 66.48 210.69 92.72 2414.24 1665.75 -1511.20 -721.82 1674.74 205.53 0.43 EMS IFR MSA 36 3191.44 66.54 210.63 31.55 2426.81 1694.69 -1536.09 -736.58 1703.56 205.62 0.26 EMS IFR MSA - 37 3254.65 66.31 210.17 63.21 2452.09 1752.61 -1586.06 -765.89 1761.30 205.78 0.76 EMS IFR MSA - 38 3286.58 66.31 210.21 31.93 2464.92 1781.84 -1611.33 -780.60 1790.46 205.85 0.11 EMS IFR MSA - 39 3348.56 65.95 210.42 61.98 2490.00 1838.51 -1660.26 -809.21 1846.97 205.98 0.66 EMS IFR MSA - 40 3442.00 65.25 209.71 93.44 2528.60 1923.58 -1733.91 -851.84 1931.85 206.16 1.02 EMS IFR MSA 41 3535.00 65.21 210.32 93.00 2567.57 2007.99 -1807.03 -894.08 2016.11 206.33 0.60 EMS IFR MSA - 42 3601.15 67.07 210.95 66.15 2594.33 2068.48 -1859.07 -924.90 2076.44 206.45 2.94 MWD IFR MSA - 43 3663.67 66.44 209.68 62.52 2619.00 2125.91 -1908.66 -953.90 2133.76 206.55 2.12 MWD IFR MSA - 44 3758.57 66.97 210.60 94.90 2656.53 2213.05 -1984.04 -997.67 2220.76 206.70 1.05 MWD IFR MSA - 45 3852.18 67.63 210.34 93.61 2692.66 2299.39 -2058.47 -1041.46 2306.93 206.84 0.75 MWD IFR MSA 46 3947.06 68.39 210.51 94.88 2728.18 2387.36 -2134.33 -1086.01 2394.74 206.97 0.82 MWD IFR MSA - 47 4041.47 68.50 211.31 94.41 2762.87 2475.16 -2209.67 -1131.12 2482.35 207.11 0.80 MWD IFR MSA - 48 4133.98 68.67 211.38 92.51 2796.65 2561.28 -2283.22 -1175.92 2568.25 207.25 0.20 MWD IFR MSA - 49 4228.00 67.42 211.06 94.02 2831.80 2648.48 -2357.79 -1221.12 2655.24 207.38 1.37 MWD IFR MSA 50 4320.32 66.74 210.76 92.32 2867.75 2733.51 -2430.75 -1264.80 2740.12 207.49 0.80 MWD IFR MSA - 51 4414.83 66.05 209.94 94.51 2905.60 2820.09 -2505.48 -1308.55 2826.61 207.58 1.08 MWD IFR MSA 52 4507.63 65.64 209.57 92.80 2943.57 2904.73 -2578.99 -1350.58 2911.23 207.64 0.57 MWD IFR MSA - 53 4602.06 65.39 209.77 94.43 2982.71 2990.62 -2653.66 -1393.12 2997.11 207.70 0.33 MWD IFR MSA -~ - 54 4695.72 65.25 209.01 93.66 3021.82 3075.67 -2727.81 -1434.88 3082.18 207.75 0.75 MWD IFR MSA 55 4790.40 65.23 208.57 94.68 3061.47 3161.55 -2803.16 -1476.29 3168.14 207.77 0.42 MWD IFR MSA 56 4883.73 65.05 208.12 93.33 3100.71 3246.11 -2877.69 -1516.49 3252.82 207.79 0.48 MWD IFR MSA - 57 4976.88 64.87 208.34 93.15 3140.13 3330.37 -2952.04 -1556.41 3337.21 207.80 0.29 MWD IFR MSA - 58 5069.47 63.92 208.49 92.59 3180.15 3413.75 -3025.48 -1596.15 3420.70 207.81 1.04 MWD IFR MSA - 59 5163.79 63.54 209.14 94.32 3221.89 3498.23 -3099.59 -1636.91 3505.27 207.84 0.74 MWD IFR MSA 60 5257.81 62.76 210.02 94.02 3264.36 3582.07 -3172.54 -1678.31 3589.11 207.88 1.18 MWD IFR MSA - [(c)2003 Anadrill IDEAL ID6 1C_10] ANADRILL SCHLUMBERGER Survey Report 10-Mar-2003 20:54:18 Page 4 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5350.71 61.40 211.66 92.90 3307.86 3664.14 -3243.02 -1720.39 3671.09 207.95 2.14 MWD IFR MSA - 62 5444.19 60.86 212.75 93.48 3352.99 3746.00 -3312.28 -1764.01 3752.73 208.04 1.17 MWD IFR MSA - 63 5537.77 60.55 214.15 93.58 3398.78 3827.56 -3380.38 -1808.99 3833.98 208.15 1.35 MWD IFR MSA - 64 5632.89 59.93 215.16 95.12 3446.00 3910.00 -3448.30 -1855.95 3916.03 208.29 1.13 MWD IFR MSA - 65 5726.74 60.26 215.17 93.85 3492.79 3991.19 -3514.81 -1902.80 3996.81 208.43 0.35 MWD IFR MSA 66 5820.98 61.96 213.95 94.24 3538.32 4073.57 -3582.76 -1949.60 4078.86 208.55 2.13 MWD IFR MSA - 67 5916.46 63.25 213.22 95.48 3582.25 4158.29 -3653.38 -1996.49 4163.31 208.66 1.51 MWD IFR MSA - 68 6010.21 64.22 213.10 93.75 3623.74 4242.32 -3723.76 -2042.47 4247.12 208.74 1.04 MWD IFR MSA - - 69 6104.63 65.65 211.73 94.42 3663.74 4327.83 -3795.96 -2088.31 4332.48 208.82 2.01 MWD IFR MSA - 70 6200.24 66.83 210.94 95.61 3702.26 4415.34 -3870.70 -2133.82 4419.90 208.87 1.45 MWD IFR MSA 71 6294.33 67.15 212.52 94.09 3739.04 4501.94 -3944.36 -2179.36 4506.39 208.92 1.58 MWD IFR MSA - 72 6386.40 67.46 214.00 92.07 3774.57 4586.83 -4015.38 -2225.95 4591.09 209.00 1.52 MWD IFR MSA - 73 6482.38 67.18 213.43 95.98 3811.57 4675.32 -4089.04 -2275.10 4679.35 209.09 0.62 MWD IFR MSA - 74 6577.85 66.87 214.04 95.47 3848.84 4763.15 -4162.14 -2323.91 4766.97 209.18 0.67 MWD IFR MSA - 75 6673.36 66.65 215.51 95.51 3886.53 4850.76 -4234.22 -2373.97 4854.31 209.28 1.43 MWD IFR MSA 76 6767.38 67.18 214.79 94.02 3923.39 4937.07 -4304.94 -2423.76 4940.36 209.38 0.90 MWD IFR MSA - 77 6860.93 68.05 213.62 93.55 3959.02 5023.47 -4376.48 -2472.38 5026.55 209.46 1.48 MWD IFR MSA - 78 6956.45 68.24 215.35 95.52 3994.58 5112.00 -4449.55 -2522.58 5114.87 209.55 1.69 MWD IFR MSA - 79 7047.92 68.41 215.44 91.47 4028.36 5196.80 -4518.84 -2571.81 5199.44 209.65 0.21 MWD IFR MSA - 80 7139.96 68.22 215.95 92.04 4062.37 5282.10 -4588.30 -2621.71 5284.49 209.74 0.55 MWD IFR MSA 81 7231.80 67.58 214.44 91.84 4096.93 5367.00 -4657.83 -2670.75 5369.20 209.83 1.68 MWD IFR MSA - 82 7325.92 67.64 213.31 94.12 4132.78 5453.95 -4730.09 -2719.26 5456.01 209.89 1.11 MWD IFR MSA 83 7420.95 68.01 212.77 95.03 4168.65 5541.92 -4803.86 -2767.24 5543.88 209.94 0.65 MWD IFR MSA ~ - 84 7512.74 68.25 213.18 91.79 4202.84 5627.07 -4875.32 -2813.60 5628.95 209.99 0.49 MWD IFR MSA 85 7604.90 68.25 211.60 92.16 4236.99 5712.66 -4947.60 -2859.45 5714.47 210.03 1.59 MWD IFR MSA 86 7698.90 68.47 212.02 94.00 4271.66 5800.03 -5021.85 -2905.51 5801.81 210.05 0.48 MWD IFR MSA - 87 7791.49 69.31 213.09 92.59 4305.00 5886.39 -5094.65 -2951.99 5888.10 210.09 1.41 MWD IFR MSA - 88 7884.82 69.21 211.99 93.33 4338.06 5973.65 -5168.23 -2998.94 5975.30 210.13 1.11 MWD IFR MSA - 89 7979.77 68.08 211.75 94.95 4372.63 6062.08 -5243.33 -3045.63 6063.69 210.15 1.21 MWD IFR MSA - 90 8073.02 67.22 211.66 93.25 4408.09 6148.32 -5316.70 -3090.95 6149.90 210.17 0.93 MWD IFR MSA [(c)2003 Anadrill IDEAL ID6 1C_10] ANADRILL SCHLUMBERGER Survey Report 10-Mar-2003 20:54:18 Page 5 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8165.97 66.34 211.66 92.95 4444.74 6233.74 -5389.41 -3135.79 6235.29 210.19 0.95 MWD IFR MSA 92 8257.78 65.24 210.47 91.81 4482.39 6317.47 -5461.13 -3179.00 6319.02 210.20 1.68 MWD IFR MSA - 93 8349.97 63.60 210.23 92.19 4522.19 6400.61 -5532.88 -3221.01 6402.17 210.21 1.79 MWD IFR MSA - 94 8442.31 63.62 209.12 92.34 4563.23 6483.28 -5604.75 -3261.97 6484.88 210.20 1.08 MWD IFR MSA - 95 8536.96 63.39 209.40 94.65 4605.46 6567.93 -5678.65 -3303.37 6569.58 210.19 0.36 MWD IFR MSA 96 8630.87 63.10 211.28 93.91 4647.74 6651.76 -5751.02 -3345.72 6653.43 210.19 1.81 MWD IFR MSA 97 8723.63 63.00 211.54 92.76 4689.78 6734.45 -5821.59 -3388.82 6736.09 210.20 0.27 MWD IFR MSA - 98 8819.34 62.68 211.84 95.71 4733.47 6819.61 -5894.05 -3433.55 6821.22 210.22 0.44 MWD IFR MSA - --" 99 8912.26 62.48 211.65 92.92 4776.26 6902.09 -5964.19 -3476.95 6903.67 210.24 0.28 MWD IFR MSA - 100 9003.93 62.48 212.87 91.67 4818.62 6983.37 -6032.94 -3520.34 6984.92 210.26 1.18 MWD IFR MSA 101 9098.87 62.59 214.92 94.94 4862.41 7067.53 -6102.85 -3567.31 7068.99 210.31 1.92 MWD IFR MSA - 102 9194.99 62.55 217.12 96.12 4906.69 7152.57 -6171.85 -3617.48 7153.87 210.38 2.03 MWD IFR MSA - 103 9290.43 63.63 219.33 95.44 4949.89 7237.07 -6238.70 -3670.14 7238.18 210.47 2.35 MWD IFR MSA 104 9384.22 65.15 221.20 93.79 4990.43 7320.65 -6303.22 -3724.80 7321.53 210.58 2.42 MWD IFR MSA - 105 9477.70 64.96 221.61 93.48 5029.86 7404.13 -6366.80 -3780.86 7404.80 210.70 0.45 MWD IFR MSA 106 9572.54 64.65 221.81 94.84 5070.23 7488.58 -6430.86 -3837.96 7489.05 210.83 0.38 MWD IFR MSA 107 9665.59 64.72 222.92 93.05 5110.02 7571.18 -6493.01 -3894.64 7571.49 210.96 1.08 MWD IFR MSA - 108 9761.07 65.24 222.01 95.48 5150.40 7656.11 -6556.83 -3953.05 7656.28 211.09 1.02 MWD IFR MSA 109 9854.93 65.37 220.79 93.86 5189.62 7740.11 -6620.80 -4009.44 7740.19 211.20 1.19 MWD IFR MSA - 110 9946.25 65.91 219.00 91.32 5227.28 7822.40 -6684.62 -4062.80 7822.43 211.29 1.88 MWD IFR MSA 111 10040.57 66.36 217.97 94.32 5265.45 7908.00 -6752.14 -4116.47 7908.02 211.37 1.11 MWD IFR MSA 112 10135.40 65.79 216.38 94.83 5303.91 7994.25 -6821.20 -4168.85 7994.25 211.43 1.65 MWD IFR MSA - --' 113 10231.03 65.28 214.70 95.63 5343.51 8081.07 -6892.03 -4219.44 8081.07 211.48 1.69 MWD IFR MSA - 114 10324.63 65.38 213.15 93.60 5382.58 8166.05 -6962.60 -4266.91 8166.05 211.50 1.51 MWD IFR MSA - 115 10418.55 65.15 211.14 93.92 5421.88 8251.34 -7034.82 -4312.30 8251.34 211.51 1.96 MWD IFR MSA 116 10511.41 64.69 211.97 92.86 5461.24 8335.44 -7106.49 -4356.31 8335.45 211.51 0.95 MWD IFR MSA 117 10606.54 64.85 211.96 95.13 5501.79 8421.50 -7179.50 -4401.87 8421.50 211.51 0.17 MWD IFR MSA - 118 10700.06 65.71 211.76 93.52 5540.90 8506.44 -7251.65 -4446.71 8506.44 211.52 0.94 MWD IFR MSA - 119 10793.57 66.13 211.37 93.51 5579.06 8591.81 -7324.39 -4491.40 8591.82 211.52 0.59 MWD IFR MSA - 120 10888.31 65.44 212.04 94.74 5617.91 8678.22 -7397.90 -4536.80 8678.22 211.52 0.97 MWD IFR MSA [(c)2003 Anadrill IDEAL ID6 1C_10] ANADRILL SCHLUMBERGER Survey Report 10-Mar-2003 20:54:18 Page 6 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 10982.94 64.61 212.32 94.63 5657.87 8763.99 -7470.50 -4582.49 8764.00 211.53 0.92 MWD IFR MSA - 122 11076.60 63.93 212.39 93.66 5698.53 8848.35 -7541.78 -4627.64 8848.36 211.53 0.73 MWD IFR MSA - 123 11169.97 62.74 213.17 93.37 5740.43 8931.77 -7611.93 -4672.81 8931.78 211.54 1.48 MWD IFR MSA - 124 11215.63 62.10 213.01 45.66 5761.57 8972.22 -7645.83 -4694.91 8972.23 211.55 1.44 MWD IFR MSA - 125 11263.45 61.38 213.66 47.82 5784.21 9014.32 -7681.03 -4718.05 9014.33 211.56 1.92 MWD IFR MSA 126 11357.01 61.77 213.78 93.56 5828.75 9096.54 -7749.46 -4763.73 9096.55 211.58 0.43 MWD IFR MSA - 127 11449.91 61.56 213.69 92.90 5872.84 9178.24 -7817.46 -4809.14 9178.27 211.60 0.24 MWD IFR MSA - 128 11542.74 61.69 212.81 92.83 5916.96 9259.88 -7885.77 -4853.92 9259.91 211.61 0.85 MWD IFR MSA -/ - 129 11634.85 61.84 213.07 92.11 5960.53 9341.00 -7953.87 -4898.05 9341.04 211.63 0.30 MWD IFR MSA - 130 11728.68 63.54 212.87 93.83 6003.58 9424.34 -8023.81 -4943.42 9424.38 211.64 1.82 MWD IFR MSA 131 11822.74 66.22 212.54 94.06 6043.51 9509.48 -8095.47 -4989.43 9509.52 211.65 2.87 MWD IFR MSA - 132 11915.56 67.46 212.53 92.82 6080.01 9594.80 -8167.42 -5035.32 9594.85 211.65 1.34 MWD IFR MSA - 133 12008.83 67.95 212.36 93.27 6115.40 9681.09 -8240.25 -5081.62 9681.14 211.66 0.55 MWD IFR MSA 134 12102.88 67.62 211.77 94.05 6150.96 9768.15 -8314.03 -5127.84 9768.21 211.67 0.68 MWD IFR MSA - 135 12195.09 67.80 211.15 92.21 6185.93 9853.47 -8386.81 -5172.37 9853.53 211.66 0.65 MWD IFR MSA 136 12284.68 67.85 210.57 89.59 6219.75 9936.43 -8458.03 -5214.93 9936.48 211.66 0.60 MWD IFR MSA - 137 12378.27 67.70 210.05 93.59 6255.15 10023.05 -8532.82 -5258.65 10023.09 211.64 0.54 MWD IFR MSA - 138 12471.74 67.42 209.19 93.47 6290.83 10109.39 -8607.92 -5301.35 10109.43 211.63 0.90 MWD IFR MSA - 139 12567.80 66.73 210.32 96.06 6328.25 10197.82 -8684.73 -5345.25 10197.86 211.61 1.30 MWD IFR MSA - 140 12663.15 65.49 211.19 95.35 6366.86 10285.00 -8759.65 -5389.83 10285.02 211.60 1.55 MWD IFR MSA - 141 12757.79 63.37 210.70 94.64 6407.71 10370.36 -8832.86 -5433.73 10370.38 211.60 2.29 MWD IFR MSA - 142 12851.73 59.57 211.38 93.94 6452.57 10452.87 -8903.57 -5476.27 10452.90 211.59 4.09 MWD IFR MSA - 143 12945.85 55.45 210.88 94.12 6503.11 10532.24 -8971.50 -5517.31 10532.27 211.59 4.40 MWD IFR MSA '-' - 144 13039.61 52.21 210.80 93.76 6558.44 10607.92 -9036.48 -5556.11 10607.94 211.59 3.46 MWD IFR MSA - 145 13134.18 49.17 210.72 94.57 6618.35 10681.08 -9099.35 -5593.53 10681.09 211.58 3.22 MWD IFR MSA 146 13227.33 46.43 210.88 93.15 6680.91 10750.07 -9158.62 -5628.86 10750.09 211.57 2.94 MWD IFR MSA 147 13320.13 43.61 210.86 92.80 6746.50 10815.70 -9214.96 -5662.54 10815.72 211.57 3.04 MWD IFR MSA - 148 13344.73 42.95 211.37 24.60 6764.41 10832.57 -9229.40 -5671.25 10832.58 211.57 3.04 MWD IFR MSA 149 13411.00 42.95 211.37 66.27 6812.92 10877.72 -9267.95 -5694.76 10877.73 211.57 0.00 Projected to TD [(c)2003 Anadrill IDEAL ID6 1C_10] i. bo f L-121 Survey Report - Geodetic SChI.bepger Report Date: 10·Mar-Q3 Survey / DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section A¡imuth: 211.470° Field: Prudhoe Bay Unit· WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 f1 Structure / Slot: L-Pad / L-121 TVD Reference Datum: KB Well: L-121 TVD Reference Elevation: 76.400 ft relative to MSL Borehole: L-121 Sea Bed / Ground Level Elevation: 44.100 ft relative to MSL UWIIAPI#: 500292313800 Magnetic Declination: +25.616° Survey Name / Date: L·121 I March 10, 2003 Total Field Strength: 57510.598 nT Tort / AHD / 001/ ERD ratio: 198.989° /10913.16 ft /6.631/1.602 Magnetic Dip: 80.784° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: March 06, 2003 L.ocation Lat/L.ong: N 70.35008050, W 149.3251975€ Magnetic Declination Model: BGGM 2002 L.ocation Grid NIE VIX: N 5978078.150 ftUS, E 583115.890 ftUS North Reference: True North Grid Convergence Angle: +0.63550853° Total Carr Mag North -> True North: +25.616° Grid Scale Factor: 0.99990785 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station 10 MD Incl Azim TVD VSec N/-S E/-W DL.S Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978078.15 583115.89 N 70.35008050 W 149.32519756 142.00 0.88 170.54 141.99 0.82 -1.08 0.18 0.62 5978077.08 583116.08 N 70.35007756 W 149.32519611 207.00 0.94 170.54 206.99 1.60 -2.09 0.35 0.09 5978076.06 583116.26 N 70.35007478 W 149.32519473 354.70 4.23 170.54 354.52 6.64 -8.66· 1.44 2.23 5978069.50 583117.43 N 70.35005683 W 149.32518584 447.17 6.19 172.17 446.60 13.07 -16.97 2.68 2.13 5978061.21 583118.76 N 70.35003414 W 149.32517578 539.39 7.98 174.72 538.11 22.05 -28.27 3.95 1.97 5978049.93 583120.15 N 70.35000327 W 149.32516550 633.83 10.99 180.34 631.25 35.01 -43.80 4.50 3.33 5978034.41 583120.87 N 70.34996083 W 149.32516103 727.65 13.58 188.38 722.92 52.80 -63.65 2.84 3.30 5978014.55 583119.44 N 70.34990662 W 149.32517450 821.17 15.03 197.34 813.55 74.66 -86.09 -2.37 2.83 5977992.05 583114.47 N 70.34984531 W 149.32521683 916.13 18.26 199.41 904.52 101.16 -111.88 -10.99 3.46 5977966.17 583106.14 N 70.34977485 W 149.32528677 1008.95 20.68 201.71 992.03 131.54 -140.83 -21.89 2.73 5977937.10 583095.57 N 70.34969577 W 149.32537523 1042.00 22.60 204.36 1022.75 143.59 -152.03 -26.67 6.52 5977925.84 583090.91 N 70.34966515 W 149.32541402 1102.58 25.89 206.73 1077.98 168.33 -174.46 -37.42 5.66 5977903.31 583080.41 N 70.34960390 W 149.32550131 1197.01 28.37 207.51 1162.01 211.27 -212.77 -57.06 2.65 5977864.78 583061.20 N 70.34949922 W 149.32566073 1291.79 29.96 206.24 1244.77 257.30 -253.98 -77.92 1.80 5977823.35 583040.79 N 70.34938665 W 149.32583011 1385.40 30.60 204.18 1325.62 304.21 -296.68 -98.02 1.30 5977780.43 583021.18 N 70.34926999 W 149.32599323 1479.53 32.82 202.40 1405.69 353.17 -342.13 -117.56 2.56 5977734.77 583002.15 N 70.34914584 W 149.32615181 1572.81 37.35 201.11 1482.00 406.00 -391.92 -137.39 4.92 5977684.77 582982.87 N 70.34900980 W 149.32631281 ~-121 ASP Final Survey.xls ! Schlumberger Private Page 1 of 5 3/19/2003-5: 12 PM .--- -' Grid Coordinates Geographic Coordinates Station ID MD Inel Azim. TVD VSec NI-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (O'10OO) (ftUS) (nus) 1665.39 41.70 200.06 1553.40 463.84 -447.07 -158.08 4.75 5977629.39 582962.80 N 70.34885913 W 149.32648073 1758.08 43.00 201.95 1621.90 525.24 -505.35 -180.47 1.96 5977570.87 582941.05 N 70.34869991 W 149.32666247 1851.21 44.52 203.68 1689.16 588.91 -564.71 -205.45 2.08 5977511 .24 582916.73 N 70.34853774 W 149.32686528 1944.53 46.30 205.22 1754.68 654.87 -625.20 -232.97 2.24 5977450.46 582889.89 N 70.34837249 W 149.32708862 2038.29 49.07 207.02 1817.79 723.88 -687.43 -263.51 3.28 5977387.90 582860.04 N 70.34820249 W 149.32733650 2131.95 48.97 207.61 1879.21 794.41 -750.25 -295.96 0.49 5977324.73 582828.30 N 70.34803086 W 149.32759985 2225.05 49.81 207.74 1939.81 864.93 -812.84 -328.78 0.91 5977261.79 582796.17 N 70.34785986 W 149.32786628 2318.50 51.58 208.60 1999.01 937.11 -876.58 -362.92 2.02 5977197.68 582762.74 N 70.34768573 W 149.32814337 2412.50 54.96 208.89 2055.22 1012.36 -942.62 -399.15 3.60 5977131.25 582727.25 N 70.34750530 W 149.32843741 2504.66 56.37 208.10 2107.20 1088.35 -1009.51 -435.45 1.69 5977063.97 582691.70 N 70.34732258 W 149.32873203 '-" 2594.36 57.55 208.52 2156.10 1163.43 -1075.70 -471.12 1.37 5976997.39 582656.78 N 70.34714173 W 149.32902145 2688.39 60.60 208.47 2204A2 1243.97 -1146.59 -509.59 3.24 5976926.09 582619.09 N 70.34694808 W 149.32933373 2782.02 61.20 209.18 2249.96 1325.70 -1218.26 -549.04 0.92 5976853.99 582580.45 N 70.34675226 W 149.32965384 2876.50 62.92 210.37 2294.22 1409.12 -1290.70 -590.49 2.13 5976781.10 582539.81 N 70.34655436 W 149.32999025 2972.25 63.98 210.82 2337.02 1494.76 -1364.43 -634.09 1.18 5976706.90 582497.03 N 70.34635293 W 149.33034403 3067.17 66.18 210.98 2377.01 1580.84 -1438.29 -678.29 2.32 5976632.56 . 582453.66 N 70.34615114 W 149.33070276 3159.89 66.48 210.69 2414.24 1665.75 -1511.20 -721.82 0.43 5976559.18 582410.94 N 70.34595193 W 149.33105598 3191.44 66.54 210.63 2426.81 1694.68 -1536.09 -736.57 0.26 5976534.13 582396.47 N 70.34588393 W 149.33117572 3254.65 66.31 210.17 2452.09 1752.61 -1586.06 -765.89 0.76 5976483.84 582367.71 N 70.34574741 W 149.33141362 3286.58 66.31 210.21 2464.92 1781.84 -1611.34 -780.59 0.11 597645B.41 582353.29 N 70.34567836 W 149.33153293 3348.56 65.95 210.42 2490.00 1838.51 -1660.26 -809.20 0.66 5976409.17 582325.23 N 70.34554469 W 149.33176508 3442.00 65.25 209.71 2528.61 1923.58 -1733.91 -851.83 1.02 5976335.06 582283.42 N 70.34534349 W 149.33211101 3535:00 65.21 210.31 2567.57 2007.99 -1 B07.03 -894.07 0.59 5976261.49 582242.00 N 70.34514371 W 149.33245371 3601.15 67.07 210.95 2594.33 2068.48 -1859.08 -924.89 2.95 5976209.10 582211.76 N 70.34500150 W 149.33270381 3663.67 66.44 209.68 2619.00 2125.91 -1908.67 -953.89 2.12 5976159.20 582183.32 N 70.34486602 W 149.33293909 3758.57 66.97 210.60 2656.53 2213.05 -1984.05 -997.65 1.05 5976083.35 582140.40 N 70.34466008 W 149.33329421 .~ 3852.18 67.63 210.34 2692.66 2299.39 -2058.48 -1041.44 0.75 5976008.44 582097.44 N 70.34445672 W 149.33364952 3947.06 68.39 210.51 2728.18 2387.36 -2134.34 -1086.00 0.82 5975932.10 582053.73 N 70.34424946 W 149.33401100 4041.47 68.50 211.31 2762.87 2475.16 -2209.6B -1131.10 0.80 5975856.27 582009.47 N 70.34404363 W 149.33437696 4133.98 68.67 211.38 2796.65 2561.28 -2283.23 -1175.90 0.20 5975782.23 581965.49 N 70.34384267 W 149.33474044 4228.00 67.42 211.06 2831.80 2648.48 -2357.80 -1221.10 1.37 5975707.17 581921.13 N 70.34363892 W 149.33510715 4320.32 66.74 210.76 2867.75 2733.51 -2430.75 -1264.78 0.80 5975633.75 581878.26 N 70.34343960 W 149.33546152 4414.83 66.05 209.94 2905.60 2820.09 -2505.49 -1308.54 1.08 5975558.54 581835.34 N 70.34323542 W 149.33581653 4507.63 65.64 209.57 2943.57 2904.73 -2579.00 -1350.56 0.57 5975484.58 581794.14 N 70.34303458 W 149.33615745 4602.06 65.39 209.77 2982.71 2990.62 -2653.67 -1393.10 0.33 5975409.45 581752.43 N 70.34283056 W 149.33650255 Schlumberger Private L-121 ASP Final Survey.xls Page 2 of 5 3/19/2003-5: 12 PM Grid Coordinates Geographic Coordinates , , Station ID MD Incl A2lm TVD VSec NI-S EJ·W DLS Northing Easting Latitu~e Longitude (ft) n (0) (ft) (ft) (ft) (ft) ("/10Oft) (ftUS) (ftUS) 4695.72 65.25 209.01 3021.82 3075.67 -2727.82 -1434.87 0.75 5975334.84 581711.50 N 70.34262797 W 149.33684135 4790.40 65.23 208.57 3061.47 3161.55 -2803.17 -1476.27 0.42 5975259.05 581670.93 N 70.34242210 W 149.33717724 4883.73 65.05 208.12 3100.71 3246.11 -2877.69 -1516.48 0.48 5975184.08 581631.56 N 70.34221847 W 149.33750337 4976.88 64.87 208.34 3140.13 3330.37 -2952.05 -1556.40 0.29 5975109.30 581592.47 N 70.34201532 W 149.33782719 5069.47 63.92 208.49 3180.15 3413.74 -3025.49 -1596.13 1.04 5975035.43 581553.56 N 70.34181467 W 149.33814947 5163.79 63.54 209.14 3221.89 3498.23 -3099.59 -1636.90 0.74 5974960.88 581513.62 N 70.34161219 W 149.33848012 5257.81 62.76 210.02 3264.36 3582.07 -3172.55 -1678.30 1.18 5974887.49 581473.03 N 70.34141287 W 149.33881597 5350.71 61.40 211.66 3307.86 3664.14 -3243.02 -1720.37 2.14 5974816.55 581431.75 N 70.34122031 W 149.33915723 5444.19 60.86 212.75 3352.99 3746.00 -3312.29 -1764.00 1.17 5974746.81 581388.90 N 70.34103105 W 149.33951109 5537.77 60.55 214.15 3398.78 3827.56 -3380.38 -1808.98 1.35 5974678.23 581344.68 N 70.34084500 W 149.33987595 , >' 215.16 3446.00 3910.00 -3448.31 -1855.93 1.13 5974609.80 581298.49 N 70.34065940 W 149.34025679 - 5632.89 59.93 5726.74 60.26 215.17 3492.79 3991.19 -3514.81 -1902.79 0.35 5974542.78 581252.38 N 70.34047768 W 149.34063684 5820.98 61.96 213.95 3538.32 4073.57 -3582.77 -1949.58 2.13 5974474.32 581206.34 N 70.34029201 W 149.34101641 5916.46 63.25 213.22 3582.25 4158.29 -3653.39 -1996.47 1.51 5974403.19 581160.24 N 70.34009905 W 149.34139672 6010.21 64.22 213.10 3623.74 4242.32 -3723.77 -2042.46 1.04 5974332.31 581115.05 N 70.33990674 W 149.34176967 6104.63 65.65 211.73 3663.74 4327.83 -3795.97 -2088.30 2.01 5974259.61 581070.02 N 70.33970946 W 149.34214144 6200.24 66.83 210.94 3702.26 4415.34 -3870.71 -2133.80 . 1.45 5974184.38 581025.35 N 70.33950524 W 149.34251047 6294.33 67.15 212.52 3739.04 4501.93 -3944.36 -2179.35 1.58 5974110.23 580980.63 N 70.33930398 W 149.34287984 6386.40 67.46 214.00 3774.57 4586.83 -4015.39 -2225.93 1.52 5974038.70 580934.84 N 70.33910991 W 149.34325763 6482.38 67.18 213.43 3811.58 4675.32 -4089.05 -2275.09 0.62 5973964.50 580886.51 N 70.33890863 W 149.34365627 6577.85 66.87 214.04 3848.84 4763.15 -4162.15 -2323.90 0.67 5973890.88 580838.51 N 70.33870890 W 149.34405213 6673.36 66.65 215.51 3886.53 4850.76 -4234.23 -2373.95 1.43 5973818.25 580789.27 N 70.33851193 W 149.34445803 6767.38 67.18 214.79 3923.39 4937.07 -4304.95 -2423.74 0.90 5973746.99 580740.27 N 70.33831869 W 149.34486183 6860.93 68.05 213.62 3959.02 5023.47 -4376.49 -2472.37 1.48 5973674.92 580692.44 N 70.33812321 W 149.34525612 6956.45 68.24 215.35 3994.58 5112.00 -4449.56 -2522.56 1.69 5973601.31 580643.07 N 70.33792354 W 149.34566315 7047.92 68.41 215.44 4028.36 5196.80 -4518.85 -2571.80 0.21 5973531 .48 580594.61 N 70.33773419 W 149.34606240 '- 7139.96 68.22 215.95 4062.37 5282.09 -4588.31 -2621.70 0.55 5973461.48 580545.49 N 70.33754439 W 149.34646705 7231.80 67.58 214.44 4096.93 5367.00 -4657.84 -2670.74 1.68 5973391.41 580497.22 N 70.33735438 W 149.34686474 7325.92 67.64 213.31 4132.78 5453.95 -4730.09 -2719.25 1.11 5973318.63 580449.53 N 70.33715695 W 149.34725803 7420.95 68.01 212.77 4168.65 5541.92 -4803.86 -2767.23 0.65 5973244.34 580402.37 N 70.33695537 W 149.34764706 7512.74 68.25 213.18 4202.84 5627.07 -4875.33 -2813.59 0.49 5973172.38 580356.81 N 70.33676010 W 149.34802297 7604.90 68.25 211.60 4236.99 5712.66 -4947.60 -2859.44 1.59 5973099.60 580311.77 N 70.33656259 W 149.34839472 7698.90 68.47 21.2.02 4271.66 5800.03 -5021.85 -2905.50 0.48 5973024.85 580266.54 N 70.33635970 W 149.34876811 7791.49 69.31 213.09 4305.01 5886.39 -5094.66 -2951.98 1.41 5972951.55 580220.87 N 70.33616076 W 149.34914495 7884.82 69.21 211.99 4338.06 5973.65 -5168.23 -2998.92 1.11 5972877 .46 580174.75 N'70.33595970 W 149.34952556 t-121 ASP Final Survey.xls Schlumberger Private Page 3 of 5 3/19/2003-5: 12 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ-5 EJ·W DLS Northing fasting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 DOff) (ftUS) (ftUS) 7979.77 68.08 211.75 4372.63 6062.08 -5243.33 -3045.62 1.21 5972801.86 580128.90 N 70.33575448 W 149.34990408 8073.02 67.22 211.66 4408.09 6148.32 -5316.71 -3090.94 0.93 5972727.99 580084.39 N 70.33555398 W 149.35027152 8165.97 66.34 211.66 4444.74 6233.74 -5389.41 -3135.78 0.95 5972654.80 580040.37 N 70.33535530 W 149.35063498 8257.78 65.24 210.47 4482.39 6317.47 -5461.14 -3178.99 1.68 5972582.61 579997.97 N 70.33515932 W 149.35098525 8349.97 63.60 210.23 4522.19 6400.61 -5532.89 -3221.00 1.79 5972510.40 579956.75 N 70.33496324 W 149.35132583 8442.31 63.62 209.12 4563.24 6483.28 -5604.76 -3261.95 1.08 5972438.09 579916.61 N 70.33476686 W 149.35165776 8536.96 63.39 209.40 4605.46 6567.93 -5678.66 -3303.36 0.36 5972363.74 579876.03 N 70.33456491 W 149.35199335 8630.87 63.10 211.28 4647.74 6651.76 -5751.03 -3345.71 1.81 5972290.91 579834.48 N 70.33436716 W 149.35233665 8723.63 63.00 211.54 4689.78 6734.45 -5821.60 -3388.80 0.27 5972219.88 579792.18 N 70.33417432 W 149.35268594 8819.34 62.68 211.84 4733.47 6819.60 -5894.06 -3433.54 0.44 5972146.93 579748.26 N 70.33397631 W 149.35304854 ---: 8912.26 62.48 211.65 4776.26 6902.08 -5964.20 -3476.93 0.28 5972076.32 579705.64 N 70.33378463 W 149.35340028 9003.93 62.48 212.87 4818.62 6983.37 -6032.94 -3520.32 1.18 5972007.10 579663.02 N 70.33359677 W 149.35375199 9098.87 62.59 214.92 4862.41 7067.53 -6102.86 -3567.30 1.92 5971936.68 579616.83 N 70.33340570 W 149.35413275 9194.99 62.55 217.12 4906.69 7152.57 -6171.86 -3617.47 2.03 5971867.13 579567.44 N 70.33321714 W 149.35453939 9290.43 63.63 219.33 4949.89 7237.07 -6238.70 -3670.13 2.35 5971799.71 579515.53 N 70.33303445 W 149.35496625 9384.22 65.15 221.20 4990.43 7320.64 -6303.23 -3724,79 2.42 5971734.59 579461.58 N 70.33285810 W 149.35540938 9477.70 64.96 221.61 5029.86 7404.13 -6366.80 -3780.85 0.45 5971670.41 579406.24 N 70.33268434 W 149.35586381 9572.54 64.65 221.81 5070.23 7488.58 -6430.87 -3837.95 0.38 5971605.72 579349.86 N 70.33250924 W 149.35632667 9665.59 64.72 222.92 5110.02 7571.18 -6493.02 -3894.63 1.08 5971542.95 579293.88 N 70.33233938 W 149.35678613 9761.07 65.24 222.01 5150.40 7656.11 -6556.84 -3953.04 1.02 5971478.49 579236.19 N 70.33216493 W 149.35725962 9854.93 65.37 220.79 5189.62 7740.11 -6620.81 -4009.43 1.19 5971413.91 579180.51 N 70.33199011 W 149.35771672 9946.25 65.91 219.00 5227.29 7822.39 -6684.63 -4062.78 1.88 5971349.50 579127.88 N 70.33181567 W 149.35814916 10040.57 66.36 217.97 5265.45 7908.00 -6752.15 -4116.46 1.11 5971281.40 579074.96 N 70.33163113 W 149.35858420 10135.40 65.79 216.38 5303.91 7994.25 -6821.21 -4168.84 1.65 5971211.77 579023.35 N 70.33144238 W 149.35900870 10231.03 65.28 214.70 5343.51 8081.07 -6892.03 -4219.43 1.69 5971140.39 578973.55 N 70.33124882 W 149.35941873 10324.63 65.38 213.15 5382.58 8166.05 -6962.61 -4266.9Q 1.51 5971069.30 578926.87 N 70.33105594 W 149.35980339 --' 10418.55 65.15 211.14 5421.88 8251.34 -7034.83 -4312.28 1.96 5970996.59 578882.30 N 70.33085857 W 149.36017114 1 0511 .4 1 64.69 211.97 5461.25 8335.44 -7106.50 -4356.30 0.95 5970924.45 578839.09 N 70.33066271 W 149.36052774 10606.54 64.85 211.96 5501.80 8421.49 -7179.50 -4401.85 0.17 5970850.95 578794.35 N 70.33046319 W 149.36089688 10700.06 65.71 211.76 5540.90 8506.44 -7251.65 -4446.69 0.94 5970778.31 578750.31 N 70.33026600 W 149.36126018 10793.57 66.13 211.37 5579.06 8591.81 -7324.40 -4491.38 0.59 5970705.08 578706.44 N 70.33006721 W 149.36162225 10888.31 65.44 212.04 5617.92 8678.21 -7397.91 -4536.79 0.97 5970631.08 578661.85 N 70.32986631 W 149.36199014 10982.94 64.61 212.32 5657.87 8763.99 -7470.51 -4582.47 0.92 5970557.98 578616.98 N 70.32966789 W 149.36236028 11076.60 63.93 212.39 5698.53 8848.35 -7541.78 -4627.63 0.73 5970486.22 578572.63 N 70.32947310 W 149.36272610 11169.97 62.74 213.17 5740.43 8931.77 -7611.93 -4672.80 1.48 5970415.58 578528.24 N 70.32928137 W 149.36309207 I' I Schlumberger Private L-121 ASP Final Survey,xls Page 4 of 5 3/19/2003-5: 12 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec W-S E/·W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) {ft) (ft) (°/1000) (ftUS) (ftUS) 11215.63 62.10 213.01 5761.57 8972.22 -7645.84 -4694.89 1.44 5970381 .43 578506.52 N 70.32918870 W 149.36327109 11263.45 61.38 213.66 5784.21 9014.32 -7681.03 -4718.04 1.92 5970345.99 578483.77 N 70.32909253 W 149.36345861 11357.01 61.77 213.78 5828.75 9096.54 -7749.47 -4763.72 0.43 5970277.06 578438.86 N 70.32890548 W 149.36382867 11449.91 61.56 213.69 5872.84 9178.24 -7817.47 -4809.13 0.24 5970208.56 578394.21 N 70.32871963 W 149.36419658 11542.74 61.69 212.81 5916.96 9259.88 -7885.78 -4853.91 0.85 5970139.77 578350.19 N 70.32853295 W 149.36455937 11634.85 61.84 213.07 5960.54 9341.00 -7953.88 -4898.04 0.30 5970071.19 578306.83 N 70.32834682 W 149.36491684 11728.68 63.54 212.87 6003.58 9424.34 -8023.82 -4943.40 1.82 5970000.75 578262.24 N 70.32815566 W 149.36528437 i ¡ 11822.74 66.22 212.54 6043.51 9509.48 -8095.48 -4989.41 2.87 5969928.60 578217.04 N 70.32795981 W 149.36565708 11915.56 67.46 212.53 6080.02 9594.80 -8167.42 -5035.31 1.34 5969856.15 578171.95 N 70.32776318 W 149.36602886 12008.83 67.95 212.36 6115.40 9681.09 -8240.25 -5081.61 0.55 5969782.82 578126.46 N 70.32756414 W 149.36640388 .-, 12102.88 67.62 211.77 6150.96 9768.15 -8314.04 -5127.83 0.68 5969708.54 578081.07 N 70.32736248 W 149.36677829 12195.09 67.80 211.15 6185.93 9853.47 -8386.81 -5172.36 0.65 5969635.28 578037.35 N 70.32716357 W 149.36713896 12284.68 67.85 210.57 6219.75 9936.43 -8458.03 -5214.91 0.60 5969563.60 577995.59 N 70.32696893 W 149.36748362 12378.27 67.70 210.05 6255.15 10023.04 -8532.83 -5258.64 0.54 5969488.33 577952.71 N 70.32676452 W 149.36783774 12471.74 67.42 209.19 6290.83 10109.39 -8607.93 -5301.34 0.90 5969412.77 577910.85 N 70.32655926 W 149.36818354 12567.80 66.73 210.32 6328.25 10197.82 -8684.73 -5345.24 1.30 5969335.49 577867.80 N 70.32634935 W 149.36853910 12663.15 65.49 211.19 6366.86 10284.99 -8759.65 -5389.82 1.55 5969260.08 577824.06 N 70.32614458 W 149.36890012 12757.79 63.37 210.70 6407.71 10370.36 -8832.87 ' -5433:72 2.29 5969186.40 577780.98 N 70.32594449 W 149.36925564 12851.73 59.57 211.38 6452.57 10452.87 -8903.57 -5476.26 4.09 5969115.23 577739.23 N 70.32575124 W 149.36960015 12945.85 55.45 210.88 6503.11 10532.24 -8971.51 -5517.30 4.40 5969046.85 577698.95 N 70.32556556 W 149.36993251 13039.61 52.21 210.80 6558.44 10607.91 -9036.49 -5556.10 3.46 5968981.45 577660.88 N 70.32538796 W 149.37024670 13134.18 49.17 210.72 6618.35 10681.07 -9099.36 -5593.52 3.22 5968918.17 577624.16 N 70.32521613 W 149.37054971 13227.33 46.43 210.88 6680.91 10750.07 -9158.63 -5628.84 2.94 5968858.52 577589.50 N 70.32505414 W 149.37083580 13320.13 43.61 210.86 6746.50 10815.70 -9214.96 -5662.52 3.04 5968801.82 577556.45 N 70.32490017 W 149.37110851 13344.73 42.95 211.37 6764.41 10832.56 -9229.40 -5671.24 3.04 5968787.29 577547.89 N 70.32486070 W 149.37117908 13411 .00 42.95 211.37 6812.92 10877.72 -9267.96 -5694.74 0.00 5968748.48 577524.82 N 70.32475533 W 149.37136942 ~ ; . L-121 ASP Final Survey. xis Schlumberger Private Page 5 of 5 3/19/2003-5: 12 PM a03-D/3 ) ) MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-121 Date Dispatched: 14-Mar-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 RECE\V:'D MAR 24 2003 Alaska OH & Gas Cons. fAmmieIiOn AnchOf!Qe Received By:a~- {~(X~') Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 ) ) ÌJ..I~/~.?/ ,J, I' t'" :-,.1, LC0:S <Jj r ':p 11~):; '7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: II Abandon D Alter Casing D Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. D Suspend II Plugging D Time Extension D Perforate D Repair Well D Pull Tubing D Variance II Other /' D Operation Shutdown D Re-Enter Suspended Well D Stimulate Plug Back for Sidetrack 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: IBI Development o Exploratory o Stratigraphic o Service 6. Datum Elevation (DF or KB) Planned RKB = 76.4' 7. Unit or Property Name Prudhoe Bay Unit (Planned) X = 577615, Y = 5968920 8. Well Number L-121 9. Permit Nu~er 203-013 10. API Number 50- 029-23138-00 11. Field and Pool Prudhoe Bay Field I Borealis Pool (Undefined) ./' 4. Location of well at surface 2357' NSL, 38011 WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 1462' SNL, 4140' WEL, SEC. 09, T11N, R11E, UM At effective depth x = 583116, Y = 5978078 At total depth 22621 SNL, 46551 WEL, SEC. 09, T11 N, R11 E, UM 12. Present well condition summary Total depth: measured (Planned) X = 577111, Y = 5968114 Effective depth: true vertical measured true vertical 13411 feet 6813 feet feet feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 108' 3616' 20" 10-3/4" 260 sx Arctic Set (Approx.) 744 sx PF 'Ll, 537 sx Class 'G' 108' 3645' 108' 26121 Perforation depth: measured None true vertical None RECEIVED MAR 1 7 2003 AJS8fra ~~I _0 G Vf, Q as Can ."\ An'" s. L:crnml-.;:.. ""ILWlge ~ltJn Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments IBI Description Summary of Proposal 14. Estimated date for commencing operation March ~2003 16. If proposal was verball1VaPprov d Wintón Aub I Name of approver L· Contact Engineer NameINumber: Rob Tirpack, 564-4166 17. I hereby certify that the fore ing is true;md correct to the best of my knowledge Signed L II C // / Title Senior Drilling Engineer owe rane r~/frlA:.&- I . ':;i:I.',":",Con.miØiOrt'tJs~ÒlÍhíi'::;' ,;,' ", ....,'1..'. ,:",', ''', .,,\ " ".', L,>" "",'7· ,'..- .., Conditions of Approval: Notify Commission so representative may witness _ Plug integrity ~ BOP Test _ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- 4. () 1 Approved by order of the Commission i€'-""4 ~~~ Form 10-403 Rev. 06/15/88 R B 0 M~ B F l :' , o Detailed Operations Program o BOP Sketch ../ 3/10/2003 15. Status of well classifications as: IBI Oil 0 Gas 0 Suspended Service Date Approved Prepared By NameINumber: Terrie Hubble, 564-4628 Date '3-II-()-~ I Approval No. .303-o"6'L/ , r>} (- Date .:; If z/ t)~ " Submit In TriPllate Commissioner bp ) ) To: Winton Aubert - AOGCC Date: March11,2003 From: Rob Tirpack - BPXA GPB Drilling & Wells Subject: Reference: L-121 Application for Sundry Approval - Plug Back well for Sidetrack Operations API # 50-029-23138 Dear Mr. Aubert, As you are aware, Borealis Well L-121 (Permit #203-013) was drilled as planned to the proposed Kuparuk . target. However, L-121 will not be completed due to encountering high water saturations in the reservoir ~ at the original bottom hole location. Plans are to plug back and sidetrack to a Kuparuk target approximately 2800' to the northeast of the current penetration. Below is an outline of the proposed plug back and sidetrack operations. Also enclosed is a schematic of the existing wellbore and proposed plug- back. If you have any questions or require any additional information, please contact me at 564-4166. t4 Scope RiQ Operations: 1. RIH to TD at 13411' MD with mule shoe on 5" DP. Circulate and condition well for cementing operations. 2. Spot a balanced 15.8 ppg cement P&A plug from TD to +/-13,000' MD (-200' above the Top Kuparuk ÓBeí.. ~rvoir). Plug volume should be based upon gauge hole plus 300/0 throughout this section / (9;1' bbls total). Pull above cement plug and circulate DP clean. c; 3. Spot a 10.7 ppg heavy mud spacer from top of cement P&A plug #1 at -13,000' MD to -9,000' MD /" (300' below base of Schrader Bluff Obf). Circulate out any excess heavy mud spacer above this point. 4. Spot a 10.5 ppg Form-A-Plug pill from -9,000' to -8,850' MD to act as a base for cement P&A plug #2. Pull DP above top of plug and circulate any excess pill out of DP. Pull to shoe and wait on Form- A-Plug to set (-6 hrs). 5. RIH to -8,850' and wash down to a maximum of -8,900' MD looking for top of plug. Circulate bottoms up. Once top of plug is verified, condition mud as required for spotting the cement P&A Plug #2. 6. Spot a balanced 15.8 ppg cement P&A plug from -8,850' to -6450' MD (-200' above the top Ma to /' -200 below the base Of~f). Plug volume should be based upon gauge hole plus 300/0 throughout this section .."bbls total). Pull above cement plug and circulate DP clean. 7. Pull to shoe and WOC 8 rs. /",---j 8. RIH to -6450' MD looking for top of plug. Stack out ~'1Ô~to verify top of plug. /' 9. POOH to -3,~~' MD. Circulate hole clean. Displac~ over to clean 9.7 ppg LSND mud. POOH. /' --r S lO·-.:.to s 5ta-0 rlJ\{ t;....( ~ 10. PU 8-3/4" driling assemoly and RIH to shoe. Planned kick-off point is at -3,795' MD (-150' below, shoe). Perform a lowside kick-off and drill the 8-3/4" hole section as per directional plan to TD @ -10,300' MD (6,895' TVD). POOH. 11. Run and cement the 7", 26# production casing as required to cover all significant hydrocarbon intervals (plans are to cover the Schrader Bluff and Kuparuk formations). Displace the 7" casing with L-121 Application for Sundry ) ) seawater during cementing operations. Once cement has had adequate time to set, freeze protect the 7 x 10-3/4 annulus as required. 12. Run a 3-1/2, 9.2#, L-80 TC-II completion and space out packer 150'-200' MD above top Kuparuk. 13. Set packer and test the tubing to 4500 psi and annulus to 4500 psi for 30 minutes. Shear open DCK valve in bottom GLM. 14. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 15. Freeze protect the well to -2200'. Secure the well. Rig down and move off. Post-Ria Work: 1. RU e-line and perforate the Kuparuk interval, using bottom most GLM to circulate guns down as required. 2. Pull DCK shear valve from bottom GLM and install dummy valve. 3. Fracture stimulate Kuparuk and perform cleanout as required. 4. Install gas lift valves. L-121 Application for Sundry TREE: 4·1/16" - SM Carbon WELLHEAD: 13 S/8"· SM FMC SH 10-3/4", 45.5 #Ift, L-SO, BTC ~ I 3645' I Top 01 Ma at -6,627' MD Base 01 Schrader Bluff Obi at -8.668' MD TO of 9-7/S" hole 113,411' I Date 03/11 /03 ) ) L-121 Proposed Plug-Back 15.8 ppg Cement Kick-off Plug 10.5 ppg Form-A-Plug Cement Base 15.8 ppg Cement \ P&A Plug 1 ~- ~ Planned KOP @ -3,79S' MD I GL Elevation = 44.1' Nabors ges KB = 28.5' KBE = 76.4' Top of 15.S ppg P&A Plug at I 6,450' I /' Top of Form-A-Plug pill at I Top of 1 O.S ppg Mud Spacer at I Top of 15.S ppg P&A Plug at Top Kuparuk Reservoir at ... Rev By Comments RBT Proposed Plug Back for Sidetrack Operations 8,850' ~/ 9,000' 13,000' .../ 13,212' Borealis WELL: L-121 API NO: 50-029-23138 BP Alaska Drilling & Wells ~~Iï\~·L æ ~ lÅL., r ~c J_l ~j ) rÆ~rÆ~~~rÆ FRANK H. MURKOWSKI, GOVERNOR ALASIi& OIL AlWD GAS CONSERVA.TION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit L-121 BP Exploration (Alaska), Inc. Permit No: 203-013 Surface Location: 2357' NSL, 3801' WEL, Sec. 34, T12N, RIlE, UM Bottomhole Location: 2262' SNL, 4655' WEL, Sec. 09, 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 frol11 obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Con1mission 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 ten11S 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, ~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this+'~ day of February, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~i6 A- l~r51f)5 12. Distance to nearest property line 13. Distance to nearest well ADL 028242,625' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casinq Weiaht Grade COUDlina 20" 91.5# H-40 Weld 10-3/4" 45.5# L-80 BTC 7" 26# L-80 BTC-M Hole 42" 13-1/2" 9-718" ') STATE OF ALASKA \ ALASKA VIL AND GAS CONSERVATION COMMlv.SION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well [] Exploratory [] Stratigraphic Test III Development Oil [] Service [] Development Gas [] Single Zone [] Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 76.4' Prudhoe Bay Field I Borealis 6. Property Designation Pool (Undefined) ADL 028241 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number , L-121 /' 9. Approximate spud d~ 02/12/03 Amount $200,000.00 /( 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 ,¿" 14217' MD 17085' TVD o 17. Anticipated pressure {s~'20 AAC 25.035 (e) (2)} 65 Maximum surface 2795 psig, At total depth (TVD) 6825' I 3478 psig Setting Depth Too Bo~om MD TVD MD TVD Surface Surface 110' 110' Surface Surface 3709' 2642' Surface Surface 14217' 7085' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work III Drill [] Redrill [] Re-Entry [] Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 583116, Y = 5978078 2357' NSL, 3801' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval x = 577615, Y = 5968920 1462' SNL, 4140' WEL, SEC. 09, T11 N, R11 E, UM At total depth x = 577111, Y = 5968114 2262' SNL, 4655' WEL, SEC. 09, T11 N, R11 E, UM Number 2S100302630-277 Lenath 80' 3679' 14187' Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) 615 sx PF 'L', 535 sx Class 'G' 659 sx Class 'G', 815 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structu ral Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD Perforation depth: measured A~aslŒ tS. true vertical 20. Attachments III Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch III Drilling Program III Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report III 20 AAC 25.050 Requirements Contact Engineer Name/Number: Rob 7ï aCk, 564-4166 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that t¥ fore ing is true a')Ø" ~ct to the best of my ~nowl~~ge . Signed Lowell Cr, é~ ~ Title Semor Dnlllng Engineer Date ~ -;21 - 03 ¡'t.""J~mro."Î~Øp,ØQlx::,·,!(¡;~".:".,,:~,,:·;,:,, :,',',:,;,;:¡";,,<,"'I':,,i':, Permit Number API Number , . ~¡¡>rq~al Date See cover letter ;:z o::? - 0 i3 50- (J ;¿. 9 - ..2. .3 I 3 g d Y I 0 ~ for other reauirements Conditions of Approval: Samples Required 0 Yes IS No Mud Log =iequired 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes ~ No Directional Survey Required g Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K q 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Te ç. 1- Þ c' f E # '150 C' t;¡~ ¡. D; II ~'7'- t4- t·...l,{ 1,.(,. Ú'-L J . by o'fder of ORIGINAL SIGNED BY Commissioner the commission M L. Bill Approved By Form 10-401 Rev. 12-01-85 Date al4 03 Submt In Triplicate ~) ~\t.,. bp ~~~ ~~. .~~ ~. ·t~,¡\~ ) To: Winton Aubert, AOGCC Date: January 22, 2003 From: Rob Tirpack Subject: Dispensation for 20 AAC 25.035 (c) on L-121 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the Borealis/Kuparuk wells at L-pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All of the Borealis L-pad Development wells were drilled to the shale underlying the SV 1 sands. The shale underlying the SVl is the deepest planned surface casing setting depth for future pad development wells. This casing point is ±300' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8~/Pþg) EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. Most recently L-l 2 was drilled with surface hole L WD and gas detection. These logs and the interpre atiõñ~ have been sent to the AOGCC for review. Although L-112 did experience some gas hyrdrates, the well did not have any pressure control or shallow gas problems. This request is being made based on L-Pad data submitted regarding mud weight, surface open hole logging in the Borealis development (PEX/Dipole sonic), and a meeting between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood (BP) and Kip Cerveny (BP). Your consideration of the waiver is appreciated. Sincerely, /;z/ ~~ #*"~~ Rob Tirpack GPB Rotary Drilling Engineer 564-4166 ) ) I Well Name: IL-121 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer ./ Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: x = 583115.89' Y = 5978078.15' 2357' FSL (2922' FNL), 3801' FEL (1479' FWL), Sec. 34, T12N, R11 E X = 577615.40' Y = 5968919.91' 38181 FSL (1462' FNL), 4140' FEL (1139' FWL), Sec. 9, T11 N, R11 E X = 577111.26' Y = 5968114.31' 3017' FSL (2262' FNL), 4655' FEL (624' FWL), Sec. 9, T11 N, R11 E / I AFE Number: I BRD5M4033 I I Estimated Start Date: 12/12/2003 I I MD: 114217' I I TVD: 17085' I I Ria: I Nabors 9ES vi I OperatinQ days to complete: 121.3 I RT/GL: 128.5' I 1 RKB: 176.4' I Well DesiQn (conventional, slim hole, etc.): I Slim hole (Iongstring) I Objective: I Single zone producer into the Kuparuk formation. Mud Program: 13 Y2" Surface Hole (0-3709'): Densitv (ppg) 8.5- 9.2 9.0 - 9.5 // 9.5 max Initial Base PF to top SV SV toTO Viscosity (seconds) 250-300 200-250 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft~) (mls/30min) 50 -70 15 - 20 30 - 45 < 10 20 - 40 < 10 8.5-9.5 8.5- 9.5 8.5- 9.5 9 7/8" Production Hole (3709' - 14217'): LSND Interval Density Tau 0 YP PV pH API 1 0' Gel (ppg) Filtrate Upper 9.7 4-7 25-30 1 0-15 8.5-9.5 6-10 10 Interval I Top of HRZ 10.5 3-7 20-25 1 0-15 8.5-9.5 4-6 10 toTO L-121 Permit to Drill Page 1 Directional: Ver. Sperry WP07 KOP: 300' Maximum Hole Angle: Close Approach Wells: Logging Program: Surface Intermediate/Production Hole ) ') 65 deg at 2453' MD All wells pass major r~ criteria. The nearest well is: L-110 - ctr-ctr 31.21' IFR-MS corrected surveys will be used for survey validation. Gyro will be needed for surface issues to 1000' MD. Drilling: Open Hole: Cased Hole: Drilling: MWD I GR None None BHA#1: MWD/GR/PWD/RES - all Realtime BHA#2: MWD/GR/PWD/RES*/NEU/AZM DENSI Isonic - all Realtime. Open Hole: None Cased Hole: None Formation Markers: Formation Tops SV6 SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 Na WS1 Oa Obf Base CM2 (Colville) CM1 THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU (Kuparuk B) Kuparuk A TMLV (Miluveach) TD Criteria L-121 Permit to Drill Est. TVDss 900 1540 1665 1690 1920 2090 2460 2765 3080 3500 3800 4060 4220 4600 4895 5630 6245 6420 6490 6540 6565 6695 6825 6920 Estimated pore pressure, PPG 8.5 ppg EMW 8.5 ppg EMW Non-Hydrocarbon bearing, 8.5 ppg EMW Possible Hydrocarbon bearing, 8.5 ppg EMW Possible Hydrocarbon bearing, 8.5 ppg EMW Non-Hydrocarbon bearing, 8.4 ppg EMW Hydrocarbon Bearing, 9.5 ppg EMW Hydrocarbon Bearing, 9.5 ppg EMW Hydrocarbon Bearing, 9.8 ppg EMW Non-Hydrocarbon Bearing, 9.8 ppg EMW \0.5 150' MD below Miluveach top Page 2 ) ') CasinglTubing Program: Hole Csgl WtlFt Gr~de CO~ Length Top Btm Size TbQ O.D. MDrrVD MDrrVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110'/110' 13-1/2" 1 0-3/4" 45.5# L-80 BTC 3679' GL 3709'/2642' 9-7/8" 7" 26# L-80 BTC-m 14187' GL 14217'/7085' Tubing 3 Y2" 9.2# L-80 IBT-Mod 12938' GL 12968'/6475' / Integrity Testing: Test Point Depth Surlace Casing Shoe 20' min from surlace shoe Test Type LOT EMW 11.5 ppg EMW Target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casinq Size 110-3/4" Surface I Basis: Lead: Based on conductor set at 110', 1934' of annulus in the permafrost @ 2250/0 excess and 566' of oper;ß0le from top of tail slurry to base permafrost @ 300/0 excess. Lead TOC: To surface Tail: Based on 1209' MD(>500'TVD) open hole volume + 300/0 excess + 80' shoe track volume. Tail TOC: At -2500' MD ~J Total Cement Volume: Lead 455 bbl I 2554 ft~ I ...15.'~kS of Halliburton Permafrost L at 10.7 ppg and 4.15 ~:îk. Tail 110 bbl I 615 ft~ ;;Vsks of Halliburton 'G' at 15.8 ppg and 1 .15 dIsk. ,. Casinq Size 17" Production Longstring* I Basis: Stage 1: Based on TOC 500' TVD above top of Kuparuk formation + 300/0 excess + 80' shoe Cement Placement: Tail from shoe to 11987' M~ 1 st Stage Cement Tail 140 bbl I 784 fe 65 sks of Halliburton Premium 'G' at Volume: 15.8 ppg and 1.1 fIsk. Basis: Stage 1: Based on BOC 500'MD below the base of the Schrader Bluff and TOC 500' MD above the top of the Schrader Bluff formation + ~% excess + 80' shoe Cement Placement: Tail from 9033' MD to 6142 M~- 00' above Ma sand 2nd Stage Cement Tail 177 bbls I 9994 fe 8.2rsks of Halliburton Premium 'G' Volume: at 15.6 ppg and 1 2 dIsk. * A single stage option for cementing may be available depending on hole conditions and risk register. L-121 Permit to Drill Page 3 ) ) Well Control: Surface hole will be drilled without diverter (pending approval). The production hole well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for future fracture stimulation treatment, the BOP equipment will be tested to 4500 psi. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3478 psi @ 6825' T~ss - Kuparuk A Sands 2795 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) / 4500 psi (The casing and tubing will be tested to 4500 psi as · Planned BOP test pressure: required for fracture stimulation.) · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class /I wastes to OS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. L-121 Permit to Drill Page 4 ) ') DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed in April 2001. 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 spool (diverter waiver requested). PU 5" DP as required and stand back in derrick. 3. MU 13%" drilling assembly with MWD/LWD and directionally drill surface hole to approximately 100' TVD below the SV1 Sands. An intermediate wiperlbit trip to surface~will be performed prior to exiting the Permafrost. I 4. Run and cement the 10-3/4", 45.5# surface casing back to surface. / 5. ND riser spool and NU casing I tubing head. NU BOPE and test to 4500 psi. 6. MU 9 7/8" drilling assembly ~ith MWD/LWD BHA #1 and RIH to float collar. Test the 10-3/4" 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 10-3/4" shoe and perform Leak Off Test. 8. Drill ahead to -800' below the base of the Schrader Bluff - Drill reamer past base of the Schrader Bluff. 9. Trip out of the hole to pick up a new bit and the Dens/Neut/lsonic tool. /' 10. Drill to +1-100' above the HRZ and ensure mud is in condition to 10.5 ppg. Hold Pre-Reservoir meeting highlighting kick tolerance and detection prior to entering HRZ. 11. Drill ahead to TD at -150' MD below Top Miluveach. 12. Condition hole for running 7" 26# long-string casing. /' 13. POOH, laying down 5" DP. 14. Run and cement the 7" production casing in two stages. (A single stage cement job may be an option.) Displace the cement with 8.5 ppg heated filtered seawater if single stage. 15. Freeze protect the 7" x 10-3/4" annulus as required. Record formation breakdown pressure' on the Morning Report. ' 16. Single in with 3-1/2" DP. Drill stage tool./OOH laying down 3-112" DP. ' . 17. Test casing to 4500 psi for 30 minutes. 18. Run the 3-1/2",9.2#, L-80 IBT-Mod completion assembly. Set packer and test the tubing to 4500 ps¡"""'-- and annulus to 4500 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below to 1000 psi. 19. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. /' 20. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. 21. Rig down and move off. L-121 Permit to Drill Page 5 ) ) L-121 Drilling Program Job 1: MIRU Hazards and Contingencies þ> L-pad is not designated as an H2S site. None of the current producers on L-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 closest surface location is L-110, 30' to the East. ~ Check the landing ring height on L-121. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: DrillinQ Surface Hole ~ There are no close approach issues in the surface hole. ~ A Camera Based Gyro (minimum requirement) survey will be required per the directional plan to 1000' MD or until the magnetic interference at the surface has dissipated. ~ Gas hydrates have been observed in wells drilled on L-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 Baroid mud recommendation ~ Should angle not build as fast as planned, there is a possibility of intersecting the L-Pad fault in , the surface hole. To date this fault has not been problematic, however, should the directional lag, we may enter the fault plane and stay in it for a while or have more difficulty in getting angle built by the time we TD the surface hole. Losses have not been an issue with this fault in the past. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. IIWell Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations Job 3: Install Surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 2250/0 excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 10-3/4" 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. L -121 Permit to Drill Page 6 ) ') Reference RPs .:. UCasing and Liner Running Procedure" .:. uSurface Casing and Cementing Guidelines" .:. uSurface Casing Port Collar Procedure" '!'.'-'-,.~-;;;'-A~W,I,:;"I,~:';"-"'",-I,'¡':";';"""'''''".\.\.\ \~~ Job 7: DrillinQ Production Hole Hazards and Contingencies ~ L-121 will cross two faults - one in the Schrader, 50' throw @-7000' MD, and the second in the HRl, 40' throw @ -12775' MD. The well will be - 65 degrees when crossing the faults. Historical information on L-pad indicates possible problems with faults in the Schrader Bluff due to higher circulating ECD's. With the 9-7/8" hole, this risk is reduced and is estimated to be low to moderate. We have avoided crossing faults in the HRl in the past so there is not a lot of information of losses in the LN pad area. This risk is therefore assumed to be medium. Follow the Lost Circulation Decision Tree and contact town should losses be encountered. ~ HRl stability studies indicate that the minimum mud weight for this deviation and azimuth be 11.1 ppg. Milne point has been able to drill the HRl at much less than the recommendations in the Shale study. A check with ConocoPhillips on their 1 C-22 well will need to be done to help optimize the drilling fluid weight. The current plan is based on a 10.5 ppg fluid to look at the HRl in this area. ~ Historical data on a ConocoPhillips well, 1 M-17, indicates the possibility of seeing a 10.3 ppg pore pressure in the Kuparuk. This data is older, April 2002, and we have data from the nearer 1C-12 and the analogous V -108 wells that lends credence to the expected lower pressu res as indicated in the SOR. As such, the risk of over pressure is low to medium. » KICK TOLERANCE: In the scenario of 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 11.5 ppg at the surface casing shoe, 10.5 ppg mud in the hole the kick tolerance is 61 bbls. An accurate LOT will be required as well as heightened awareness for / kick detection. Contact Drilling Manager if LOT is less than 11.5 ppg. L-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 » Hole angle of 65 degrees will require optimized flow rates, pipe rotation and mud rheology to achieve hole cleaning. Follow hole cleaning guidelines outlined in operational specifics. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. uShale Drilling- Kingak & HRZ" h.....';. -,:... 'I;;"';;;~---¡¡,-"¡;";u;.u.;.-;--" ,110, _U/ 1..;;...11--- . ,~.." ." _ 1- 1;;;1'" -- 1---;_-;- - r:II._,._o;IA..;--,-n.; .-.--.-.---no,;-u-,-_ _ _II. ~W~:I_"L ~', ",._.,':'" ,I.-.I\-"'-~-;";-'-.I.-:.""':"W.~,)¡". ;,){-;"''''''''' UI¡; -..;- -¡¿;,- -j.,; L-121 Permit to Drill Page 7 ') ) Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The interval is planned to be cemented in two stages with a 15.8 ppg first stage (500'TVD above the Kuparuk) and a 15.6 ppg second stage (500'MD above the Schrader Ma). If a single stage cement job is deemed possible, then the cement job may be performed in this manner. ~ Ensure the lower production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 10-3/4" casing outer annulus with 112 bbls of dead crude (2300' MD), 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 LQ::r:will be req~ired prior to displacing freeze /" 1 protect. This to satisfy AOGCC for fut~,~é annular ~_~,~pihg permits.) ~ Ensure a minimum hydrostatic equivalent(of::'LQ:,á:þpg"on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells drilled with 8-3/4". A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. Ulntermediate Casing and Cementing Guidelines" .:. uFreeze Protecting an Outer Annulus" T, ..),:/:" .'-~,:,.,,",.-.Ie., ..-¡'-.:¡.ß ,:m,,", '-~''-'-,I.-" ."-ßmW!ÁI.I!¡m,l¡.;mm.Im.,I,lwm,¡¡.¡~mm'J.AA-'-.-,wm¡,;,~;;u'-,.-.-AA-'-A-)m~)¡AAI'-¡"-))A:,I,I,lm,I,I¡"II';;~~~m¡!,I,¡,I¡¡¡,n:Jm.;m',I.IW,:;I,I)':¡ --mn-.-'-'-!,I.D),\I>J!I.ImÁ-;!,I.\W,IJ.I,I!^~,!.IW,I,IJ,rm.:.l,lm,l,I,Im,I'm"'-:.-~..mm.IAA-"-.' . -,-",-;',.:.-¡\:';,I,I,I,I,IJH\a,lmmWm,I.l.O/,l!,o,;,I,I,1),I,I'AI,Im,I,I.I.I.I.I.1.w».!W,;I.I.-.-.-AX.-I,-,-.-.-.-AA-.-.-A-,I,"¡.).-!,I,I,I,IM;,¡,¡,.,;;.....;,.,~;"M ,...,." ,;;"-;10.;,11,4",,.,.,,,,,,,, ,:.-.-1,1. Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be underbalanced if there is a casing integrity problem. ~ Utilize the DCK shear valve. When testing annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4500 psi annulus pressure. 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 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 L-121 Permit to Drill Page 8 TREE = 4-1/16" CIW WELLHEAD = FMC ACTUÄTOR;" NA KB. ELEV = 76.4' BF~"ËLEV';""'"'' , NA \·koþ";..··.. ... .......... ......·..'''....·..·....30·0'· Mã'x·"Ãng"lé"";···· 6so'@260:¡i' Di:iiÚmMÖ;" ...... .. Datum TV D = 8800' SS ) 10-3/4" CSG, 45.5#, L-80, ID = 9.95"--1 3709" ~ Minimum ID = 2.813" @ xxxx' 3-1/2" HES X NIPPLE (4 total) (top joint)4-1/2" TBG, 12.6#, L-80, IBT-M, .0152 bpf, ID = 3.958" 3-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 11 13049" ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLE A T TOP ÆRF: xx @ xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I PBTD 1--1 14137" 17" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 1--1 14217" DA TE REV BY COMMENTS 12/18/02 jdf ffiOPOSED COMPLETION - - 11 10-3/4" TAM PORT - 1 011" COLLAR 2200" 1--1 3-1/2" HES X NIP, ID = 2.813" 1 ~ GAS LIFT MA NDRELS ST MD TVD DEV 1YÆ VLV LATCH PORT DATE 1 tbd KBG DCK-3 BTM 3.5x 1.0 2 5300 KBG Dummy BTM 3.5x 1.0 3 4500 KBG Dummy BTM 3.5x1.0 4 3500 KBG Dummy BTM 3.5x1.0 L-121 - - I I L /" ) I I I Stage Tool @ 9033' MD I I :8: I ./1 ~ ~t J ~ DA TE REV BY COMMENTS 12949" 1--13-1/2" HES X NIP, ID = 2.813" 12969" H 7" X 4-1/2" BKR S-3 PKR, ID = 2.992" 1 12989' 1--1 3-1/2" HES X NIP, ID = 2.813" I 13019' 1--1 3-1/2" HES X NIP, ID = 2.813" 13049' 1--1 3-1/2" WLEG, ID = 2.875" 1 13088' I., Radioactive Pip Tag 2jt I above TKUP 11 13843' Radioactive Pip Tag @ TKUPA4 GPB BOREALIS WElL: L-121 ÆRMrr No: API No: SEe 34, T12N, R11 E 2922' NSL & 3801' WEl BP Exploration (Alaska) ) ') L-121 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates have been observed in offset wells. These are expected to be encountered from the base of the Permafrost to TD of the hole section. Surface hole logs have been run at L- 106 and L-112. Both logs show hydrate zones present below the permafrost, but show no signs of significant surface hole free gas. · The L-pad fault was originally mapped on seismic as being crossed twice in this hole section, however historical geological data indicates that we should not cross this fault in the surface hole. If the planned build rate and angle are not achieved, then we increase the risk of intersecting the fault. If this happens then we run the risk of staying in the fault for a prolonged time as we will hit it at roughly the same angle as the fault plane. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity and yield point is maintained to avoid stuck pipe situations. Production Hole Section: · The production section will be drilled with a recommended mud weight of 10.5 ppg to ensure adequate overbalance in the Kuparuk formation and shale stability in the HRZ shale. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. The short trips in the production hole has proved problematic if hole cleaning practices are not in place. Back reaming at connections and monitoring excessive annular ECD via the PWD will contribute to favorable hole conditions. · FAULTS: The well trajectory is expected to intersect 2 faults - one in the Schrader Bluff and one in the HRZ. Losses are anticipated to be a medium risk, but if losses are encountered, consult the Lost Circulation Decision Tree for recommended LCM treatments. · KICK TOLERANCE: With 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 11.5 ppgat the surface casing shoe, and 10.5 ppg mud in the hole, the kick tolerance is 61 bbls.7 · L-Pad development wells have "kick tolerances" in the 25-50 bbl range. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. (Continued on next page) Version 1.0 Rigsite Hazards and Contingencies Page 1 of 2 ) ) HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 2 of 2 ·Aj Date: 1219/2002 Date: Date: Plan: L-121 wp07 (Plan L-1211Plan 1.-12 Created By: Ken Allen Checked: Reviewed: SURVEY PROGRAM Depth Fm Depth To Sur\'eylPlan Tool 34.00 1000.00 Planned: 1.-121 v.IflI VI7 CB-GYRO-SS 1000.00 14217.36 Planned: 1.-121 v.p07 VI7 MWD+IFR+MS REFERENCE INFORMATION C<><.nIinate (NÆ) Refereoœ: Well Centre: Plan lo121. True Nor1h Vertical (TVD) Refereoœ: 81.90 81.90 Sectioo (VS) Refer=: SIoI· (O.!XN,O.ooE) Measun:d Depth Reference: 81.90 81.90 ~1culaDoo Method: MinimumCUn'3lUre COMPANY DETAILS BP Amoco CalculaJion Method: Mininun C'un-. ~~ ~~~~~Nor1h Error Surf_ Eßipical + CasiI>¡ Wamin4 Method: R..... Bucd O··~,p T' Size No. 10.750 1 7.000 2 3 4 5 6 7 0- ,A ~ I ¡ Start Dir 1.5/100' : 300' MD, 300'TVD 10 _ ! ; ./ Start Dir3/100': 433.33' MD,433.31'1VD 11 AI:""""/ 12 '1' ¡. 13 I I ßO 14 - I: 15 - It 16 I .! 17 ¡sV,6 ð? 18 _ ' II([)()i 11 . 19 I I I A' StartDlr2.5/100';1469.0TMD,I409.2ITVD 20 300 _ ! 1 .~ 21 _ ¡ ¡ , ~ 22 _ ; r $V5 .; - Stan DIr 4/1 00' : 2002.9' MD, 1821.9'f 23 - .! t, l gV~, d> ~~ ; I BPRf "n" ' .~ - ¡ - i ¡ -: ,2~ ' .,- ,.;. End Dir : 2607.44' MD, 2176.05' TVD - i -t :' f ! S'{3 : .! '0 Ii ¡ r! r'~ ¡ ¡! ¡ : i l ¡ i ...nnhi - , ¡i!il! i'wr~\~ 2600 ¡ ¡ ! ; i : I l' ::' I I _ _ _ ._. , . ~_¡ ____\_....1_,....] '_ i ' ,I I I : I L J..I /1 I , - It f ,! ¡ '1 i ¡+ -~M4'L...1-4oo!J~- - - If·j ¡ ¡ i ¡ fl ¡-j-iH-¡-hulf4Ä--¡ -, _ . -- '\ . I, ¡ r .. ,- "-I-i--~-,--,_·~--+--1- I ¡ ¡ r: l : ¡ \- ¡, ! ~¡lt~¡~lu:~--¡ r1'~-H--1 _ . ! -. .!" I -, . -- .-[ n" -"----+---;---- . ,--¡-, I I ' ÌÌ"-.. ¡i ¡ ¡ i ! i ! -f - -~ iH ~-L¡-+-- i! i : I ¡ i I ~ I ' ¡ j t i:! t ì t : f~ n ì ì,uluf, -t ,---t,--ri, ,-+-1 I I I ®09 3900 I:: : I ' , i 'I '; ¡,I :: :,'::" I I I _ l -i I : I 1 ¡ l~ -I f-:-J -~-J-l--h- --LLJ !! I ! I - ¡ i i i ! II! ¡ f· ¡ I)· Lj_¡--1,-~, ~-+-!--~ i- ¡ I I 1 I I "I I I . '-i I I ' " " 'I ' . I __ -. _I '~1 - I . -I -- _L L-4 --.J~-~--'--7 " I I I I ! I I ; I 1 ¡' I' I: I ¡ I Ii' I i I I : ,. _ '-I f : I t I - ~ t-I-' -~ n'_!-_~;_ I ' , , I i I ¡ ¡ I : ! I I ; I I I I !: ! i ! 1 I I I - Ii ! ì! ¡ 11 ~i FH -¡~rTl-T- -rrr¡1 i _ 1 I ¡ ¡I. ¡ L :, - . ¡ _.Lu~ _,._L_,-_: " " 'I I I ' 'I I ì I 1 I' ,ì I Iii ¡ ,; I' I i In' -r I ¡ ¡ - -f- j -- t .--1--,' ----j : : I: : II I I '. l ! i: I, ,I I :' I I; I I I I . - " ¡ ¡,-. U¡ -I -'+-¡--¡---- I ,I , I! I ': I,! I! I i I : ii' I I 1 5200 \ \ ' I I : I \ I: l \ ,,; :' I I I I ' i ' -' f.- f lit· ¡- n._ ¡--i--.,-J--¡--!----'--' ¡ ¡ i ; ¡III ! I ¡: !: I I: I I ¡-' L-...l..-.; L..i...-i-L I . I ì - 1 '-, ¡ í '¡--·"I,!-i! :---, Ii' rT!! - t' I I. ,II J -II -. --¡-~-..- . I ,I '. I " I" il,!' I I: ,'I Iii! - ,- I =. \ All TVD depths are ~ = -[ ssTVD plus 81.9'for RKBE. ¡ ! 6500 I II "I I I i I : I' , I I ¡ ! r I I I l ! I \ 1 \ -It \l-\-·- - I I I ¡ I - -I t - i I --II -, ..~ -Ii - I I' Ii ~ ¡ __ . l I I I o WElL DETAILS Name .q.q -Ii +Ff·W NonhiDg Easting Latitude Loogitude Slot Plan 1.-121 -155.90 11735 S978078.15 S8311 5.89 70"21'OO.290N 149"19'30.7I1W WA T AllGET DETAILS Name 1VD -+NI-li +EJ·W Nor1hing Easting Shape 1.-121 SV5 1621.90 52830 ·575J3 597859'>-99 S82S34.99 PoI)-goJO loI21 TIb 6641.90 -0097.50 -S602.51 5968919.91 577615.14 Point loI21 Poly 6641.90 -379S.27 -5799.19 5969219_91 577415_14 Polygon SECTION DETAILS Sec MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSee Target 1 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 185.00 300.00 0,00 0.00 0.00 185.00 0.00 3 433.33 2.00 185.00 433.31 -2.32 -0.20 1.50 185.00 2.08 4 1469.07 33.00 200.00 1409.21 -292.51 -100.72 3.00 15.85 301.78 5 1869.07 43.00 200.00 1724.02 -523.63 -184.84 2.50 0.00 542.62 6 2002.90 43.00 200.00 1821.90 -609.40 -216.06 0.00 0.00 632.00 7 2607.44 64.99 212.66 2176.05 -1040.13 -437.68 4.00 29.00 1114.91 8 13168.70 64.99 212.66 6641.90 -9097.50 -5602.51 0.00 0.00 10684.21 L-121 Tlb -~ 9 14067.36 64.99 212.66 7021.90 -9783.10 -6041. 98 0.00 0.00 11498.46 10 14217.36 64.99 212.66 7085.33 -9897.54 -6115.34 0.00 0.00 1\634.37 FORMATION TOP DETAILS TVDPath MDPath Formation Gl SV6 SV5 SV4 BPRF SV3 SV2 SV1 UG4A UGJ UGl Ma Na Oa Obfbase CM2 CM1 1HRZ BHRZ K-1 TKUP KupC LCU KupA TMLV 346.90 992.97 1733.12 1900,36 1934.54 2270.99 2597.69 3472.64 4193.93 4938.87 5932.13 6641.59 7256.47 7634,85 8533.51 9231.15 10969.35 12471.06 12884.92 13050.46 13168.70 13227.83 [3535.26 [3842.70 14067.36 346.90 981.90 1621.90 [ 746.90 1771.90 200 1.90 2171.90 2541.90 2846.90 3161.90 3581.90 3881.90 4141.90 4301.90 4681.90 4976.90 5711.90 6346.90 6521.90 6591.90 6641.90 6666.90 6796.90 6926.90 702 1.90 CASING DETAILS No. lVD MD Name 2641.90 3709.12 10 3/4' 7085.32 14217.35 7" --' wp07 ... ......~ ~' ~ .. -~' /! ,,~... ~ ...".:;', I I 1700 -:"CJ, I™tY ~ I í ¡ 11 , ,I' L121736' ~. 7P8l3~' \ I I , , I I I I I 10400 11 l~oqo ¡ I~ ¡....!..-..!. , ' lif~~ I II' Iii II~OOO ! : I : i i ! I' "I : ¡ i , I! I! ¡ I II T otJl ¡oept~ : I. I I I I I I I I ,I ~ ,I ¡I ~ ; #,## l" 9100 I 7800 ''t 9bo<¡ Ì' I èM2 ¡ \ i ¡ i ¡ ! ! I ¡ I I I I I i ¡ I I i 1 i I 5200 6500 Vertical Section at 211.710 [1300ftlin] 11M I ' , I ! ! i ¡ ¡ ! I ! i I i i ! i I i ¡ ì I I I I ! i I ¡ ! I I ! I 3900 [Lf~[[TJJ]IL~+ I I I I I I I I I I I I I 1300 2600 [J I I .L I ë ~ 8 ~ -5 g ~ t: > 2 !- "Aj 1219/2002 wp07 (Plan L-1211P1an L-t Date Plan: L-12 Created By: Ken Allen Tool CB-GYRO-SS MWD+IFR+MS SURVEY PROGRAM Depth To Sun")'/PIan 100(1)() Planned: L-121 \\p07 VI7 1421736 Planned: L·121 \\p07 VI7 Depth Fro 34.00 1000.00 REFERENCE INFORMATION Co-onIinaIe (NIE) Refereoce: Well Centre: Plan !r121. True Nonh Vertical (TVD) Reference: 81.90 81.90 Sec60n (VS) Ref"en:oœ: Slot - (O.o<N.01)()E) McamrOO~= ~~œn~~~ COMPANY DETAILS DP Amoco Calculation Method: MirUmum Cun."""" ==: ~s.;:¿:~Nonh Error Surf-= EDipticoJ ~ Casinø WlI1Iinø M_ Rub Based bp O~-·,: - - L-121 SV~ 95% eont: ~tat1 Dir,1.5/1OO'I: ~OC' MD, 3qo'rvP I ' ; , tart Dir 31190'1: 433!3~' rm; 4ß3,f3lt-r0>¡::;- ,^^t rtb-Û" 2:51 OQ' : 1 1469fo1. ~D: 1409.21'1iVÐ : ~~ '1~1 I I " 1,,"" ' -¡-I~di~~~D¡-1-'þ4.~'1VÞ ;l5~0, - - - LStaitDlr-4l!OO': 1002.c;"~, 1'~--:'- ' - -H--f- i ¡ ! ¡ '! I ¡ : ~O(.() I : - -J~næÐh-1~7##~5' r\fD I ¡ !~ il 1 i ¡! ¡ i ¡!' " _ ! 0 ß/4" , All TVD d~ ; : Iii ¡ I TT/D I RKBE r:1---'- i SS Y j P us " !' i ~()( 0 i ! I ¡q=~~~ i-I Ii -3200 i t i I :! ¡ I : ; ; I 1 I t Jf¡;r~-I~; _ !. i i .-. -r- f'--r-T¡- : ¡ : I I , ; : I ì -4800 ¡Ii H-li- i-iH i+ i i '7' . t '_1_ ~._"'~ _L-rj-f'~, I! I ! ¡ ¡ wrl=t~i -j-ti-+i- ¡ ! ¡ r.n ¡ ¡ ¡! : ! Ii! i I I i-I ¡~~ ~-++-i I !:! I -f f y- :r+---t+-¡-. 1--1-:-, -¡ ¡ 1-- , ¡ ¡ ¡ ,Ii i ¡: ¡ -6400 I! I "L I! I! i; ! - -¡ 7" rr-'¡ -t¡--+-! : r I 1-1 ' I I I I '¡-1- ¡1~1--~~±--+t! i - j-¡ ~--TI---I ! ¡: I - - ¡J-J:--=±l~----UJ I JJ ! I i ' i i! I )t. .. - --¡---¡-- i ; I ¡ i -8000 , ' '. . ., , t_ . n _81- -+ +--- _-L-¡ I I .' 1- -- _1-.-+. : I,! I , I ! i I I I' I I - --- i 1- : I I ¡ I ¡ .n-I-í--+----~-¡ I _Ll _ un-'--jdU.J.----.l--i-.l - :t~~ ==-r-.-I I! I r . "-ï---+-¡nn_--1 ¡ -4- +---11 I Iii -9600 ! .1_ _ _ L_.j_ ~_n--Ll-- J i ! l tZJ- -. ·-1-_1__ -H-t--#' -- ! ! I I t-t-1 2-1. '~,-t1 ,-- --+-: +t J~I-T-L~1.---L' I I ! I ! I ! I I I I I I I I I I I I I I I -4800 -3200 -1600 W est( - )/East( +) [1600ftJin] Dat Dat Checked: Reviewed: WELL DETAIlS Nonhing Easbog 5978078.15 583115.89 Slo< WA Loog;tude 149" 19'30.7 II W Easting Shape 582534_99 Polygon 577615.14 Poinl 577415.14 Polygon LarinxIe 70"2 I '00290N TARGET DETAILS TVD -;-N/.I) +f)-W Nonhing 1621-90 528.30 -575.13 m8S99.99 6641-90 -909750 ·5602-51 596891991 6641.90 ~9S27 -5199.19 596921991 SECTION DETAILS +N/-S +FJ-W +FJ-W Jl7J5 Name -;-N/-S Plan !r121 -155.90 Name L-121 SV5 L·121 Tlb L-121 Poly I -! 1 Tlb Target L-121 vSec 0.00 0.00 2.08 301.78 542.62 632.00 1114.91 10684.21 11 498.46 11634.37 TFace 0.00 185.00 185.00 15.85 0.00 0.00 29.00 0.00 0.00 0.00 DLeg 0.00 0.00 1.50 3.00 2.50 0.00 4.00 0.00 0.00 0.00 0.00 0.00 -0.20 -100.72 -184.84 -2 I 6.06 -437.68 -5602.51 -6041.98 -6115.34 0.00 0.00 -2.32 -292.51 -523.63 -609.40 -1040.13 -9097.50 -9783.10 -9897.54 TVD 34.00 300.00 433.31 1409.21 1724.02 1821.90 2176.05 6641.90 7021.90 7085.33 MD Ine Azi 34.00 0.00 0.00 300.00 0.00 185.00 433.33 2.00 185.00 1469.07 33.00 200.00 1869.07 43.00 200.00 2002.90 43.00 200.00 2607.44 64.99 212.66 13168.70 64.99 212.66 14067.36 64.99 212.66 14217.36 64.99 212.66 See 1 2 3 4 5 6 7 8 9 10 I o ~ -1600 ~~ ~- CASING DETAILS MD Name Size 3709.12 10 3/4' 10.750 14217.35 7" 7.000 FORMATION TOP DETAILS TVDPath MDPath Formation No. 1 346.90 346.90 G1 2 981.90 992.97 SV6 3 1621.90 1733.12 SV5 4 1746.90 1900.36 SV4 5 1771.90 1934.54 BPRF 6 2001.90 2270.99 SV3 7 2171.90 2597.69 SV2 8 2541.90 3472.64 SV1 9 2846.90 4193.93 UG4A 10 3161.90 4938.87 UG3 11 3581.90 5932.13 UOl 12 3881.90 6641.59 Ma 13 4141.90 7256.47 Na 14 4301.90 7634.85 Oa 15 4681.90 8533.51 Obfbase 16 4976.90 9231.15 CM2 17 5711.90 10969.35 CM1 18 6346.90 12471.06 THRZ 19 6521.90 12884.92 BHRZ 20 6591.90 13050.46 K-1 21 6641.90 13168.70 TKUP 22 6666.90 13227.83 Kup C 23 6796.90 13535.26 LCU 24 6926.90 13842.70 Kup A 25 7021.90 14067.36 TMLV No. TVD 1 2641.90 2 7085.32 '/.c ,~ " ~ .. _, I! 4> ~ ..... .ß>' ~ tfjT "~ o i I I ¡ i ! ¡ i i I I i , ¡ i i - I -6400 -- ) BP KW A Planning Report MAP Company: BP Amoco Field: Prudhoe Bay Site: PB L Pad Well: Plan L-121 Wellpath: Plan L-121 "A" Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 12/9/2002 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: Map Zone: Coordinate System: Geomagnetic Model: Site: PB L Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5978232.73 ft 582996.83 ft Latitude: Longitude: North Reference: Grid Convergence: Well: Plan L-121 Slot Name: Well Position: +N/-S -155.90 ft Northing: 5978078.15 ft Latitude: +E/-W 117.35 ft Easting: 583115.89 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan L-121 "A" 50029 Current Datum: 81.90 Magnetic Data: 12/4/2002 Field Strength: 57508 nT Vertical Section: Depth From (TVD) ft 0.00 Height 81.90 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft _._-----,----- 0.00 -_._--,-~._- Plan: L-121 wp07 Date Composed: Version: Principal: Yes Tied-to: Casing Points MD TVD Diameter Hole Size Name ft ft in in 3709.12 2641.90 10.750 13.500 10 3/4" 14217.35 7085.32 7.000 9.875 7" Formations MD TVD Formations Lithology ft ft -----------.-------- 346.90 346.90 G1 992.97 981.90 SV6 1733.12 1621.90 SV5 1900.36 1746.90 SV4 1934.54 1771.90 BPRF 2270.99 2001.90 SV3 2597.69 2171.90 SV2 3472.64 2541.90 SV1 4193.93 2846.90 UG4A 4938.87 3161.90 UG3 5932.13 3581.90 UG1 6641.59 3881.90 Ma 7256.47 4141.90 Na 7634.85 4301.90 Oa 8533.51 4681.90 Obf base 9231.15 4976.90 CM2 10969.35 5711.90 CM1 12471.06 6346.90 THRZ 12884.92 6521.90 BHRZ 13050.46 6591.90 K-1 13168.70 6641.90 TKUP 13227.83 6666.90 KupC ) Time: 18:16:01 Page: Well: Plan L-121, True North 81.9081.9 Well (0.00N,O.00E,211.71Azi) Minimum Curvature Db: Oracle Alaska, Zone 4 Well Centre BGGM2002 70 21 1.823 N 149 19 34.141 W True 0.63 deg 70 21 0.290 N 149 19 30.711 W Well Ref. Point 0.00 ft Mean Sea Level 25.71 deg 80.78 deg Direction deg 211.71 12/9/2002 17 From Well Ref. Point Dip Angle deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip Direction deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ) BP KW A Planning Report MAP ') Company: BP Amoco Field: Prudhoe Bay Site: PB L Pad Well: Plan L-121 Wellpath: Plan L-121 "A" Date: 12/9/2002 Time: 18:16:01 Page: 2 Co-ordinate(NE) Reference: Well: Plan L-121 , True North Vertical (TVD) Reference: 81.9081.9 Section (VS) Reference: Well (0.00N,O.00E,211.71Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Formations MD ft 13535.26 13842.70 14067.36 TVD ft 6796.90 6926.90 7021.90 Formations Lithology Dip Angle deg 0.00 0.00 0.00 Dip Direction deg 0.00 0.00 0.00 LCU KupA TMLV Targets Map Map <-. Latitude -> <- L9ngitude ..--> Name Description TVD +N/-S +E/-W Northing Easting Deg. Min Sec Deg . Min See Dip. Oil'. ft ft ft ft ft L-121 SV5 1621.90 528.30 -575.13 5978599.99 582534.99 70 21 5.485 N 149 19 47.520 W -Polygon 1 1621.90 528.30 -575.13 5978599.99 582534.99 70 21 5.485 N 149 19 47.520 W -Polygon 2 1621.90 523.59 -150.12 5978600.00 582959.99 70 21 5.439 N 149 19 35.099 W -Polygon 3 1621.90 -1708.70 25.15 5976369.99 583159.99 70 20 43.485 N 149 19 29.976 W -Polygon 4 1621.90 -1703.60 -434.86 5976369.99 582699.99 70 20 43.535 N 149 19 43.417 W -Plan out by 1055.23 at 1621.90 -439.33 -154.16 5977637.18 582966.63 70 20 55.969 N 149 19 35.216 W L-121 T1b 6641.90 -9097.50 -5602.51 5968919.91 577615.14 70 19 30.796 N 149 22 14.242 W -Plan hit target L-121 Poly 6641.90 -8795.27 -5799.19 5969219.91 577415.14 70 19 33.767 N 149 22 19.989 W -Polygon 1 6641.90 -8795.27 -5799.19 5969219.91 577415.14 70 19 33.767 N 149 22 19.989 W -Polygon 2 6641.90 -9046.21 -5266.89 5968974.91 577950.14 70 19 31.303 N 149 22 4.446 W -Polygon 3 6641.90 -9449.01 -5471.39 5968569.91 577750.14 70 19 27.340 N 149 22 10.407 W -Polygon 4 6641.90 -9188.40 -5973.58 5968824.91 577245.14 70 19 29.899 N 149 22 25.071 W -Plan out by 360.59 at 6641.90 -9097.50 -5602.51 5968919.91 577615.14 70 19 30.796 N 149 22 14.242 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 185.00 300.00 0.00 0.00 0.00 0.00 0.00 185.00 433.33 2.00 185.00 433.31 -2.32 -0.20 1.50 1.50 0.00 185.00 1469.07 33.00 200.00 1409.21 -292.51 -100.72 3.00 2.99 1.45 15.85 1869.07 43.00 200.00 1724.02 -523.63 -184.84 2.50 2.50 0.00 0.00 2002.90 43.00 200.00 1821.90 -609.40 -216.06 0.00 0.00 0.00 0.00 2607.44 64.99 212.66 2176.05 -1040.13 -437.68 4.00 3.64 2.09 29.00 13168.70 64.99 212.66 6641.90 -9097.50 -5602.51 0.00 0.00 0.00 0.00 L-121 T1b 14067.36 64.99 212.66 7021.90 -9783.10 -6041.98 0.00 0.00 0.00 0.00 14217.36 64.99 212.66 7085.33 -9897.54 -6115.34 0.00 0.00 0.00 0.00 Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 34.00 0.00 0.00 34.00 -47.90 5978078.15 583115.89 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 185.00 100.00 18.10 5978078.15 583115.89 0.00 0.00 185.00 CB-GYRO-SS 200.00 0.00 185.00 200.00 118.10 5978078.15 583115.89 0.00 0.00 185.00 CB-GYRO-SS 300.00 0.00 185.00 300.00 218.10 5978078.15 583115.89 0.00 0.00 185.00 CB-GYRO-SS 346.90 0.70 185.00 346.90 265.00 5978077 .86 583115.87 0.26 1.50 0.00 G1 400.00 1.50 185.00 399.99 318.09 5978076.84 583115.79 1.17 1.50 360.00 CB-GYRO-SS 433.33 2.00 185.00 433.31 351.41 5978075.83 583115.71 2.08 1.50 0.00 CB-GYRO-SS 500.00 3.96 192.93 499.88 417.98 5978072.42 583115.13 5.30 3.00 15.85 CB-GYRO-SS 600.00 6.95 196.35 599.42 517.52 5978063.22 583112.76 14.40 3.00 7.93 CB-GYRO-SS 700.00 9.94 197.72 698.32 616.42 5978049.15 583108.59 28.61 3.00 4.52 CB-GYRO-SS 800.00 12.94 198.46 796.32 714.42 5978030.25 583102.62 47.88 3.00 3.17 CB-GYRO-SS 900.00 15.93 198.93 893.16 811 .26 5978006.55 583094.89 72.17 3.00 2.44 CB-GYRO-SS 992.97 18.72 199.23 981.90 900.00 5977980.29 583086.12 99.19 3.00 1.99 SV6 1000.00 18.93 199.25 988.55 906.65 5977978.15 583085.40 101.40 3.00 1.70 MWD+IFR+MS 1100.00 21.93 199.48 1082.25 1000.35 5977945.09 583074.19 135.50 3.00 1.68 MWD+IFR+MS 1200.00 24.93 199.67 1174.00 1092.10 5977907.49 583061.28 174.37 3.00 1.46 MWD+IFR+MS 1300.00 27.93 199.81 1263.53 1181.63 5977865.44 583046.72 217.91 3.00 1.30 MWD+IFR+MS 1400.00 30.93 199.93 1350.62 1268.72 5977819.06 583030.53 265.99 3.00 1.17 MWD+IFR+MS ) ) BP KW A Planning Report MAP Company: BP Amoco Date: 12/9/2002 Time: 18:16:01 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) ReCerence: Well: Plan l-121, True North Site: PB l Pad Vertical (TVD) Reference: 81.9081.9 Well: Plan l-121 Section (VS) ReCerence: Well (0.00N,O.00E,211.71Azi) Wellpath: Plan l-121 "A" Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 1469.07 33.00 200.00 1409.21 1327.31 5977784.57 583018.43 301.78 3.00 1.06 MWD+IFR+MS 1500.00 33.77 200.00 1435.04 1353.14 5977768.51 583012.79 318.45 2.50 360.00 MWD+IFR+MS 1600.00 36.27 200.00 1516.93 1435.03 5977714.37 582993.76 374.64 2.50 0.00 MWD+IFR+MS 1700.00 38.77 200.00 1596.23 1514.33 5977656.92 582973.57 434.28 2.50 0.00 MWD+IFR+MS 1733.12 39.60 200.00 1621.90 1540.00 5977637.18 582966.63 454.77 2.50 0.00 l-121 SV5 1800.00 41.27 200.00 1672.80 1590.90 5977596.26 582952.25 497.25 2.50 360.00 MWD+IFR+MS 1869.07 43.00 200.00 1724.02 1642.12 5977552.55 582936.88 542.62 2.50 0.00 MWD+IFR+MS 1900.00 43.00 200.00 1746.64 1664.74 5977532.65 582929.89 563.28 0.00 0.00 MWD+IFR+MS 1900.36 43.00 200.00 1746.90 1665.00 5977532.42 582929.81 563.51 0.00 0.00 SV4 1934.54 43.00 200.00 1771.90 1690.00 5977510.43 582922.08 586.34 0.00 0.00 BPRF 2002.90 43.00 200.00 1821.90 1740.00 5977466.44 582906.62 632.00 0.00 0.00 MWD+IFR+MS 2100.00 46.43 202.60 1890.89 1808.99 5977402.57 582882.48 699.17 4.00 29.00 MWD+IFR+MS 2200.00 50.01 204.98 1957.52 1875.62 5977334.05 582853.13 773.01 4.00 27.16 MWD+IFR+MS 2270.99 52.58 206.52 2001.90 1920.00 5977283.91 582829.61 828.11 4.00 25.57 SV3 2300.00 53.64 207.12 2019.32 1937.42 5977263.08 582819.37 851.23 4.00 24.60 MWD+IFR+MS 2400.00 57.30 209.07 2075.99 1994.09 5977190.02 582781.37 933.43 4.00 24.24 MWD+IFR+MS 2500.00 61.00 210.87 2127.26 2045.36 5977115.22 582739.30 1019.22 4.00 23.14 MWD+IFR+MS 2597.69 64.62 212.50 2171.90 2090.00 5977040.81 582694.48 1106.10 4.00 22.22 SV2 2607.44 64.99 212.66 2176.05 2094.15 5977033.32 582689.81 1114.91 4.00 21.47 MWD+IFR+MS 2700.00 64.99 212.66 2215.19 2133.29 5976962.21 582645.33 1198.78 0.00 0.00 MWD+IFR+MS 2800.00 64.99 212.66 2257.4 7 2175.57 5976885.39 582597.28 1289.39 0.00 0.00 MWD+IFR+MS 2900.00 64.99 212.66 2299.76 2217.86 5976808.57 582549.23 1380.00 0.00 0.00 MWD+IFR+MS 3000.00 64.99 212.66 2342.05 2260.15 5976731.75 582501.18 1470.61 0.00 0.00 MWD+IFR+MS 3100.00 64.99 212.66 2384.33 2302.43 5976654.93 582453.13 1561.21 0.00 0.00 MWD+IFR+MS 3200.00 64.99 212.66 2426.62 2344.72 5976578.10 582405.08 1651.82 0.00 0.00 MWD+IFR+MS 3300.00 64.99 212.66 2468.90 2387.00 5976501.28 582357.03 1742.43 0.00 0.00 MWD+IFR+MS 3400.00 64.99 212.66 2511.19 2429.29 5976424.46 582308.98 1833.04 0.00 0.00 MWD+IFR+MS 3472.64 64.99 212.66 2541.90 2460.00 5976368.66 582274.08 1898.85 0.00 0.00 SV1 3500.00 64.99 212.66 2553.47 2471.57 5976347.64 582260.93 1923.64 0.00 0.00 MWD+IFR+MS 3600.00 64.99 212.66 2595.76 2513.86 5976270.81 582212.88 2014.25 0.00 0.00 MWD+IFR+MS 3700.00 64.99 212.66 2638.04 2556.14 5976193.99 582164.83 2104.86 0.00 0.00 MWD+IFR+MS 3800.00 64.99 212.66 2680.33 2598.43 5976117.17 582116.79 2195.47 0.00 0.00 MWD+IFR+MS 3900.00 64.99 212.66 2722.61 2640.71 5976040.35 582068.74 2286.07 0.00 0.00 MWD+IFR+MS 4000.00 64.99 212.66 2764.90 2683.00 5975963.52 582020.69 2376.68 0.00 0.00 MWD+IFR+MS 4100.00 64.99 212.66 2807.18 2725.28 5975886.70 581972.64 2467.29 0.00 0.00 MWD+IFR+MS 4193.93 64.99 212.66 2846.90 2765.00 5975814.54 581927.50 2552.39 0.00 0.00 UG4A 4200.00 64.99 212.66 2849.47 2767.57 5975809.88 581924.59 2557.90 0.00 0.00 MWD+IFR+MS 4300.00 64.99 212.66 2891.75 2809.85 5975733.06 581876.54 2648.50 0.00 0.00 MWD+IFR+MS 4400.00 64.99 212.66 2934.04 2852.14 5975656.24 581828.49 2739.11 0.00 0.00 MWD+IFR+MS 4500.00 64.99 212.66 2976.32 2894.42 5975579.41 581780.44 2829.72 0.00 0.00 MWD+IFR+MS 4600.00 64.99 212.66 3018.61 2936.71 5975502.59 581732.39 2920.32 0.00 0.00 MWD+IFR+MS 4700.00 64.99 212.66 3060.89 2978.99 5975425.77 581684.34 3010.93 0.00 0.00 MWD+IFR+MS 4800.00 64.99 212.66 3103.18 3021.28 5975348.95 581636.29 3101.54 0.00 0.00 MWD+IFR+MS 4900.00 64.99 212.66 3145.46 3063.56 5975272.12 581588.24 3192.15 0.00 0.00 MWD+IFR+MS 4938.87 64.99 212.66 3161.90 3080.00 5975242.26 581569.56 3227.37 0.00 0.00 UG3 5000.00 64.99 212.66 3187.75 3105.85 5975195.30 581540.19 3282.75 0.00 0.00 MWD+IFR+MS 5100.00 64.99 212.66 3230.03 3148.13 5975118.48 581492.14 3373.36 0.00 0.00 MWD+IFR+MS 5200.00 64.99 212.66 3272.32 3190.42 5975041.66 581444.09 3463.97 0.00 0.00 MWD+IFR+MS 5300.00 64.99 212.66 3314.60 3232.70 5974964.83 581396.04 3554.58 0.00 0.00 MWD+IFR+MS 5400.00 64.99 212.66 3356.89 3274.99 5974888.01 581347.99 3645.18 0.00 0.00 MWD+IFR+MS 5500.00 64.99 212.66 3399.17 3317.27 5974811.19 581299.94 3735.79 0.00 0.00 MWD+IFR+MS 5600.00 64.99 212.66 3441.46 3359.56 5974734.37 581251.89 3826.40 0.00 0.00 MWD+IFR+MS \ ) l BP KW A Planning Report MAP Company: BP Amoco Date: 12/9/2002 Time: 18:16:01 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-121, True North Site: PB L Pad Vertical (TVD) Reference: 81.9081.9 Well: Plan L-121 Section (VS) Reference: Well (0.00N,0.00E,211.71Azi) Wellpath: Plan L-121 "A" Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 5700.00 64.99 212.66 3483.75 3401.85 5974657.54 581203.84 3917.01 0.00 0.00 MWD+IFR+MS 5800.00 64.99 212.66 3526.03 3444.13 5974580.72 581155.79 4007.61 0.00 0.00 MWD+IFR+MS 5900.00 64.99 212.66 3568.32 3486.42 5974503.90 581107.74 4098.22 0.00 0.00 MWD+IFR+MS 5932.13 64.99 212.66 3581.90 3500.00 5974479.22 581092.30 4127.33 0.00 0.00 UG1 6000.00 64.99 212.66 3610.60 3528.70 5974427.08 581059.69 4188.83 0.00 0.00 MWD+IFR+MS 6100.00 64.99 212.66 3652.89 3570.99 5974350.26 581011.64 4279.44 0.00 0.00 MWD+IFR+MS 6200.00 64.99 212.66 3695.17 3613.27 5974273.43 580963.59 4370.04 0.00 0.00 MWD+IFR+MS 6300.00 64.99 212.66 3737.46 3655.56 5974196.61 580915.54 4460.65 0.00 0.00 MWD+IFR+MS 6400.00 64.99 212.66 3779.74 3697.84 5974119.79 580867.49 4551.26 0.00 0.00 MWD+IFR+MS 6500.00 64.99 212.66 3822.03 3740.13 5974042.97 580819.44 4641.87 0.00 0.00 MWD+IFR+MS 6600.00 64.99 212.66 3864.31 3782.41 5973966.14 580771.39 4732.47 0.00 0.00 MWD+IFR+MS 6641.59 64.99 212.66 3881.90 3800.00 5973934.19 580751.41 4770.16 0.00 0.00 Ma 6700.00 64.99 212.66 3906.60 3824.70 5973889.32 580723.34 4823.08 0.00 0.00 MWD+IFR+MS 6800.00 64.99 212.66 3948.88 3866.98 5973812.50 580675.29 4913.69 0.00 0.00 MWD+IFR+MS 6900.00 64.99 212.66 3991.17 3909.27 5973735.68 580627.24 5004.30 0.00 0.00 MWD+IFR+MS 7000.00 64.99 212.66 4033.45 3951.55 5973658.85 580579.19 5094.90 0.00 0.00 MWD+IFR+MS 7100.00 64.99 212.66 4075.74 3993.84 5973582.03 580531.14 5185.51 0.00 0.00 MWD+IFR+MS 7200.00 64.99 212.66 4118.02 4036.12 5973505.21 580483.09 5276.12 0.00 0.00 MWD+IFR+MS 7256.47 64.99 212.66 4141.90 4060.00 5973461.83 580455.96 5327.28 0.00 0.00 Na 7300.00 64.99 212.66 4160.31 4078.41 5973428.39 580435.04 5366.73 0.00 0.00 MWD+IFR+MS 7400.00 64.99 212.66 4202.59 4120.69 5973351.57 580386.99 5457.33 0.00 0.00 MWD+IFR+MS 7500.00 64.99 212.66 4244.88 4162.98 5973274.74 580338.94 5547.94 0.00 0.00 MWD+IFR+MS 7600.00 64.99 212.66 4287.16 4205.26 5973197.92 580290.89 5638.55 0.00 0.00 MWD+IFR+MS 7634.85 64.99 212.66 4301.90 4220.00 5973171.15 580274.15 5670.12 0.00 0.00 Oa 7700.00 64.99 212.66 4329.45 4247.55 5973121.10 580242.84 5729.16 0.00 0.00 MWD+IFR+MS 7800.00 64.99 212.66 4371.73 4289.83 5973044.28 580194.79 5819.76 0.00 0.00 MWD+IFR+MS 7900.00 64.99 212.66 4414.02 4332.12 5972967.45 580146.74 5910.37 0.00 0.00 MWD+IFR+MS 8000.00 64.99 212.66 4456.30 4374.40 5972890.63 580098.69 6000.98 0.00 0.00 MWD+IFR+MS 8100.00 64.99 212.66 4498.59 4416.69 5972813.81 580050.64 6091.59 0.00 0.00 MWD+IFR+MS 8200.00 64.99 212.66 4540.87 4458.97 5972736.99 580002.59 6182.19 0.00 0.00 MWD+IFR+MS 8300.00 64.99 212.66 4583.16 4501.26 5972660.16 579954.54 6272.80 0.00 0.00 MWD+IFR+MS 8400.00 64.99 212.66 4625.44 4543.54 5972583.34 579906.50 6363.41 0.00 0.00 MWD+IFR+MS 8500.00 64.99 212.66 4667.73 4585.83 5972506.52 579858.45 6454.01 0.00 0.00 MWD+IFR+MS 8533.51 64.99 212.66 4681.90 4600.00 5972480.78 579842.34 6484.38 0.00 0.00 Obf base 8600.00 64.99 212.66 4710.02 4628.12 5972429.70 579810.40 6544.62 0.00 0.00 MWD+IFR+MS 8700.00 64.99 212.66 4752.30 4670.40 5972352.88 579762.35 6635.23 0.00 0.00 MWD+IFR+MS 8800.00 64.99 212.66 4794.59 4712.69 5972276.05 579714.30 6725.84 0.00 0.00 MWD+IFR+MS 8900.00 64.99 212.66 4836.87 4754.97 5972199.23 579666.25 6816.44 0.00 0.00 MWD+IFR+MS 9000.00 64.99 212.66 4879.16 4797.26 5972122.41 579618.20 6907.05 0.00 0.00 MWD+IFR+MS 9100.00 64.99 212.66 4921.44 4839.54 5972045.59 579570.15 6997.66 0.00 0.00 MWD+IFR+MS 9200.00 64.99 212.66 4963.73 4881.83 5971968.76 579522.10 7088.27 0.00 0.00 MWD+IFR+MS 9231.15 64.99 212.66 4976.90 4895.00 5971944.83 579507.13 7116.49 0.00 0.00 CM2 9300.00 64.99 212.66 5006.01 4924.11 5971891.94 579474.05 7178.87 0.00 0.00 MWD+IFR+MS 9400.00 64.99 212.66 5048.30 4966.40 5971815.12 579426.00 7269.48 0.00 0.00 MWD+IFR+MS 9500.00 64.99 212.66 5090.58 5008.68 5971738.30 579377.95 7360.09 0.00 0.00 MWD+IFR+MS 9600.00 64.99 212.66 5132.87 5050.97 5971661.47 579329.90 7450.70 0.00 0.00 MWD+IFR+MS 9700.00 64.99 212.66 5175.15 5093.25 5971584.65 579281.85 7541.30 0.00 0.00 MWD+IFR+MS 9800.00 64.99 212.66 5217.44 5135.54 5971507.83 579233.80 7631.91 0.00 0.00 MWD+IFR+MS 9900.00 64.99 212.66 5259.72 5177.82 5971431.01 579185.75 7722.52 0.00 0.00 MWD+IFR+MS 10000.00 64.99 212.66 5302.01 5220.11 5971354.19 579137.70 7813.13 0.00 0.00 MWD+IFR+MS 10100.00 64.99 212.66 5344.29 5262.39 5971277 .36 579089.65 7903.73 0.00 0.00 MWD+IFR+MS 10200.00 64.99 212.66 5386.58 5304.68 5971200.54 579041.60 7994.34 0.00 0.00 MWD+IFR+MS 10300.00 64.99 212.66 5428.86 5346.96 5971123.72 578993.55 8084.95 0.00 0.00 MWD+IFR+MS ) ) BP KW A Planning Report MAP Company: BP Amoco Date: 12/9/2002 Time: 18:16:01 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-121, True North Site: PB L Pad Vertical (TVD) Reference: 81.9081.9 Well: Plan L-121 Section (VS) Reference: Well (0.00N,O.00E,211.71Azi) Wellpath: Plan L-~1 "A" Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 10400.00 64.99 212.66 5471.15 5389.25 5971046.90 578945.50 8175.56 0.00 0.00 MWD+IFR+MS 10500.00 64.99 212.66 5513.43 5431.53 5970970.07 578897.45 8266.16 0.00 0.00 MWD+IFR+MS 10600.00 64.99 212.66 5555.72 5473.82 5970893.25 578849.40 8356.77 0.00 0.00 MWD+IFR+MS 10700.00 64.99 212.66 5598.00 5516.10 5970816.43 578801.35 8447.38 0.00 0.00 MWD+IFR+MS 10800.00 64.99 212.66 5640.29 5558.39 5970739.61 578753.30 8537.99 0.00 0.00 MWD+IFR+MS 10900.00 64.99 212.66 5682.57 5600.67 5970662.78 578705.25 8628.59 0.00 0.00 MWD+IFR+MS 10969.35 64.99 212.66 5711.90 5630.00 5970609.51 578671.93 8691.43 0.00 0.00 CM1 11000.00 64.99 212.66 5724.86 5642.96 5970585.96 578657.20 8719.20 0.00 0.00 MWD+IFR+MS 11100.00 64.99 212.66 5767.14 5685.24 5970509.14 578609.15 8809.81 0.00 0.00 MWD+IFR+MS 11200.00 64.99 212.66 5809.43 5727.53 5970432.32 578561.10 8900.42 0.00 0.00 MWD+IFR+MS 11300.00 64.99 212.66 5851.72 5769.82 5970355.50 578513.05 8991.02 0.00 0.00 MWD+IFR+MS 11400.00 64.99 212.66 5894.00 5812.10 5970278.67 578465.00 9081.63 0.00 0.00 MWD+IFR+MS 11500.00 64.99 212.66 5936.29 5854.39 5970201.85 578416.95 9172.24 0.00 0.00 MWD+IFR+MS 11600.00 64.99 212.66 5978.57 5896.67 5970125.03 578368.90 9262.85 0.00 0.00 MWD+IFR+MS 11700.00 64.99 212.66 6020.86 5938.96 5970048.21 578320.85 9353.45 0.00 0.00 MWD+IFR+MS 11800.00 64.99 212.66 6063.14 5981.24 5969971.38 578272.80 9444.06 0.00 0.00 MWD+IFR+MS 11900.00 64.99 212.66 6105.43 6023.53 5969894.56 578224.75 9534.67 0.00 0.00 MWD+IFR+MS 12000.00 64.99 212.66 6147.71 6065.81 5969817.74 578176.70 9625.28 0.00 0.00 MWD+IFR+MS 12100.00 64.99 212.66 6190.00 6108.10 5969740.92 578128.65 9715.88 0.00 0.00 MWD+IFR+MS 12200.00 64.99 212.66 6232.28 6150.38 5969664.09 578080.60 9806.49 0.00 0.00 MWD+IFR+MS 12300.00 64.99 212.66 6274.57 6192.67 5969587.27 578032.55 9897.10 0.00 0.00 MWD+IFR+MS 12400.00 64.99 212.66 6316.85 6234.95 5969510.45 577984.50 9987.71 0.00 0.00 MWD+IFR+MS 12471.06 64.99 212.66 6346.90 6265.00 5969455.86 577950.36 10052.09 0.00 0.00 THRZ 12500.00 64.99 212.66 6359.14 6277.24 5969433.63 577936.45 10078.31 0.00 0.00 MWD+IFR+MS 12600.00 64.99 212.66 6401.42 6319.52 5969356.81 577888.40 10168.92 0.00 0.00 MWD+IFR+MS 12700.00 64.99 212.66 6443.71 6361.81 5969279.98 577840.35 10259.53 0.00 0.00 MWD+IFR+MS 12800.00 64.99 212.66 6485.99 6404.09 5969203.16 577792.30 10350.13 0.00 0.00 MWD+IFR+MS 12884.92 64.99 212.66 6521.90 6440.00 5969137.93 577751.50 10427.08 0.00 0.00 BHRZ 12900.00 64.99 212.66 6528.28 6446.38 5969126.34 577744.25 10440.74 0.00 0.00 MWD+IFR+MS 13000.00 64.S9 212.66 6570.56 6488.66 5969049.52 577696.20 10531.35 0.00 0.00 MWD+IFR+MS 13050.46 64.99 212.66 6591.90 6510.00 5969010.75 577671.96 10577.07 0.00 0.00 K-1 13100.00 64.99 212.66 6612.85 6530.95 5968972.69 577648.16 10621.96 0.00 0.00 MWD+IFR+MS 13168.70 64.99 212.66 6641.90 6560.00 5968919.91 577615.14 10684.21 0.00 0.00 L-121 Poly 13200.00 64.99 212.66 6655.13 6573.23 5968895.87 577600.11 10712.56 0.00 0.00 MWD+IFR+MS 13227.83 64.99 212.66 6666.90 6585.00 5968874.49 577586.73 10737.78 0.00 0.00 KupC 13300.00 64.99 212.66 6697.42 6615.52 5968819.05 577552.06 10803.17 0.00 0.00 MWD+IFR+MS 13400.00 64.99 212.66 6739.70 6657.80 5968742.23 577504.01 10893.78 0.00 0.00 MWD+IFR+MS 13500.00 64.99 212.66 6781.99 6700.09 5968665.40 577455.96 10984.39 0.00 0.00 MWD+IFR+MS 13535.26 64.99 212.66 6796.90 6715.00 5968638.31 577439.01 11016.34 0.00 0.00 LCU 13600.00 64.99 212.66 6824.27 6742.37 5968588.58 577407.91 11074.99 0.00 0.00 MWD+IFR+MS 13700.00 64.99 212.66 6866.56 6784.66 5968511.76 577359.86 11165.60 0.00 0.00 MWD+IFR+MS 13800.00 64.99 212.66 6908.84 6826.94 5968434.94 577311.81 11256.21 0.00 0.00 MWD+IFR+MS 13842.70 64.99 212.66 6926.90 6845.00 5968402.14 577291.29 11294.90 0.00 0.00 KupA 13900.00 64.99 212.66 6951.13 6869.23 5968358.12 577263.76 11346.82 0.00 0.00 MWD+IFR+MS 14000.00 64.99 212.66 6993.42 6911.52 5968281.29 577215.71 11437.42 0.00 0.00 MWD+IFR+MS 14067.36 64.99 212.66 7021.90 6940.00 5968229.54 577183.34 11498.46 0.00 0.00 TMLV 14100.00 64.99 212.66 7035.70 6953.80 5968204.47 577167.66 11528.03 0.00 0.00 MWD+IFR+MS 14200.00 64.99 212.66 7077.99 6996.09 5968127.65 577119.61 11618.64 0.00 0.00 MWD+IFR+MS 14217.36 64.99 212.66 7085.33 7003.43 5968114.31 577111.26 11634.37 0.00 0.00 MWD+IFR+MS ) } ",},\, ,,,,...__ _ ........""""""^" w...·......""".... _ ............._ ----~'-- -'.....", ) ,/ ·~..·'..r" t.f ~;'" V1~~)~, PROJECT ' . "..\'.>.. T12N AREA \~ T11N w ~ I ¡ I 3£\ " ... \../é~ \:ÞF""r\"~'~/""~ '. 4 %Z!AY;, 3, ( . 2 <. '....'!" ,./~ .j.. - >.'...::,' Lt';~~):!) ~ VICINITY MAP N.T.S. ! i. I I . N-L (NWE-1) L-111i . L-114 . L-SD . " , ,/ L-121 + · N-A (NWE-2) · L-113 · L-1121 · L-NE · L-122 LEGEND + AS-BUILT CONDUCTOR . EXISTING CONDUCTOR I -~~ I PLANT J 15"00'00" GRID L-110 . L-SI . L-116 . L -109 . L-SL . · L-115i · L-117 · L-11S L-01 . L-107 . L-10SI. L-105i. L-106 . L-104 . S-W . L-102 . · L-103i · L-119i · L-120 L-PAD NOTES 1. DATE OF SURVEY: APRIL 18-19, 2001. 2. REFERENCE FIELD BOOK: WO-01-13 PAGES 36-47. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS L-PAD OPERATOR MONUMENTION. 5. BASIS OF ELEVATION IS NWE RP#1(REF WO-01-05-56). ELEVATIONS ARE BP MSL DATUM~ 6. MEAN PAD SCALE FACTOR IS 0.999907827. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 19, 2001. / / ç -S~;;eNët .;;;;;;: ¡: y' diN-;v ~ ~t . LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS L-121 Y= 5,978,078.15 N= 9,819.86 70"21'00.290" 70.3500806" 47.9' 2,357' FSL X= 583,115.89 E= 5,075.00 -149'19'30.711" -149.3251975" 3,801' FEL F. ROb' DRAWN: ObP JACOBS l -- CHECKED: AlliSON 1]__ ,".', DATE: 12/9/02 DRA\\\NG: WOA L-PAD FRB02 WOl 12-00 SHEET: ~ ill~~rnœo JOB NO: JJ RFA SCALE: AS-BUlL T CONDUCTOR JJ RFA (~ AHO L.NIO ~ WELL L-121 1 OF 1 80'1 \llll[Sf na:.UD L,NI( 1"= 130' BY CHK NlCHQM.Q[" AlASI<A er.IQJ 1 12/10/02 R~SEO WELL NAIoIE '" DATA TABLE 012/9/02 ISSUED FOR NF"ORIoIA liON NO, DATE REVISION p0511993 DATE INVOICE I CREDIT MEMO 12/19/2002 INV# CK121702B DESCRIPTION GROSS PERMIT TO DRILL FEE L-- l Z, \ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY: NATIONAL CITY BANK Ashland. Ohio '(8..' ~H.D trr~'r ;AAt t1ftg.{J . ..;; ..,-_r-. ~ ~~J.~_-_._\mI ~IUtJ,_._:~U:;1I TO THE ORDER OF: ALASKA OIL & GAS CONSERVATION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK99501 11·0 5... ~ ~ :¡III -:0.... 20 :¡a c¡ 5-: 0 ¡ 2 78 c¡ bill - _ 0"--'··.. '~~':"CI"'~:!4:4,," ~{t_~~:!.~,,~.:.... DATE CHECK NO. 12/19/2002 P054993 VENDOR DISCOUNT NET R~. . E r t=. I V· t f''% B \...kZ Lv I ¡- ¡. ¡ r¡ ,) 20{Y~ J. ¡\¡ / r \ h I ~¡ \. \j L..~....... v v Alaska OU & Gas Cons. Commission .' Anchorage 56-389 412 No. P 054993 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT ." -. ""- .- **"¡***h,\~-*f***.~$1 00.00*** NO. ~;%~~:~:.~~~~.;~.~~~.~~t::;~:~.~~~~:}~{ ;. :~}i·~::·::A~~i~::i::::}$:::S:··:·~~:{i ;i;; i:::~:\0BT ¢~~~;i(;~t~;:\~~t}i:i::::Ei H '-" -~ ') ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment 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 hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from. records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (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. WELL PERMIT CHECKLIST COMPANY A 1)1 WELL NAME.P8U ¿ - /2/ FIELD & POOL C$lO).1ð INITCLASS O~ /.-o,í ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. W ell located proper distance from other wells.. . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE 11/ :k/o3 APPR DATE \JjGA- '2-/3(03 (Service Well Only) GEOLOGY APPR DATE (~j// - f4;;/e>J I ~xploratory Only) 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . .' . . . . . . . . . 24. If diverter required, does "it meet regulations. .. . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to '-/;ç; 00 psig. ~g. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (ifoff-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... -t PROGRAM: Exp _ Dev $. Redrll _ Re-Enter _ Serv _ Wellbore seg _ GEOL AREA ;> 7 ð UNIT# // ~ \" ('"") ON/OFF SHORE 0...0 (Y\N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N Ý )f' ,/VIAl YN ~ ~"'" f z S~:~C ~ ~ Ai ,,-b 0 y-Ç. ~'to- ~ Ai/k- N' '._ .'~) N i.tJ M VÌÞ// V'(: h ¿~ 1;- d£411,,1f£4 . ~ fÞ'ltvv Ir[ k-I' I 0, S PPí NMSP l7QS ps/. N N Y@ Y Ñ '/'LIÆ- ~ Jr N, A. ( l " GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RPc/fÞ TEM JDH JBR COT DTS 0 2jö:;1 03 / MJW MLB tC>'</e>tJ;' ./~J SFD WGA Rev: 10/15/02 - G:\geology\permits\checklist.doc