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201-136
e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs_ Inserts\Microfilm _Marker,doc ,28. ) 29. ~) FORMATION TESTS GEOLOGIC MARKERS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Schrader Bluff M 4338' Schrader Bluff N 4723' Schrader Bluff 0 4938' Colville Mudstone 5419' CM1 6595' HRZ 7263' Kalubik 7471' Kuparuk C 7703' LCU / Kuparuk B 7864' Kuparuk A 8014' Base Kuparuk / Top Miluveach 8087' 3891' None 4145' 4299' 4664' 5589' 6186' 6380' 6602' 6758' 6904' 6975' 30. List of Attachments: Summary of Pre-Rig Work and Daily. Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble-1f1V1it. &~ Title Technical Assistant Date Cf1- bJ..?. · OS PBU L-114 201-136 305-178 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number N Drilling Engineer: Matt Marilin, 564-4101 Permit No. / Approval o. J' INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: L -114A Prudhoe Bay Unit 50-029-23032-01-00 205-112 Accept: Spud: Release: Rig: 08/09/05 08/15/05 08/23/05 Nabors 9ES PRE-RIG WORK 07/20/05 DRIFTED WI 2.50 CENT & SAMPLE BAILER. TAG AT 7732' SLM +27' KB CORR = 7759' MD, (ALL PERFS OPEN 9' RAT HOLE). SAMPLE BAILER EMPTY. RDMO. 07/26/05 KILL WELL WI 135 BBLS KCL. REDUCE RATE TO 0.5 BPM. TAG TO, CORRECT TO SIL DEPTH OF 7759'. FLAG CT AT 7420'. PUMP DOWN COIL TO COOL PERFS. PUMP 9.7 BBLS OF 15.8# CLASS G CEMENT FROM 7694'. LAY IN AND PULL TO SAFETY. HESITATE. FINAL INJECTIVITY = 1.6 BPM AT 680 WHP. CONTAMINATE FROM 7300' TO 7700. BATCH UP AGAIN AND PUMP 11.3 BBLS OF 15.8# CLASS G CEMENT FROM 7694'. ESTIMATE 2.2 BBLS BEHIND PIPE. SAW GOOD PRESSURE BUMP. HESITATE. GOOD PT. DROP 7/8" BALL AND PUMP BIO FROM SAFETY TO ESTIMATED TOC AT 7420'. CHASE OUT AT 80% WASHING ALL JEWERL Y. FREEZE PROTECT TUBING WITH DIESEL TO 2500'. LEAVE 485 PSI ON WELL. RDMO. JOB COMPLETE. 07/27/05 DRIFTED TO 7392' SLM. TESTED PLUG TO 1500 PSI. FIRST 15 MIN LOSS 40 PSI, SECOND 15 MIN LOSS 0 PSI. WELL LEFT SHUT IN OPERATOR NOTIFIED OF STATUS. 07/29/05 DEPTH CORRELATED TO BP TUBING SUMMARY DATED 16-AUG-2001. STRING SHOT FIRED 7203' - 7216'. TUBING PUNCHER FIRED 7264' - 7266'. CHEMICAL CUTTER FIRED AT 7213'. ) ) BP EXPLORATION Operations Summary Report Page 1 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-114 L-114 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 8/4/2005 Rig Release: 8/23/2005 Rig Number: Spud Date: 8/4/2001 End: 8/16/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/9/2005 00:00 - 06:00 6.00 MOB P PRE Move rig and spot over L-114A. Accepted Rig @ 0600 hrs. 06:00 - 08:30 2.50 WHSUR P DECOMP Check Annulus Pressures, IA 0 psi. OA 250 psi. Install Secondary Annulus Valves on IA and OA. R/U Circulating Lines to Tree for Displacement of Freeze Protection from Wellbore taking Returns Through Choke Manifold to Cuttings Tank 08:30 - 09:30 1.00 WHSUR P DECOMP P/U and R/U DSM Lubricator and Pull BPV. R/D and UD Luburicator. Tubing 0 psi. 09:30 - 10:00 0.50 WHSUR P DECOMP Held Pre-Spud Safety Meeting w/ Toolpusher, WSL and 110:00 - 11 :00 Mudman 1.00 WHSUR P DECOMP R/U Rig Floor to Reverse Out Freeze Protection. Test Lines t/ 3,500 psi 11 :00 - 13:30 2.50 WHSUR P DECOMP Reverse Circulated Diesel f/2,428' at 3 bpm at 500 psi. Switch Directions and Circulate Down Tubing taking Returns Up Annulus at 3 bpm at 230 psi. Total Diesel Recovered - 50 bbls. Monitor Well-Static. Circulate 8.8 ppg 40 bbl Brine Soap Sweep I followed by 150 bbls Clean 8.8 ppg Brine at 4 bpm at 625 psi. I Monitor Well-Static 13:30 - 14:00 0.50 WHSUR P DECOMP Blow Down Choke Manifold and Lines. R/D Same. 14:00 - 14:30 0.50 WHSUR P DECOMP Install TWC and Test from Below t/ '1,000 psi 14:30-16:00 1.50 WHSUR P DECOMP N/D Production Tree. Inspect NSCT Threads on Tubing Hanger 16:00 - 18:00 2.00 BOPSUR P DECOMP N/U BOPE, Install Drilling Riser. 18:00 - 19:00 1.00 BOPSUP P DECOMP R/U Test Joint and Test Manifold. 19:00 - 23:30 4.50 BOPSUF P DECOMP PJSM-Test BOPE's; Blind/Shear and Pipe Rams, Annular, Choke Manifold, Choke and Kill Line Valves, Floor Safety Valves, Upper and Lower IBOP Valves t/250 psi low /3,500 psi high. All Tests held 5 min with No Visual Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor, Nabors Tourpusher and AOGCC Rep. Jeff Jones 23:30 - 00:00 0.50 BOPSUP P DECOMP RID Test Joint and Manifold. Blow Down Top Drive. 8/10/2005 00:00 - 01 :00 1.00 PULL P DECOMP Change Out Bails 01 :00 - 02:00 1.00 BOPSUR P DECOMP P/U and RlU DSM Lubricator and Pull TWC. R/D Lubricator. Monitor Well-Static 02:00 - 03:00 1.00 PULL P DECOMP P/U XO/ Landing Joint and M/U to Tubing Hanger. RlU Tubing Handling Equipment and Camco Contol Line Spooler 03:00 - 03:30 0.50 PULL P DECOMP Pull Tubing Off Seat with 98,000# Up Weight, Continue to Pull Tubing Hanger to Rig Floor, Circulate Surface to Surface w/8.8 ppg Brine at 10 bpm at 3,000 psi. Monitor Well-Static 03:30 - 15:00 11.50 PULL P DECOMP B/O and UD Landing Joint and Hanger. Continue to POH with 3-1/2" 9.2# L-80 IBT-mod Tubing. Recovered 229 Full Jts-2 GLM's-1 HES SSSV-3 Pup Jts-20.12' Cutoff Jt. and 75 SS Contol Line Bands 15:00 - 15:30 0.50 PULL P DECOMP Clean and Clear Rig Floor 15:30 - 16:00 0.50 BOPSUP P DECOMP Install Wear Ring, 9" ID 16:00 - 17:00 1.00 EVAL P DECOMP PJSM-RlU SWS E-Line, RIH with 4.72" Gauge Ring/Junk Basket t/2,870'. POH w/ Same. Junk Basket Clean 17:00 - 18:30 1.50 DHB P DECOMP MIU EZSV on E-Line. RIH and Set at 2,770'. POH w/ E-line and RID SWS 18:30 - 19:00 0.50 DHB P DECOMP Test EZSV x 5-1/2" Casing t/3,500 psi. Held 10 min. Bled Down Pressure and Blew Down Lines. 19:00-21:00 2.00 STCTPL P DECOMP PJSM-RlU Handling Tools for 3-1/8" DC's and 2-7/8" PAC DP. Load Pipeshed with DC's and Strap Same. 21 :00 - 00:00 3.00 STCTPL P DECOMP P/U and MIU 5-1/2" Casing Cutter BHA: 3-3/4" Multi-String Printed: 8/26/2005 11 :38:53 AM ) ) BP EXPLORATION Operations Summary Report Page 2 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-114 L-114 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 8/4/2005 Rig Release: 8/23/2005 Rig Number: Spud Date: 8/4/2001 End: 8/16/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/1 0/2005 21 :00 - 00:00 3.00 STCTPL P DECOMP Cutter wI 3· Knives-XO-XO-Stabilizer-3 x 3-1/8· DC's. Total BHA Length = 96.99'. NOTE: While Picking up DC's Heavy Internal Scaling was Encountered During the Rabbiting Process. Decision was Made to Flush DC's wI Rig Pumps Prior to RIH wI BHA 8/11/2005 00:00 - 03:30 3.50 STCTPL P DECOMP RIH wI 2-7/8· PAC DP. Picking Up from Pipeshed 1 x 1. Tag EZSV at 2,775' 03:30 - 04:00 0.50 STCTPL P DECOMP PIU and MIU XO's from Top Drive to 2-7/8· PAC DP 04:00 - 05:00 1.00 STCTPL P DECOMP Break Circulation at 2 bpm, 385 psi. Up Wt. 65K, Dn Wt. 60K. Shut Down Pumps. Position Cutter Blades at 2,720'. Bring Rotary Up to 100 rpm, 1,000 ftllbs Torque. Bring Pumps up to 725 psi at 2.5 bpm. Rotated Steady for 20 min. Observed Pressure Loss of 65 psi. No Increase or Decrease in Annulus Pressure of 200 psi. Increase Pump Rate to 3.5 bpm at 935 psi. 05:00 - 06:00 1.00 STCTPL P DECOMP Pump 25 bbl Hi-Vis Sweep Surface I Surface at 3.5 bpm at 1,015 psi. Continously Rotating at Cut with 100 rpm through out Circulatio 06:00 - 08:00 2.00 STCTPL P DECaMP PJSM-Close Annular and Pump Down DP. Lined Up to take Returns up OA Through the Choke to Cuttings Tank. Pressured up to 700 psi. OA Pressure Steady at 180 psi. Bled Down OA to 0 psi. Bring DP Pressure up to 1,240 psi. No Returns, Pressure Held Steady. Bled Down all Pressure. Open Annular. Close OA. 08:00 - 10:30 2.50 STCTPL P DECOMP POH wI 2-7/8" PAC DP 10:30 - 11 :30 1.00 STCTPL P DECOMP UD Cutter-No Wear on Cutter Blades, P/U New Cutter 11 :30 - 12:00 0.50 STCTPL P DECOMP Test 5-1/2· Casing to 3,500 psi. Good Test 12:00 - 14:30 2.50 STCTPL P DECOMP RIH wI 5-1/2" Casing Cutter. Tag EZSV at 2,775' 14:30 - 15:00 0.50 STCTPL P DECOMP PIU to 2,580'. Pump at 2.5 bpm, 555 psi. Slack Off and Located 5-1/2" Collar at 2,709' 15:00 - 16:00 1.00 STCTPL P DECOMP Position Cutter at 2,715'. Cut Casing with 100 Rotary RPM, 705 ftllbs Torque, 3.25 bpm at 780 psi. 16:00 - 16:30 0.50 STCTPL P DECOMP Increase Pump to 4-1/2 bpm, 1,500 psi, 680 ftllbs Torque. Shut Down Pump and P/U above Cut, Slack Off with Pumps at 3.5 bpm at 530 psi. to Verify Cut. Blades Engaged Cut at 2,715' and Took Weight 16:30 - 17:00 0.50 STCTPL P DECOMP Closed Annular. Pump Down DP Attempting to Take Returns up OA through Choke to Cuttings Tank. Pressured up to 980 psi. Started Pumping Fluid Away with No Returns from OA. Shut Down Pumps and Bled Down Pressure. Pump Down OA and Pressured up to 2,500 psi. No Bleed Off 17:00 - 17:30 0.50 STCTPL P DECOMP Held 2,500 psi on OA. No Bleed Off 17:30 - 21 :00 3.50 STCTPL P DECOMP Bled Down OA Pressure and Leave Open to Cuttings Tank. Pump Down DP with 102 deg 8.8 ppg Brine, Taking Returns up IA. Circulating at 3.5 bpm, 1500 psi. 21 :00 - 21 :30 0.50 STCTPL P DECOMP Shut Down Pumps and Switch to OA. Pressure up on OA in 500 psi Increments to 2,500 psi. No Pressure Loss at Each Stage. 21 :30 - 00:00 2.50 STCTPL P DECOMP Circulate Heated 8.8 ppg Brine Down DP Taking Returns UP IA at 3.5 bpm, 1,500 psi 8/12/2005 00:00 - 02:00 2.00 STKOH P DECOMP POH wI 2-7/8" PAC DP 02:00 - 02:30 0.50 STCTPL P DECOMP B/O and UD 3-1/8" DC's, UD 5-1/2" Casing Cutter 02:30 - 03:00 0.50 STCTPL P DECOMP C/O Elevators, P/U Joint 4" DP, Pull Wear Ring Printed: 8/26/2005 11 :38:53 AM ) ) BP EXPLORATION Operations Summary Report Page 3 ,. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-114 L-114 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 8/4/2005 Rig Release: 8/23/2005 Rig Number: Spud Date: 8/4/2001 End: 8/16/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/12/2005 03:00 - 03:30 0.50 STCTPL P DECOMP P/U and M/U 5-1/2" Casing Spear w/4.961 Grapple on 4" DP 03:30 - 05:30 2.00 STCTPL P DECOMP RIH w/ Spear Assy. Spear Stopped at 25'. Try to Work Spear through Hanger, w/o success. Released Spear and POH. Suspect Pack-off. Pull Pack-off and Rerun Spear. Stopped at 25'. Worked Spear Free. POH w/ Same 05:30 - 06:00 0.50 STCTPL P DECOMP Clear and Clean Rig Floor 06:00 - 08:00 2.00 STCTPL P DECOMP C/O Bails, P/U 200 Ton Elevators, M/U 5-1/2" BTC x HT40 XO, Floor Safety Valve and Circulating Head 08:00 - 10:30 2.50 STCTPL P DECOMP P/U Landing Joint and M/U to 5-1/2" Hanger. Pull 210K, (23" stretch). Work Pipe f/ 50k - V 21 OK with 500 psi on 5-1/2" Casing, w/o success. Work Pipe V 235K w/o success. Bled Down Pressure to 0 psi. 10:30 - 11 :00 0.50 STCTPL P DECOMP Pump Down OA and Pressure Up V 2,350 psi in Attempt to Circulate OA and IA. No Communication. Bled Down All Pressure. 11 :00 - 12:30 1.50 STCTPL P I DECOMP R/D Landing Joint, XO, Safety Valve and Circulating Head. C/O Elevators and Bails, RIU 4" Elevators 12:30 - 16:00 3.50 STCTPL P j DECOMP P/U and M/U Jarring Assy. wI Spear (4.961 Grapple). MIU Landing Joint to Hanger. Spear Landing Joint w/ Jarring Assy. Jarring on 5-1/2" Casing with 235 Up Wt. Grapple Failed. B/O and LID Spear Assy. B/O and LID Landing Joint. 16:00 - 16:30 0.50 STCTPL P DECOMP Inspect Derrick and Top Drive 16:30 - 17:30 1.00 STCTPL P DECOMP P/U and M/U Multi-Sring Cutter (w/3" Knives), 3 x 31/8" DC's. Total BHA Length = 96.73' 17:30 - 19:00 1.50 STCTPL P DECOMP RIH w/2-7/8" PAC DP V 2,615'. 19:00 - 19:30 0.50 STCTPL P I DECOMP M/U Top Drive and Established Parameters; Up Wt. 62K, Dn Wt. 60K, Break Circulation w/ 2.5 bpm, 500 psi. S/O and Found 5-1/2" Collar at 2,625'. Shut Down Pumps and S/O to Position Knives at 2,627' 19:30 - 20:30 1.00 STCTPL P DECOMP Cut 5-1/2" Casing at 2,627' w/100 Rotary rpm (680 tVlbs Torque w/o Pump). Pump Rate 3.5 bpm, 1,100 psi, 730 fVlbs Torque. Observed Pressure Loss of 60 psi. Increased Pump Rate to 4.5 bpm, 1,640 psi. 20:30 - 21 :00 0.50 STCTPL P DECOMP Circ Hi-Vis Sweep S/S. Continuing to Rotate at 100 rpm at 2,627' While Circulating Sweep Around. Shut Down Rotary and Pumps. P/U V 2,635' Bring Pumps Up to 600 psi. SIO and Engaged Cut w/ Knives at 2,627'. Repeat Process to Verify Cut. 21 :00 - 22:30 1 .50 STKOH P DECOMP POH w/2-7/8" PAC DP 22:30 - 23:00 0.50 STCTPL P DECOMP UD 3-1/8" DC's & 5-1/2" Casing Cutter. Lost 1 Knife from Cutter, 3" x 1-1/4" x 5/8" 23:00 - 00:00 1.00 STCTPL P DECOMP C/O Elevators, P/U 5-1/2" Landing Joint and M/U to Casing Hanger. M/U Top Drive to Landing Joint 8/13/2005 00:00 - 01 :30 1.50 STCTPL P DECOMP Work 5-1/2" Casing f/2,627' - V 2,600'. String Came Free at 325K. Intermittent Drag to 325K.Attempting to Circulate w/o success 01 :30 - 02:30 1.00 STCTPL P DECOMP B/O and UD Landing Joint and Casing Hanger 02:30 - 03:30 1.00 STKOH P DECOMP POH w/5-1/2" Casing w/O Circulating V 2,425' 03:30 - 05:00 1 .50 STKOH P , DECOMP Close Annular and Circulate 45 bbls 8.8 ppg Brine Down Casing Taking Returns up OA to the Cutttings Tank. Open Annular and Circulate 8.8 ppg Brine S/S. Pump 50 bbls Safe-Surf Pill followed by 40 bbls 120 deg Brine. Pump Additional S/S at 10 bpm to Clean Casing. Printed: 8/26/2005 11 :38:53 AM ) ) BP EXPLORATION Operations Summary Report Page 4 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-114 L-114 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 8/4/2005 Rig Release: 8/23/2005 Rig Number: Spud Date: 8/4/2001 End: 8/16/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/13/2005 05:00 - 08:30 3.50 STKOH P DECOMP POH wI 5-1/2" Casing 08:30 - 09:30 1.00 STKOH P DECOMP Clean and Clear Rig Floor, UD Baker Tools, RID and UD Casing Equipment 09:30 - 12:00 2.50 STKOH P DECOMP RIH wI 2-7/8" PAC DP From Derrick 12:00 - 14:30 2.50 STKOH P DECOMP POH LDDP 14:30 - 15:00 0.50 STKOH P DECOMP RID and UD 2-7/8" Handling Tools 15:00 - 16:00 1.00 STKOH P DECOMP Slip and Cut Drilling Line. Inspect Drawworks 16:00 - 16:30 0.50 STKOH P DECOMP Install Wear Ring 16:30 - 17:00 0.50 STKOH P DECOMP PIU 15 Joints 4" DP and Stand Back in Derrick 17:00 - 18:00 1.00 STKOH P DECOMP P/U Milling BHA; Pilot Mill-3 x Junk Baskets-Bit Sub-Jars-9 x 4-3/4" DC's- XO. BHA Total Length = 306.33' 18:00 - 19:30 1.50 STKOH P DECOMP RIH w 4" DP. Picking Up From Pipeshed 1 x 1 19:30 - 20:00 0.50 STKOH P DECOMP MIU Top Drive. Established Parameters; Up Wt. 85K, Dn Wt. 80K, Rt Wt. 82K, Pump 8 bpm, 350 psi, Rotary 65 rpm, 900 Wlbs Torque. Wash Dn fl 2,544'. Mill Started Taking 2/3K Wt. at 2,550' - tJ 2,627'. Mill 5-1/2" Casing fl 2,627', WOM 3/4K. 80 rpm, 1,100 ftJlbs Torque. 20:00 - 00:00 4.00 STMILL P DECOMP Mill 5-1/2" Casing fl 2,627' - tJ 2,633'. WOM 3/4K. 80 rpm, 1,250 ftJlbs Torque. 8 bpm, 500 psi. Pumping Hi-Vis Fibre Sweep Every 5'. Weighted Fibre Sweep Every 20' 8/14/2005 00:00 - 12:00 12.00 STMILL P DECOMP Mill fl 2,633' - tJ 2,691'. Up Wt. 83K, Dn Wt. 80K, Rt Wt 80K, Pump 8 bpm, 585 psi, Rotary 100 rpm, 1450 ftJlbs Torque. Pumping Hi-Vis Sweep Every 5' tJ 2,640', Every 10' tJ 2,690' 12:00 - 14:00 2.00 STMILL P DECOMP Circulate and Condition Mud; Pump 27 bbls Weighted Fibre Sweep followed by 23 bbls Hi-Vis Sweep,. Back Ream to 7-5/8" shoe at 2,636'. Circulate Bottoms Up 14:00 - 15:30 1.50 STMILL P DECOMP POH wI 4" DP 15:30 - 16:30 1.00 STMILL P DECOMP UD Milling BHA; Recovered 1/2 gal. Metal Cuttings from Junk Baskets 16:30 - 17:30 1.00 STMILL P DECOMP Pull Wear Ring, PIU BOPE Flushing Tool, Function All Rams and Annular, Flush Choke Line. Flush BOPE of Metal Cuttings. Install Wear Ring, 9.937 ID, UD Flushing Tool 17:30 - 18:30 1.00 STKOH P DECOMP RIU 2-7/8" Handling Tools. RIH wI 2-7/8" Mule Shoe- 4 Stands 2-7/8" PAC DP- 2 x XO. Total Stinger Length = 380.36' 18:30 - 21:00 2.50 STKOH P DECOMP RIH wI 4" DP. P/U from Pipeshed 1 x 1 to 2,775' 21 :00 - 21 :30 0.50 STKOH P DECOMP Circulate and Condition Mud. Held PJSM wI WSL, Rig Crew, SCH Cementers, MI and Veco while Circulating. 21 :30 - 22:30 1.00 STKOH P DECOMP RIU Cement Head, Pump 5 bbls Water, Shut In Cement Head, Test Lines to 3,500 psi. Pump 5 bbls water, 14 bbls 17 ppg Class "G" Cement, 3.28 bbls water. Switched to Rig Pump and Displace Cement wI 19.5 bbls 8.8 ppg Brine at 3 bpm, 235 psi. RID Cement Head and POH with 5 stand 4" DP tJ 2,346'. CIP AT 2215 HRS. 22:30 - 23:00 0.50 STKOH P DECOMP Circulate Bottoms Up at 450 gpm at 680 psi. No Cement at BU 23:00 - 00:00 1.00 STKOH P DECOMP POH wI 4" DP 8/15/2005 00:00 - 01 :30 1.50 STKOH P WEXIT POH wI 4" DP and Stand Back In Derrick. POH wI 2-7/8" PAC Dp and UD Same 01 :30 - 02:00 0.50 STKOH P WEXIT RID 2-7/8" Handling Tools 02:00 - 06:30 4.50 STKOH P WEXIT PIU 111 Joints (3,470') 4" DP and Stand Back In Derrick 06:30 - 07:00 0.50 STKOH P WEXIT Pull Wear Ring 07:00 - 08:00 1.00 STKOH P WEXIT P/U BOPE Flushing Tool, Function Test Rams and Annular, Flush Stack, UD Flushing Tool 08:00 - 08:30 0.50 STCTPL P WEXIT Test Cement Plug tJ' 1,500 psi. Good Printed: 6/26/2005 11 :38:53 AM ) ) Page 5 .. BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-114 L-114 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours Task Code NPT Phase 8/1 5/2005 08:30 - 10:00 1.50 BOPSUPP WEXIT 10:00 - 10:30 0.50 BOPSUP P WEXIT 10:30 - 12:00 1.50 BOPSUF P WEXIT 12:00 - 13:00 1.00 BOPSUP P WEXIT 13:00 - 15:30 2.50 STKOH P WEXIT 15:30 - 16:00 0.50 STKOH P WEXIT 16:00 - 17:30 1.50 STKOH P WEXIT 17:30 - 18:00 0.50 DRILL P INT1 18:00 - 19:00 1.00 DRILL P INT1 19:00 - 20:00 1.00 DRILL P INT1 20:00 - 22:00 2.00 DRILL P INT1 22:00 - 00:00 2.00 DRILL P INT1 8/16/2005 00:00 - 01 :00 1.00 DRILL P 01 :00 - 02:00 1.00 02:00 - 03:30 P 1.50 DRILL P 0.50 DRILL P 1.00 DRILL P PROD1 PROD1 PROD1 I PROD1 PROD1 Start: 8/4/2005 Rig Release: 8/23/2005 Rig Number: Spud Date: 8/4/2001 End: 8/16/2005 Description of Operations Install Test Plug, Remove Mouse Hole and Drilling Riser. NID BOPE FMC Rep. Inspected Csg Bowl. One area of minor scratching. Dress with flapper wheel and sand paper to remove any sharpe edges. OK NIU BOPE, Install Drilling Riser and Mouse Hole Test Csg. Spool x Tbg. Spool Flange to 250 psi low/3,500 psi high. Test Held for 5 min Each wlo Pressure Loss. RID Test Equipment and Remove Test Plug. PIU and MIU Directional BHA; Bit, Motor (1.15 ABH), By Pass Sub, NM Lead DC, NM Stabilizer, MWDILWD, VPWD, ADN, 2 NM Flex DC, XO, 1 HWDP, Jars, 20 HWDP, Ghost Reamer. Total BHA Length = 860.06' Test MWD Tools at 860',260 gpm, 740 psi, Good Test. RIH wi 4" Dp. Tag Cement at 2,406' Drill Cement fl 2,406' - tJ 2,657' Drill f/2,657' - tJ 2,677', KOP Circulate, Pump 43 bbl Spacer and Displace 8.8 ppg Brine 8.8 ppg LSND Mud Perform LOT with following results: EMW = 13.8 P ,Test mud= 8.8; TVD=2598 Surface pressure=675 Drill f/2,677' - tJ 2,822'. Observed Increase ow, Shut Well In Let Pressures Stabilize, Initial SICP 270 i, Initial SIDPP 60 psi 2210 hrs. 2217 hrs. 2220 hrs. 2245 hrs. DPP 80 psi SIDPP 110 psi SIDPP 150 psi SIDPP 270 psi Start Drille Kill Method. Circulate 8.8 ppg Mud. STB Stks = 497, B Stks = 1,475, Total Stks = 1.972 Stks. ICP 480 psi, At 0 Stks. Away Lost Returns. Shut Down Pumps, Shot Well . SICDP 270 psi, SIDPP 150 psi. Resume Pumping wi New Valve, ICP 380 psi. Continue Pumping at 34 spm Until 8.8 ppg Mud at Surface Shut Down Pumps, Shut Well In, Let Pressures Stabilize, SICP 150 psi, SIDPP 150 psi. Bled Down 50 psi, Pressure Stabilized at 100 psi, Bled Down 50 psi to 50 psi, Pressure Stabilized at 50 psi, Bled All Pressure Down to 0 psi. Opened Annular and Monitor Well. Well Started to Flow Gradually Increasing in Volume, Shut Well In. Monitor Pressures; Final Shut In Pressure SICP 150 psi, SIDPP 150 psi. Weight Mud in Pits to 9.2 ppg. Start Pumping 9.2 ppg LSND Mud. ICP = 400 psi, FCP = 348 psi. Circulated Around Until 9.1 + ppg Back to Surface. Shut Down Pumps, Shut In Well, SICP = 90 psi, SIDPP = 90 psi. Bled Down 5 bbls Mud. CBU wi 9.2 ppg Using Drillers Method. Shut Down Pump, Shut In Well. SICP 0 psi, SIDPP 0 psi. Open Up Well. Observed Small Amount of Flow. Shut In Well After 20 min SICP 20 psi, SIDPP 0 psi. Circulate Around 9.2 ppg Mud at 52 spm 300 psi (SPR) Through Choke. Shut down pumps, monitor pressure, zero Printed: 8/26/2005 11 :38:53 AM ) ) ~r~ '~ I I ì r i : II II [ ~r: , I i I I l0U !í 1 [1 ¡/M (QCJ n/7 /'t,l~\ . ,i: : ö\ \.'\ [I:·~ /;' \ \ . \!I /,~,\I...,\ i¡~~ ¡' ~ I \' b!LJ U l~~) tI\j Uu FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AlWD GAS CONSERVATION COltDllSSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ro bert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~ot- 13" I Re: Prudhoe Bay L-114 Sundry Number: 305-178 SCA¡\JNED JUL 1 4 20.05 Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on liday or weekend. A person may not appeal a Commission decisio to 'uperior Court unless rehearing has been requestedc. ~ S1 er y, , ~o~ . No man ~i~m DATED this 1.3 day of July, 2005 Encl. 1. Type of Request: II Abandon / 0 Suspend 0 Operation Shutdown 0 Perforate o Alter Casing 0 Repair Well II Plug Perforations 0 Stimulate o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver \H4it 7( It f1-t.~Oç 'Ó ) STATE OF ALASKA ) RECEIVEDÄ0 ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 0 8 2005 ~ APPLICATION FOR SUNDRY APPROVAL . '.~ 20 AAC 25.280 A\aska Oi\ & Gas Cons. Co~m'sslon ~Mili_for Sidetrack II Other o Re-Enter Suspended Well o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Claj$: 181 Development 0 Exploratory o Stratigraphic 0 Service 76.30 9. Well Name and Number: 5. Permit To DJiIl Number 201-136 / 6. APINumbe~ / 50- 029-23032-00-00 PBU L-114 / 99519-6612 8. Property Designation: Total Depth MD (ft): 8270 Casi'rig '..". Structural Conductor Surface Intermediate Production Liner 1 O. Field 1 Pool(s): ADL 028239 Prudhoe Bay Field 1 Borealis Pool , " RRI:S·ENT WEI'I" CONI"\I~IOf\I$I:IMr.j ^ D)'!,. ',., .:"'....'.,.:,,,.,!:...:,......,..·..:1,;<.,,:.'.'.'.·,·,'.'.I:,¡'I··,','.:.',.....,·,'..'.;:.I1.',','1'.',1,'""·...',,,':'."'. i.,"I·...·,.":'.,:.',,:,,,:.:,:,'.,','.,',,1,:.',:,' ',., 1 ,""". ," ...,:" ~' ,'." :. . .,.....,......., ...~~,,,: . ,:: .'~ .1' .,' ........ ..,':,",~II~I~!<",',';,,: :.",'::::::,,: Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7155 8158 7045 NIA N/A ,···.··'.Lengfh .""'," '····,'$ize "M,D .' 'nip, .·..Burst,.Calla'pse 106' 20" 106' 106' 1490 2610' 7-5/8" 2637' 2598' 6890 7414' 5-1/2" 7438' 6349' 7000 815' 3-1/2" 7438' - 8253' 6349' - 7139' 10160 470 4790 4990 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): 7704' - 7750' 6603' - 6647' Packers and SSSV Type: 3-1/2" HES XDB BVN (Nipple) Tubing Size: 3-1/2",9.2# Tubing Grade: L-80 Packers and SSSV MD (ft): 2193' Tubing MD (ft): 7442' 12. Attachments: B Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: / o Exploratory 181 Development 0 Service / 15. Well Status after proposed work: BOil ./' DGas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name RQbert Tirpack Title Senior Drilling Engineer Sianature /~~.~ Phone ">£¿¡~~/~t, Date 7á/J- . / . Commission Use Only 07/20/05 Date: Contact Matt Martyn, 564-4101 Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity [!(i3op Test 0 Mechanical Integrity Test 0 Location Clearance T€<;.t- ,~oPE fc ~C;OD p~' Other: "-1) f' \~ lÍt d h i' / c ~ 4c~ ( Subsequent ~ : l (fí, Approved By: / ~ Form 1 0-403 Re~d 11 2004 ~ I Sundry Number: 3oS-/7Y W'b INtr-{d JL ç; cLe .t; ~K RBDMs 8Fl JUL 1 4 2005 APPROVED BY COMMISSIONER THE COMMISSION I,v.-R ( I L-II{A.. '---- ORIGINAL Date Ø~[ . " ) ) bp G~&r.tIr. To: Winton Aubert - AOGCC Date: July 7, 2005 From: Matt Martyn - BPXA GPB Rotary Drilling Subject: Reference: L-114A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-23032-00 Approval is requested for the proposed P&A of Borealis well L-114 (Permit# 201-136). This microbore Kuparuk producer was originally drilled in 2001 and produced at 4000+ bopd, but went to high water cut / shortly after the L-111 i was put on injection and is now producing 200 bopd and 3500 bwpd. L-114 is thought to be in communication with a conductive fault approximately 400 feet to the north. Sidetracking the well 1400 feet to the southwest should return the well to normal oil production rates ,/ The sidetrack is currently scheduled for Nabors rig 9ES, beginning around August 1 ¡th 2005, after the completion of the L-03 Grassroots well. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Scope Pre-RiQ Work: 1. Drift 3-1/2" tubing as deep as p sible. 2. Fluid pack tubing and IA wit eaWater. 3. P&A production interval wi ~6b1S cement to 7,420' MD & obtain squeeze. / 4. Tag TOC. 5. Pressure test 3-1/2" tubing and P&A plug. 6. Chemical cut the 3-1/2" tubing at -7210' MD (1st full joint above GLM 2). / 7. Circulate to seawater and freeze protect with diesel. 8. Test the casing and tubing pack-ofts. Test the OA. Function all Lock Down sc7rews. 9. Set BPV. Secure well. Remove the wellhouse. If necessary, level the pad. RiQ Operations: 1. MIRU Nabors 9ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. 3. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 3-1/2" tubing from pre-rig cut. 5. RIH (picking up 2-7/8" DP) w/5.5", 15.5# bridge plug and set at ?l-1Ð\MD (50' below cut point). 6. Pressure test casing to 3500 psi for 10 minutes. /' // / 7. Swap over to 9.2 ppg LSND cutting/drilling fluid. Spot an }á' ppg Dffí on the bridge plug to -50' above the cut point. ~ 8. RIH with 5.5, 15.5# mechanical casing cutting assembly to top of bridge plug 9. Cut 5.5" casing at 2720' MD (80' below surface shoe) & circulate out IA to 9.2# mud. 10. Attempt to pull on casing to verify good cut. POOH (laying down 2-7/8" DP) w/ casing cutter. . '\ 11. Pull 5.5" casing from cut. / 12. RIH w/ 4" drillPiPtid a 2-7/8" cement stinger. Tag bridge plug in lower casing stub. Circulate bottoms up. 13. Spot a balanced 17 ~ g cement kick-off plug from EZSV' to -2500'. WOC. / 14. MU 6-3/4" drilling sembly with Dir/GR/Res/Dens/Neu/PWD and RIH. Drill excess cement in 7-5/8" casing to surface casing shoe. 15. Kick off and drill 6-3/4" hole -20' past cement kick-oft plug. Perform LOT. T~s to'" 40'~ ~ P )"<1\/ fÅ, I . L-114A Application for Sundry ) ') 16. Drill the 6-3/4" hole, turning at 4°/100' to a 58° hold angle. 17. Verify that the mud weight is at least 10.0 ppg prior to cutting HRZ. 18. Drill ahead to TD at -8803' (-150' MD below LCU/KUP-B). 19. Condition hole for running 5.5" 17# x 3.5" 9.2# casing. 20. Run and cement the production casing in a single stage (expected TOC=3600' MD) Displace the cement with 8.5 ppg filtered seawater. 21. Freeze protect the 5-1/2" x 7-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 22. Test casing to 3500 psi for 30 minutes. 23. Run the 3-1/2", 9.2#, L-80 IBT-Mod completion assembly. Test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below to 1000 psi. 24. AU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. 25. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 26. Rig down and move off. Post-RiQ Operations: 1. Install wellhouse, flowlines and instrumentation. 2.' MIRU slickline. 3. Drift & Tag PBTD & Install gas lift valves. 4. MIRU E-Line. Record Jewelry Log & Perforate well (Approximately 40' of perforations). 5. POP well and evaluate production for -2 months prior to frac job to ensure trac will be effective. Estimated Pre-rig Start Date: 7/20/05 Estimated Spud Date: 8/17/05 Matt Martyn Operations Drilling Engineer 564-4101 - Office 632-3862 - Cell 564-4040 - Fax Mart49@bp.com L-114A Application for Sundry ) TREE = 3-1/8" 5MOW WELLHEAD = 11" Frv1C AClUA TOR = KB. ELEV = - J.F. ELEV = ,OP= IVax Angle = Datum rvo = Datum TV D = 76.3' 49.4' 1591' 55 @ 4052' 7780' 6600'SS 7-5/8"CSG, 29.7#, L-80, ID= 6.875" H 2637' ) Minimum ID = 2.75" @ 2193' 3-112" HES SSSVN PERFORATION SUMMA. RY REF LOG: ANGLEA TTOP ÆRF: 15 @ 7704' f\hte: Refer to A"oductbn œ for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 2-1/2" 6 7704 - 7750 0 09/13/01 1 5-1/2" CSG, 15.5#, L-80, BTC, ID= 4.950" 1-1 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 1-1 15-1/2" X 3-1/2" CSGXO, ID =2.968" 1-1 'I DATE '~ 08/17/01 f 09/13/01 12/30/02 04/08/03 05/15/03 OS/28/03 7425' 7431' 1 FBTD H 13-1/2" CSG, 9.2#, L-80, NSCT, ID = 2.992" H REV BY COM'v1ENTS CHIKAK ORIGINAL COMPLETION CWS/KK ÆRFS DA ClKK GL V CORRECTIONS DRSlTP TV D'MD CORRECTIONS JCM'TLH GL V C/O MI-VTLP GLV C/O DA1E L-114/' '- ~ ;.;...:" 7438' I ~ r/} --I e ~ ) SAFETY NOTES: 981' 1-17-5/8" TAM PORf COLLAR I 2193' 1-13-112" HES XDB BVN,ID = 2.75" I GAS LIFT MA.NDRELS L ST MD TVD DEV lYÆ VLV LATCH FORf DATE 4 3695 3423 49 KBG-2 DOI'vE BL 16 OS/28/03 3 6246 5226 37 KBG-2 SO BL 20 05/14/03 2 7234 6084 24 KBG-2 DMY BL 08/17/01 1 7353 6194 21 KBG-2 DMY BL 10/11/01 I ~ 8158' 8253' REV BY COM'v1ENlS l 7379' 1-13-1/2" HES XNP, ID=2.75" 7425' 1-1 TOP OF BKR PBR, ID =4.00" I 7442' 1-13-1/2" BKR SEAL ASSY, D = 3.00" I 7489' 1-13-1/2" HES X N P, ID = 2.75" 7509' 1-13-112" HES X NP, ID = 2.75" 7551' H20' RJPJT W / RA TAG I 8146' H10' RJPJT W /RA TAG I BOREALIS LNIT WELL: L-114 PERMIT No: 2011360 AR No: 50-029-23032 SEe 34, T12N R11 E, 2346' NSL & 3844' WEL BP Exploration (Alaska) ) ~ ) Borealis L-114A: TREE: 3-1/8" - 5M CIW L-80 WELLHEAD: 11" - 5M FMC G5 11808' Top of Kick-Off Cement 12537'1 7-51If'i 29. 7 ~~~;m' Br .411 , ! 2720' 5-1/2",15.5 # - EZSV 2770' 5-1/2", 15.5 #/ft, L-BO, BTC-Mod 3-1/2" 'X' Landing Nipple 7379' Top of P&A Cement 7420' 5-1/2"x3-1/2" XO above Kuparuk 7437' I L-114 Perfs @ 7704'-7750' MD I 3-1/2" 'X' Landing Nipple 7489' 3-1/2" 'X' Landing Nipple 7509' Plug Back Depth 3-1/2",9.2 #/ft, L-80,IBT Mod Date 14-J un-OS Rev By MJM Proposed Completion / Cellar Elevation = 47.80' RKB - MSL = 76.30' I I 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 3-112" x 1.5" Gas Lift Mandrels with handling pups installed. L GAS LIFT MANDRELS # MD/lVD Size Val\e Type 7 2014' 12000' 3.5" x 1" DK-1/Bottom Latch 6 2639' 12600' 3.5" x 1" DK-1/Bottom Latch 5 3635' 13400' 3.5" x 1" DK-1/Bottom Latch 4 4954' /4100' 3.5" x 1" DK-1/Bottom Latch 3 6277' 14800' 3.5" x 1" DK-1/Bottom Latch 2 7434' 15500' 3.5" x 1" DK-1/Bottom Latch 1 ? I?' 3.5" x 1" DCK-3/Bottom Latch ~ L 5-1/2",17 #/ft, L-80, BTC /"--) 41 'I Proposed Top of Cement 3-1/2" 9.2# IBT Mod L-80, Tubing ~ 3-1/2" 'X' Landing Nipple with 2.813" seal bore,1 jt above PBR L 3-1/2" Seal Asembly ~BR 1 T wi 4 Seal Sedio". (4.0· 00, 3.0" ID) ::::::s..1/2"X3-1/2" XO placed above Kuparuk L . 18318' 1 18335' 1 "- 18385' I ~ 18465' II ~ 3-112" 'X' Landing Nipple with 2.813" seal bore 10 ~ 3-1/2" 'X'Landing Nipple w/2.813" sealbore 10.+/-150' above Kuparuk / 18545' I RA Tag (only 1 pip) in 10' x 3.5" pup at TKC4 8158' I 8718' I r¡rJi3\~;, I ' I ;~i:¡Ÿ,\~'~¡ 8803 MA 3-1/2",9.2 #/ft, L-BO,IBT Mod Comments Borealis WELL: L-114A API NO: 50-029-23032-01 Proposed Seal Bore Completion - \'VP3 BP Alaska Drilling & Wells Date: To: From: Subject: ) July 11, 2005 File Jane Williamson Borealis Well, L-114 ) BP is requesting approval plug-back of Borealis Well L-114 to allow for sidetrack within the same formation 1400 feet away from the current completion. The water cut in the well has increased to over 95%. Remaining reserves in the current wellbore are less than 100 MBBLs. The sidetrack should drain reserves from the existing well bore. The plug- back should be approved. 1CXXD am 1tXX)- &D 100 I I SJ 10 2001 FRlJI:HE ew, OCREAUS OL FB.LL FRlJI:HE B<\Y L-114 02 03 Dåe 02923032??oo: 130 - 01 R.... (CD) (bbl/d) . .. II Water R.... (CD) (bblld ) GG. Ro'" (CD) ( Wid) '....n'. n. Water Cut ,- I 04 05 , , ' Œl , " I' "!' , I ' 04 œ œ =E :ë .c ê Ræe 01 ~ 100~' Case NaTe Case1 .$ b ° (II ) O,:rx:fœAe. a::: Q 188.167l:ti1d ð ti Œ'Kf.Y'ð:ffJ te 04/'J:Y2f1J1 Erd Rote 100 I:tiId 10 -: RmI Rote W,7629l:ti1d Qm Atx:t. 1133. 01 M:tJ Qm Dte 04/'J:Y'ð:ffJ Ræaves 92.JJ5l M:tJ aR 1225.38 M:tJ Fae::ast ErŒd B¡ Rote Rre:ast Dte a:xJ1 ....¡...."....',.. æ 02 L-114 FRI...O-Œ B<\Y, B::R&LJS 0 L 1CXXXJ ) ., ,) ;11> Permit to Drill 2011360 DATA SUBMITTAL COMPLIANCE REPORT 101312003 Well Name/No. PRUDHOE BAY UN BORE L-114 Operator BP EXPLORATION (ALASKA) INC MD 8270 ~-~ 'I'VD 7155 '~ Completion Date 9/13/2001 ~- Completion Status 1-OIL Current Status 1-OIL APl No. 50-029-23032-00-00 UIC N REQUIRED INFORMATION Mud Log N._~o Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Ded/Frmt Electr Dataset Log Log Run Number Name Scale Media No ?.-?.:?.?:.'?.:?-?.-?.:!:.?::.'?:':.??: Directional Survey FINAL :::::::::::/:::::::::::::::::::::::::::::::::;::::::::;:::::::::??::::::::::::::::::::::;:::::::::::::;::::::::::::::::::: 'I-VD Resistivity 2/5 FINAL ................................................... iiii~:?iii!:.i~;ii:~iii?i;~?~;!::i.~!i!i;i?~i~:.::~:;:.~::i;i~;~:~;~;!!:~:!?i;:?~ii~!i:;. Combinable Magnetic 2 FINAL Resonance 1~39 MD Resistivity 2/5 FINAL TVD Density Neutron 2/5 FINAL BHCS 1 Caliper 2/5 FINAL MD Density Neutron 2/5 FINAL ........ CMR Processed Log 5 FINAL -1~39 FINAL ,Rpt Directional Survey FINAL 10398 Magnetic Resonance 1 - . . Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint) OH / CH Received Comments Interval Start Stop Interval Name Start Stop Sent Received 100 4250 100 100 2604 2400 2604 43OO 100 2368 Open 8/20/2001 Directional Survey Digital Data 8217 Open 9/27/2001 100-8217 BL, Sepia 5690 Case 10/26/2001 4250-5690 BL, Sepia 8270 Open 9/28/2001 100-8270 8217 Open 9/28/2001 100-8217 BL, Sepia 8217 Open 9/28/2001 2604-8217 BL, Sepia 5780 Case 10/26/2001 2400-5780 BL, Sepia 8217 Open 9/28/2001 2604-8217 BL, Sepia 4762 Case 9/14/2001 4300-4762 Color Print 8270 Open 9/28/2001 100-8270 digital data Open 8/20/2001 Directional Survey 7850 Open Sample Set Number Comments Permit to Drill 2011360 DATA SUBMITTAL COMPLIANCE REPORT ~01312003 Well Name/No. PRUDHOE BAY UN BORE L-t14 Operator BP EXPLORATION (ALASKA) INC MD 8270 'I'VD 7155 Completion Date 9/13/2001 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION (A,~__ (~)/N Well Cored? ~_,~N ~.'~ {J'J~-~ ~ Daily History Received? Chips Received? ~ Formation Tops ~ N Analysis Y / N Received? APl No. 50-029-23032-00-00 UIC N Compliance Reviewed By: Quarterly flowline inspection reports ( G aC)/-/3(¡~ ~ Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom - maunder@admin.state.ak.us, bob _fleckenstein@admin.state.ak.us CC: "n161?" <n1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 10-102: PTO 2000750, Sundry #302-101 1 D-105A: PTO 2012020, Sundry #302-294 10-110A: PTO 2000390, Sundry #302-227 10-121: PTO 1971810, Sundry #302-304 1D-127: PTO 1981090, Sundry #353-057 10-129: PTO 1972130, Sundry #303-092 10-140: PTO 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 10-102 Insp Log.xls)(See attached file: 10-105 Inspection Log.xls)(See attached file: 10-110 Insp Log.xls)(See attached file: 10-121 Inspection Log.xls)(See attached file: 10-127 Inspection Log.xls)(See attached file: 10-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) f..r,."------""""'\"""''''''''^'''-''''''''^_~---~H'''''''''''__'_'''''''''''''w.w.\"WHI'''''MYNmNNH'o\''w.w.w.w.WM'^'''''~WNNNNI"""""'''''''''\Mw,_Mw.w_'--WI"\W/olH,W.'''''''','''M\_'''''^''Wffl<I'W'=\_NM'I''''''^'MW,W.'''',",'W""'M~,w.wmHM"""M""w""'¡^'M""""'_""""\'--w"""'^',,,w."",-^-"'M"""""IN'''''M\"M\'11ffl.I1ffl,W¡'M'I,\","""'MWNWo'NNJ,'¡'¡.',''''''''''''''IYMY.., Name: 3H-05 Quarterly Inspection Log.xls, / ~3H-05 Quarterlv Inspection Loo.xls Type: EXCEL File (application/msexcel) : '.. . . Encoding: base64 . .' l~'ì-O\~ j Name: 10-102 Insp Log.xls . ~ 1 0-102 Insp Loo.xls Type: EXCEL File (application/msexcel) Encoding: base64 dÖO-CJ~S: J ~ 'Name: 10-105 Inspection Log.xls : ~ 1 0-1 05 Inspection Loo.xls! Type: EXCEL File (application/msexcel)¡ -d 0 \ - ~()~ , Encoding: base64 : ( þ.. ,Name: 10-110 Insp Log.xls . . ~10-110 Insp Loo.xlsi Type: EXCEL File (application/msexcel). , ¡ Encoding: base64 . J{)O - a~ C) J. Name: 10-121 Inspection Log.xls : . ~ 1 0-121 Inspection Loo.xls i Type: EXCEL File (application/msexcel)i , ; Encoding: base64 I ) Name: 11};:127 Inspection Log.xls ~ 1 0-127 Inspection Loo.xls i Type: EXCEL File (application/msexcel)i Encoding: base64 \~'\-\15\ \~<6--l0" 1 of 2 ~)t;A~NED' DEC Ü4: 2003 10/6/20033:17 PI \..lUärteny TlOWllne inspection reports . (") J Name: 10-129 Inspection Log.xls ~ 1 0-129 Inspection LaQ.xls Type: EXCEL File (application/msexcel) Encoding: base64 , I Name: 10-140 Inspection Log.xls I ~ 1 0-140 Inspection LOQ.xls I Type: EXCEL File (application/msexcel) Encoding: base64 2of2 (~ \~l-;}.\S dDb-~ S b 10/6/2003 3:17 p~ ( f 1 D-140 Special Inspection Request Log DS1D 1D-140 - 2 in. Annulus flowback inspection - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of #of Worst Damage Inspection B, I, N Case Wall Comments Inspection Locations Loss % Grade 01/06/03 6 B 0% A Base Line Inspection 01/09/03 6 N 0% A 1 - Day Follow-up Inspection 01/16/03 6 N 0% A 1-Week recur inspection 1-Week recur inspection No RT inspection performed locations are 01/23/03 2 N 0% A buried under snow bank 01/29/03 6 N 0% A 1-Week recur inspection 03/02/03 6 N 0% A Monthly Inspection Interval 04/01/02 6 N 0% A Monthly Inspection Interval 05/02/03 6 N ()Ofn ^ ./1(.)trrIJ Monthly Inspection Interval -~ 07/27/03 6 (f\J -----------n-% A-- --- Ið"v- -.. Quarterly Inspection Interval - -- l V( (,0 ~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~,,..sSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: .0~09/02, Put on Line 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-136 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23032-00 4. Location of well at surface ..... _~.,i'.:...j:?:'~.,--';' J ~'~'~' 9. Unit or Lease Name 2346' NSL, 3845' WEL, SEC. 34, T12N, R11E, UM !, ¥~.~I~D [ Prudhoe Bay Unit At top of productive interval 3513' NSL, 1625' WEL, SEC. 33, T12N, R11E, : .,, . ~ , Su 10. Well Number 3551' NSL, 1740' WEE, SEC. 33, T12N, R11E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Borealis Pool KBE = 76.30' ADL 028239 (Undefined) 12. Date Spudded 8/4/2001 110' Date T'D' Reached 114' Date C°mp" SNap" °r Aband'o/11/2001 9/13/2001 I15' water depth' if °ffsh°re N/A MSL 116' N°' °f C°mpleti°ns One 17. Total Depth (MD+'FVD) 118. Plug Back Depth (MD+'FVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 8270 7155 FTI 8158 7045 FTI •Yes [] NoI (Nipple) 2193' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR, RES, NEU, DEN, CMR, BHC Sonic 23. CASING, LINER AND CEMENTING RECORD ' CASING ' SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 91.5# H-40 Surface ' 106' 30" 260 sx Arctic Set (Approx.) 2O" 7-5/8" 29.7# L-80 27' 2637' 9-7/8" 352 sx Articset Lite, 173 sx Class 'G' 5-1/2" 15.5# L-80 24' 7438' 6-3/4" 5-1/2" x 3-1/2" Cement Listed Below 3-1/2" 9.2# L'80 7438' 8253' 6-3/4" 239 SX LiteCrete 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 7442' None MD TVD MD TVD 7704' - 7750' 6603' - 6647' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7704' - 7750' ;rac'd: 191,937# 16/20 Carbolite behind pipe 2500' Freeze Protect with 80 Bbls of MeOH '27. ' PRoDuCTioN TEST .... Date First P~oduction Method of Operation (Flowing, gas lift, etc.) ..... November 6, 2001 Gas Lift Date of Test Hours Tested PRoDucTiON FOR OIL-BBL GA'~-McF WATER-BBL CHOKE Si'zs" ' I GAs-0'iL RATio' 11/7/2001 4 TEST PERIOD 4683 1883 0 176I 402 Flow"Tubing Casing Pressure CALCULATED OIL-DEL' GAS-MCF WATER-BBL OIL GRAVITY-APl (coRR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Attachment provided with original 10-407. RECEIVED . la,La 0~1 & Gas Cons. C0rr~m~ss~o~ Form 10-407 Rev. 07-01-80 JAN 2 3 2002 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Schrader Bluff M 4338' 3891' Schrader Bluff N 4723' 4145' Schrader Bluff O 4938' 4299' Colville Mudstone 5419' 4664' CMl 6595' 5589' HRZ 7263' 6186' Kalubik 7471' 6380' Kuparuk C 7703' 6602' LCU , Kuparuk B 7864' RECEIVED Kuparuk A 8014' 6904' Base Kuparuk / Top Uiluveach 8087' 6975' Alaska 0ii & Gas Cons. Commissior~ Anchorage 31. List of Attachments: Provided with 10-407 dated 10/23/01' Summary of Daily Drilling Reports, Sidewall Core Summary, Surveys, Summary Post-Rig Work, Leak-Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,~']~~.,,x/' ~ Title TechnicalAssistant Date L-114 201-136 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL STATE OF ALASKA .. ALASKA OIL AND GAS CONSERVATION COMMIUSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-136 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23032-00 4. Location of well at surface '.' .................. I LOC. A~. ' t 9. Unit or Lease Name 2346' NSL, 3845' WEL, SEC. 34, T12N, R11E, UM : ~-....v :'..-- ,.:~ ~ ¥~:~.,_J~Lt~, ~ Prudhoe Bay Unit At top of productive interval _' :C~(:'~is~r~'~~~--, .s., WEL, SEC. UM At total depth ~ ' ......... :~' ~ '~' "'- ~ -~,.2-.-~...~ 10. Well Number 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Borealis Pool KBE = 76.30' ADL 028239 (Undefined) 12. Date Spudded 8/4/2001 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'8/11/2001 9/13/2001 115' Water depth' if °ffsh°re N/A MSL 116' N°' of C°mpletions One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 8270 7155 FTI 8158 7045 FTI [] Yes [] NoI (Nipple) 2193' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR, RES, NEU, DEN, CMR, BHC Sonic 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE S~ZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 106' 30" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 27' 2637' 9-7/8" 352 sx Articset Lite, 173 sx Class 'G' 5-1/2" 15.5# L-80 24' 7438' 6-3/4" 5-1/2,, x 3-1/2" Cement Listed Below 3'1/2" 9.2# L-80 7438' 8253' 6-3/4" 239 SX LiteCrete 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 7442' None MD TVD MD TVD 7704'- 7750' 6603'- 6647' 26. ' ACiD,"FRAcTU'REi CEMENT SQUEEZE, ETC. '" DEPTH INTERVAL (MD) . AMOUNT & KIND OF MATERIAL USED 7704' - 7750' -'rac'd: 191,937# 16/20 Carbolite behind pipe , 2500' Freeze Protect with 80 Bbls of MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER'BBL OIL GRAVITY-APl (CORE) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit com[~ C E I V ED See Attachment. 0 © 4. 2.0 O1 Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Schrader Bluff M 4338' 3891' Schrader Bluff N 4723' 4145' Schrader Bluff O 4938' 4299' Colville Mudstone 5419' 4664' CMl 6595' 5589' HRZ 7263' 6186' Kalubik 7471' 6380' Kuparuk C 7703' 6602' LCU / Kuparuk B 7864' 6758' Kuparuk A 8014' 6904' Base Kuparuk / Top Miluveach 8087' 6975' 31. List of Attachments: Summary of Daily Drilling Reports, Sidewall Core Summary, Surveys, summary Post-Rig Work, Leak-Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble,,~~_,~ {~~_ Title TechnicalAssistant Date L-114 201-136 Prepared By Name/Nurnbec Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 L-114 Sidewall ~",res Shot 45 Cores, Recovered 45,? "0% Recovery Sample# Depth i Recovery Condition Lithology ~ .~omments 1 5381 1" Intact Sand 2 5376 1" Intact Clay ? 3 5366 1" Intact Clay Sulphur odor 4 5337 1" Intact Clay 5 5314 1/2" Intact Sand 6 5309 3/4" Intact Sand 7 5290 3/4" Intact Sand 8 5262 1" Intact Clay ? 9 5253 1" Intact Clay ? 10 5243 1" Crumbly Sand/filter Cake 11 5230 7/8" Intact Sand/filter Cake 12 5173 1 1/2" Intact Sand 13 5167 1 1/4" Intact Sand 14 5164 1 1/2" Intact Sand 15 5157 1 1/4" Intact Sand 16 5098 2 1/4" Intact Sand/Clay 17 5093 3/4" i lntact Sand/Clay 18 5062 1 1/4" Intact Sand/Clay 19 5042 1 1/2" Intact Sand/Clay 20 5037 1 1/2" Intact Sand/Clay 21 4986 3/4" Intact Clay 22 4980 1 1/4" Intact Sand 23 4968 1 5/8" Intact Clay 24 4959 5/8" Intact Sand 1 4951 1 1/2" Intact Sand/Clay 2 4941 1 1/2" Intact Sand/Clay 3 4818 1 1/2" Intact Sand/Clay 4 4805 1 1/2" Intact Sand Stron~ oil odor 5 4774 1 1/2" Intact Sand Bleedin~l blk oil 6 4766 1 1/2" Intact Sand 7 4761 1 1/2" Intact Sand 8 4726 1 1/2" Intact Sand/Clay 9 4712 1" Crumbly Sand Dark oil stain 10 4693 1 1/2" Intact Sand 11 4675 1 1/8" Mushy Sand 12 4623 1 5/8" Crumbly Sand Oil odor 13 4615 1 1/2" Crumbly Sand Oil odor 14 4547 1 1/4" Crumbly Sand Darkoil stain 15 4523 1 1/4" Crumbly Sand I Dark oil stain 16 4505 1 1/4" Crumbly Sand IDarkoil stain 17 4454 1 1/2" Intact Sand/Clay 18 4428 1 1/4" Intact Sand ~Dark oil stain 19 4403 1 1/2" Crumbly Sand 20 2881 1 1/2" Intact Clay 21 2853 3/4" V crumbly Sand/Pebbles i Black heavy oil BP Exploration (Alaska), Inc. L-114 Prudhoe Bay Alaska FORMATION: DRLG FLUID: Water Base LOCATION: CORES :Schlumberger FILE NO. DATE APl ANALYST : HOU- 010764 · September 10, 2001 : : RL, RC, LA PRELIMINARY SIDEWALL CORE ANALYSIS DA TA 400 psi.q NCS SMPL DEPTH Kair POR No. (Feet) (mD) (%) GRAIN DEN (g/cc) Retort Sample Extraction K/Phi Sco Stw GAS ° APl ° APl Viscosity sq rt (%) (%) DET (cp) LITHOLOGY FLU 1 2853.00 Failed sample 2 2881.00 1040 28.8 3 4403.00 489 31.0 4 4428.00 1550 34.7 5 4454.00 119 31.1 6 4505.00 538 34.0 7 4523.00 1160 34.1 8 4547.00 Failed Sample 9 4615.00 196 32.5 10 4623.00 409 31.6 11 4675.00 Failed Sample 12 4693.00 118 30.2 13 4712.00 1350 31.2 14 4726.00 106 28.2 15 4761.00 317 30.2 16 4766.00 311 29.8 17 4774.00 596 31.2 18 4805.00 1180 30.2 19 4818.00 63.0 28.6 20 4941.00 191 30.1 21 4951.00 135 29.0 22 4959.00 69.6 29.7 23 4968.00 240 29.1 24 4980.00 17.7 28.5 25 4986.00 135 29.4 26 5037.00 98.5 30.2 27 5042.00 47.7 28.4 28 5062.00 54.4 27.8 29 5093.00 56.0 26.5 30 5098.00 274 28.8 2.666 2.627 2.646 2.653 2.617 2.600 2.627 2.641 2.549 2.637 2.706 2.660 2.672 2.657 2.674 2.707 2.702 2.679 2.667 2.772 2.700 2.849 2.703 2.711 2.717 2.751 2.709 0 18 11.8 1339 60.1 8.9 82.5 0 * ** ** 39.7 23.9 72.6 0 18 12.7 696 66.9 27.9 66.9 0 18 11.3 1553 19.6 35.5 53.0 0 16 11.1 1574 39.8 22.0 71.7 0 17 13.0 538 58.3 31.1 57.7 2 20 13.0 715 I 21 13.1 763 24.6 18.8 68.5 39 19 13.4 511 36.0 32.9 62.1 7 20 13.3 510 0 19 14.2 367 19.8 10.2 80.0 27 14 13.5 468 65.7 6.8 75.5 0 18 13.9 461 19.4 8.9 60.8 94 23 ** 161 32.4 39.3 45.8 8 20 15.5 123 32.3 35.6 52.4 19 20 14.8 147 43.7 35.1 46.9 0 20 14.8 193 62.5 25.7 43.6 53 23 16.1 112 14.8 11.7 55.0 12 23 16.0 124 25.2 25.9 30.2 23 19 14.8 351 21.6 19.9 41.1 20 18 14.6 307 15.3 0.9 77.8 0 ** .... 28.7 19.5 54.2 4 18 14.6 370 7.9 10.0 69.6 3 * ** 339 21.4 2.1 40.8 0 * ** 245 18.1 5.5 79.0 0 ..... 13.0 6.3 80.7 0 * ** 229 14.0 2.3 79.1 1 * ** 174 14.5 1.4 76.8 4 23 ** 197 30.9 - 16 * ** 187 Sd f-vcg Sd vf-fg slty shy lam(1,2) Sd fg slty sshy Sd fg sslty sshy Sd vf-fg sslty shy Sd f-mg shy lam(l,3) Sd m-cg shy Sd f-cg sshy (Mudshot) Sd vf-fg slty sshy lam(2) Sd fg shy Sd m-cg cln (Mudshot) Sd vf-fg slty shy lam(2) Sd f-mg cln Sd fg slty Sd fg sslty sshy Sd vf-fg slty Sd fg shy Sd f-mg slty sshy lam(2) Sd vfg vslty Sd vfg slty Sd vfg slty Sd vfg vslty Sd vfg slty Sd vfg slty Sd vfg vslty shy Sd vfg slty Sd vf-fg slty Sd vfg slty shy lam (2) Sd vfg slty Sd vfg slty stk gld ev dl gld ev dl gld ev dl gld stk dl gld ev dl gld ev dl gld ev gld ev gld ev gld stk y Y fy ev dl gld ev dl gld ev dl gld f stk y fy fy fy no fy fy stk y dy Y stk f y Y Y Y BP Exploration (Alaska), Inc. L-114 Prudhoe Bay Alaska FORMATION: DRLG FLUID: Water Base LOCATION: CORES 'Schlumberger FILE NO. DATE APl ANALYST : HOU - 010764 : September 10, 2001 : : RL, RC, LA PRELIMINARY SIDEWALL CORE ANALYSIS DA TA 400 psi.q NCS GRAIN Retort Sample Extraction SMPL DEPTH Kair POR DEN K/Phi Sco Stw GAS oAPi ° APl Viscosity No. (Feet) (mD) (%) (g/cc) sq rt (%) (%) DET (cp) LITHOLOGY FLU 31 5157.00 151 27.7 2.721 23.3 - 31 23 ** 64 32 5164.00 48.2 29.0 2.669 12.9 - 34 * ** 92 33 5167.00 145 29.6 2.682 22.1 - - 3 26 ** 91 34 5173.00 113 26.1 2.694 20.8 - 1 ..... 35 5230.00 215 27.5 2.748 28.0 - 10 ..... 36 5243.00 Failed Sample 4 * ** 128 37 5253.00 327 27.8 2.731 34.3 - 11 23 ** 77 38 5262.00 567 28.8 2.703 44.3 - 10 24 ** 77 39 5290.00 107 26.8 2.581 20.0 - 34 * ** 72 40 5309.00 Failed Sample 0 26 .... 41 5314.00 1760 34.6 2.706 71.3 - 1 ..... 42 5337.00 2200 30.1 2.682 85.4 - 0 ..... 43 5366.00 1700 32.3 2.623 72.6 - 44 ..... 44 5376.00 1560 27.4 2.633 75.5 - - 10 ..... 45 5381.00 Failed Sample 44 22 ** 139 Sd vfg slty sshy Sd vf-fg vslty Sd vfg slty Sd vfg slty Sd vfg slty Sd vf-fg sslty (Mudshot) Sd vfg slty Sd vfg slty Sd vfg slty Sd vfg-silt shy Sd vfg vslty shy Sd vfg vslty shy lam(2,3) Sd vfg slty shy lam(2,3) Sd vfg slty shy lam(2) Sd vfg slty shy lam(2) Y fY spy fY dly f stk y fstk y ev y stk y no stk y stk y stk y stk y stk y Viscosity determined on oil extracted by methylene chloride and measured with a Core & Plate Viscometer @ 122 F. + Indicates short or irregular shaped sample * Indicates fractured sample ** Indicates insuffcient for analysis Note: No Dean-Stark analysis performed on samples 30 to 45 in an effort to provide more sample for the extraction method of analysis. Legal Name: L-114 Common Name: L-114 : ~TestDate ::~'~: i :: i Te~tTypei~ ? :~ :TeSt:DepthliTMD)~ : :Test Depth (~D): AMW :i: ii :SUrface Pressure Leak Off Pressure (BHP) EMW 8/6/2001 LOT 2,637.0 (ft) 2,598.0 (ft) 9.30 (ppg) 892 (psi) 2,147 (psi) 15.91 (ppg) 8/15/2001 LOT 3,800.0 (ft) 3,567.0 (ft) 10.40 (ppg) 301 (psi) 2,228 (psi) 12.02 (ppg) Printed: 8/21/2001 4:01:00PM BP EXPLORATION Page 1 of 5 Operations Summa Report Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: DRILL+COMPLETE Start: 8/3/2001 End: Contractor Name: NABORS Rig Release: :Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/2/2001 17:00 - 00:00 7.00 MOB P PRE Mobilize Nabors Rig 9 ES to move to L-114. 8/3/2001 00:00 - 06:00 6.00 MOB P PRE R/D on L-110. Nabors performing variety of tests & measurements on rig jacking, hydraulic systems and tires. Skid and spot Rig over L-114. Spot Pit module. Hook up power and liquid transfer lines. Begin taking on water. Conductor rigged up and line run. RIG ACCEPTED AT 06:00 HRS. 06:00 - 11:30 5.50 MOB P PRE Rig up top drive unit. Mix spud mud. Transfer 4" drill pipe to pipe shed. 11:30 - 12:00 0.50 MOB P PRE Pre spud meeting with Co Rep, tool pusher, Hunt's crew, & all service company personnel. 12:00 o 16:30 4.50 MOB P PRE Change out 16" drilling nipple to 20" nipple for riser on diverter stack. N/U riser & lines & con't R/U rig floor. R/U cellar for drilling operations. Con't to prepare spud mud. 16:30 - 18:30 2.00 MOB P PRE Pick up singles of 4" drill pipe & stand back same in derrick. 18:30 - 19:00 0.50 MOB IR PRE Pre spud meeting with Co Rep, tool pusher, Lunda's Crew, & all service company personnel. 19:00 - 23:00 4.00 MOB P PRE Con't pick up drill pipe singles & stand back in derrick. 35 stands of 4" drill pipe in derrick (3267'). Pick up & stand back HWDP w/ jars. 23:00 - 23:30 0.50. MOB P PRE Start picking up BHA # 1. Function test diverter. Accumulator test. Note - AOGCC Rep notified, Mr. Chuck Sheive, waived witness function test. 23:30 - 00:00 0.50 MOB P PRE Con't - picking up BHA # 1. 8/4/2001 00:00 - 01:30 1.50 MOB P PRE Con't P/U & M/U BHA # 1 & orient directional tools. 01:30 - 02:00 0.50 MOB P PRE Fill conductor & check rig circulating system (pumps, pits, & plumbing) for leaks - OK. 02:00 - 15:30 13.50 DRILL P SURF Directionaly drill 9 7/8" hole w/1.50 Deg MWD f/106' to 1747'. 'MWD = Power Pulse, GR, & DNI. (stg wt = 85 k up, 85 k dn& 85 k rot). ART = 8 Hrs AST= 2.5 Hrs. 550 GPM @ 2150 psi. 15:30 - 16:00 0.50 DRILL P SURF Pump weighted sweep & circulate hole clean. 16:00 - 17:30 1.50 DRILL P SURF POH f/bit # 2. No hole problems. 17:30 - 19:00 1.50 DRILL P SURF P/U bit # 2 & RIH. 19:00 - 19:30 0.50 DRILL SURF Wash & ream last 90' to bottom @ 1747'. No hard fill @ TD. 19:30 - 00:00 4.50 DRILL P SURF Directionaly drill 9 7/8" hole w/1.50 Deg MWD f/1747' to 2618'. MWD = Power Pulse, GR, & DNI. (stg wt = 92 k up, 85 k dn, 92 k rot ). ART = 2.0 Hrs AST = 1.0 Hrs. 600 GPM @ 2700 psi. 8/5/2001 00:00 - 00:30 0.50 DRILL SURF Directionaly drill 9 7/8" hole w/1.50 Deg MWD f/2618' to 2657'. MVVD = Power Pulse, GR, & DNI. (stg wt = 92 k up, 85 k dn, 92 k rot ). ART = 0.50 Hrs AST = 0.0 Hrs. 600 GPM @ 2700 psi. 00:30 - 03:00 2.50 DRILL SURF Circulate hole with weighted sweep. Spot casing running pill on bottom. Monitor well - static. 03:00 - 08:00 5.00 DRILL SURF POH. 15 k overpull @ 2170'. Wipe tight spot clean. Con't POH & L/D BHA # 1. (stg wt = 107 k up & 85 k dn on bottom). 08:00 - 10:00 2.00 DRILL SURF Make dummy run with 7 5/8" csg hanger - OK. PJU 7 5/8" casing running tools & equipment. 10:00 - 15:00 5.00 DRILL SURF PJSM. Run 63 jts 7 5/8", 29.7#, L-80, BTC csg w/float shoe, float collar, & TAM collar to 2637'. 15:00 - 17:30 2.50 DRILL SURF R/D & L/D Franks tool. P/U & M/U cement head. Break circulation slowly. Circulate & condition hole @ 260 GPm @ 300 psi. Reciproate casing (stg wt = 112 k up & 90 k DN). 17:30 - 20:30 3.00 DRILL SURF PJSM. R/U Schlumberger equipment to cement 7 5/8" surface casing. Pump 10 Bbls CW 100 & pressure test pumps & lines Printed: 8/21/2001 4:00:44 PM BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2_001 Event Name: DRILL+COMPLETE Start: 8/3/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/5/2001 17:30 - 20:30 3.00 DRILL SURF to 4000 psi - OK. Repair cement head O ring. Con't - pump 40 Bbl Cw 100, Drop Bottom Plug,75 Bbl Mudpush XL @ 10.2 ppg., 75 Bbl Lead slurry (352 sx @ 10.7 ppg), 36 Bbl tail slurry (172 sx @ 15.8 ppg). Drop top plug & displace 7 5~8" csg with 108 Bis mud with rig pump. Bumped plug to 2050 psi. Plug down & cement in place @ 2030 Hrs. Full circulation during cement job - No Loses 45 Bbls, 10.7 ppg, good cement to surface. 20:30 - 22:30 2.00 DRILL SURF Bleed pressure from casing & check floats - OK. PJD & flush out cement equipment. Break out landing joint & PJD casing equipment. 22:30 - 00:00 1.50 BOPSUI~ SURF Break out valves in cellar & flush diverter system. N/D riser & RID diverter system. 8/6/2001 00:00 - 01:30 1.50 BOPSUI; SURF Complete N/D Diverter, Riser & Lines.. 01:30 - 06:00 4.50 BOPSUIq PROD1 N/U Base flange, Tubing Spool, DSA and 13 5/8" BOP. ( Test Csg head Seal to 1000 psi ) 06:00 - 10:00 4.00 BOPSUIq PROD1 Test BOPE to 4000 psi. Annular to 3500 psi. - APl. Witness of test waived by Chuck Sheve, AOGCC. 10:00 - 14:00 4.00 DRILL PROD1 P/U and stand back 4" DP to TD Hole. 14:00 - 16:30 2.50 DRILL PROD1 P/U & M/U & RIH w/6 3/4" BHA 16:30 - 17:00 0.50 DRILL PROD1 RIH past Tam port collar (980') to 1026' 17:00 - 17:30 0.50 DRILL PROD1 Shallow test MWD and put 1500 psi on casing to check Port Collar integrity- OK 17:30 - 18:30 1.00 DRILL PROD1 RIH to 2426' 18:30 - 19:30 1.00 DRILL PROD1 Break Circulation. Pressur Test Casing to 4000 psi for 30 minutes. OK. Reservoir meeting with Lunda's crew while testing. 19:30 - 23:00 3.50 DRILL PROD1 PJSM. Change out Drilling Line. 23:00 - 00:00 1.00 DRILL PROD1 Wash down to plugs on top of float collar at 2551'. 8/7/2001 00:00 - 02:00 2.00 DRILL PROD1 Drill out float collar, shoe track, rat hole, 20 ft new hole to 2677 ff. 02:00 - 02:30 0.50 DRILL PROD1 Displace well with 9.3 ppg Isnd mud system. 02:30 - 03:00 0.50 DRILL PROD1 Flow check, perform LOT, 892 psi / 15.9 EMW, at 2598 tvd. 03:00 - 03:30 0.50 DRILL PROD1 Reservoir meeting with all essential personnel. 03:30 - 00:00 20.50 DRILL PROD1 Flow check, drill ahead drctnl, 6 3/4 hole, 1.15 deg motor, MWD / LWD. 2677 - 4168 ft. Up 105, Dn 88, Rot 95 280 GPM @ 1650 psi ART = 3.75 hrs, AST = 11.25 hrs 8/8/2001 00:00 - 00:30 0.50 DRILL PROD1 Cont drill ahead 6 3/4 hole 4168 - 4197 ft. 280GPM @ 1650 psi P/U = 105K S/O = 92K ROT = 92 K WOB = 2 - 12K RPM = 50 Torque + 4 to 5K 00:30 - 01:30 1.00 DRILL PROD1 Flow check, pump hi vis sweep, follow with wt pill. 01:30 - 03:00 1.50 DRILL PROD1 Poh wiper trip to csg shoe 2600 ft. Slight swabbing, work pipe, recip string, regain normal displacement. No packoff, hole free. 03:00 - 03:30 0.50 DRILL PROD1 Service top drive, crown. 03:30 - 04:30 1.00 DRILL PROD1 Rih wiper trip, work tight hole 3450 - 3500 ft. Precautionary wash 90 ft to btm. No fill. 04:30 - 00:00 19.50 DRILL PROD1 Flow check, resume drill ahead drctnl, 6 3/4 hole 4197 - 5849 ff. Up 130, Dn 100, Rot 115 280 GPM @ 2200 psi. Tq. + 4 to 5K Art = 13 hrs, Ast= 2.6 hrs 8/9/2001 00:00 - 00:30 0.50 DRILL PROD1 Cont drill ahead 6 3/4 hole 5849 - 5879 ft. Printed: 8/21/2001 4:00:44 PM BP EXPLORATION Page 3 of 5 Operations Summar Report Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 81412001 Event Name: DRILL+COMPLETE Start: 81312001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 81912001 00:00 - 00:30 0.50 DRILL PROD1 No abnormalties. ART = 3.5 hfs, AST = 2 hrs Up 131, Dn 100, Rot 119 Press 2200, Rpm 50, Wob 2-12, Gpm 280 00:30 - 01:00 0.50 DRILL PROD1 Circ btms up, hi-vis sweep, shaker clean. 01:00 - 03:30 2.50 DRILL PROD1 Flow check, commence poh wiper trip, new hole, to 4200 ft. Pump / back ream various intervals, 25 K overpull. Cont pull into old hole to 3545 ft. Old hole free of obstruction. 03:30 - 04:30 1.00 DRILL PROD1 Flow check, rib, no hole problems. 04:30 - 05:00 0.50 DRILL PROD1 Precautionary wash 90 ft to btm, no fill. 05:00 - 00:00 19.00 DRILL PROD1 Cont drill ahead 6 3/4 hole 5879 - 6863 ft. No abnormalties. ART 6 hfs, AST 4 hfs Up 131, Dn 100, Rot 119 Press 2200, Rpm 50, Wob 2-12, Gpm 280, Tq 4 - 6 8/10/2001 00:00 - 04:00 4.00 DRILL PROD1 Directional drill 6 ~34" hole from 6863 to 7014. Weight up mud to 10.6 ppg while drilling. P/U = 160K S/O = 112K ROT = 128K 300 GPM @ 2380 psi. Tq. = 5 to 6K 04:00 - 05:00 1.00 DRILL PROD1 CBU - Hole clean. 05:00 - 06:30 1.50 DRILL PROD1 Wipe Hole to 5693'. Pulled 20K over @ 6020', wiped through twice - no problem. No drag RIH. 06:30 - 00:00 17.50 DRILL PROD1 Directional Drill 6 3/4" Hole from 7014' to 7653'. P/U = 168K S/O = 118K ROT = 135K. 290 GPM @ 2420 psi Tq. = 4 to 6K 40 to 70 RPM ART = 14.4 Hrs. AST = 2.5 Hrs. 8/11/2001 00:00 - 23:00 23.00 DRILL PROD1 Cont drill ahead 6 3/4 hole 7653 to 8270 ft td. 150 ft below Miluveach as per Co Geologist. Up 180, Dn 120, Rot 142 Rop = 25 fph, Press 2550, Gpm 290, Wob 12, Rot 50, Tq 8450 23:00 - 00:00 1.00 DRILL PROD1 Flow check, Circ / cond mud while reicp pipe. 8/12/2001 00:00 - 00:30 0.50 DRILL PROD1 Cont circ / cond for wiper trip. 98 spm, 2350 psi, 290 gpm. 00:30 - 04:00 3.50 DRILL PROD1 Flow check, survey, pump wt pill. 04:00 - 06:00 2.00 DRILL PROD1 Flow check, poh for hole opener. Tight intervals 7745 - 3291 ft. Flow check at shoe. Resume poh to bha. 06:00 - 09:30 3.50 DRILL PROD1 Flow check, handle / lay dn bha, all related drctnl equip. 09:30 - 13:00 3.50 DRILL PROD1 Commence test bope as follows: Annular 250 / 3500 psi - 10 min Pipe / blinds 250 / 4000 psi - 10 min Kill line / choke lines / choke manifold 250 / 4000 psi 10 min. Standpipe / top drive to pumps - 250 / 4000 psi 1 min Floor safety valves 250/4000 psi- 10 min Accumulator test / BP specs. Al tests successful, no retest. Witness test waived by Luke Grimaldi Pul test plug, re-install wear bushing. 13:00 - 14:00 1.00 DRILL PROD1 Change out lower valve / top drive. Test 250 / 4000 psi - 10 min. 14:00 - 15:00 1.00 DRILL PROD1 Make up 6 3/4 hole opening bha. Rih same. 15:00 - 18:30 3.50 DRILL PROD1 Flow check, follow bha with 4" dp to 8062 ft. Tight at 7415 ft. 18:30 - 20:00 1.50 DRILL PROD1 Make up top drive, ream 7415' to7505', precautionary wash / ream 8062 - 8270 ft. No fill. 20:00 - 00:00 4.00 DRILL PROD1 Flow check, prepare / poh for E logs. Hole good condition. 8/13/2001 00:00 - 01:30 1.50 DRILL PROD1 Cont poh, stand bk bha. 01:30 - 03:00 1.50 DRILL PROD1 PJSM, rig up Schlum, sheaving, all related E line equip. 03:00 - 22:00 19.00 DRILL PROD1 Commence E log well as follows: Rih run #1, CMR/BHC Sonic/GR. Can not pass 5800 ft. Printed: 8/21/2001 4:00:44 PM BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: DRILL+COMPLETE Start: 8/3/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/13/2001 03:00 - 22:00 19.00 DRILL PROD1 Log well 5800 - 4300 ft. Run #1. Run #2, ST Core Sample Taker, sidewall core 5381 - 2853 ft, ,/"' Total 45 core samples taken. All cores retrieved. No debris left in hole. 22:00 - 23:00 1.00 DRILL PROD1 Lay out all Schlum wireline equip, release unit. 23:00 - 00:00 1.00 DRILL PROD1 Flow check, make up 6 3/4 hole opener bha, rih same. 8/14/2001 00:00 - 01:30 1.50 CASE P PROD1 Rih, slip / cut drlg line at 7 5/8 shoe. 01:30 - 02:00 0.50 CASE P PROD1 Resume rib to 3030 ft. Note drlg line spooling improperly. 02:00 - 03:00 1.00 CASE N RREP PROD1 Flow check, poh for line spooling inspection. 03:00 - 09:00 6.00 CASE N RREP PROD1 Repair "crown saver"/line spooling problem. 09:00 - 14:00 5.00 CASE P PROD1 Flow check, rib to 8262 ft. precautionary wash / ream 8062 - 8270 ft. 8 ft soft fill. 14:00 - 16:30 2.50 CASE P PROD1 Recip pipe. High tq / packed off at 8206 ft. Work free, regain circ. Cont recip, circ hi vis, note 100% circ. Shaker clean. Pump wt pill. 16:30 - 00:00 7.50 CASE P PROD1 Flow check, poh laying dn 4" dp. 5 - 15K drag. No swabbing. Flow check at shoe, resume poh laying dn. 8/15/2001 00:00 - 00:30 0.50 CASE P PROD1 Cont lay dn bha, clear rig floor. 00:30 - 02:00 1.50 CASE P PROD1 Flow check, pull wear bshng, make dummy run csg hgr, record spaceout. Lay dn hgr / Idng jr. :02:00 - 15:00 13.00 CASE P PROD1 Flow check, commence run 5 1/2 X 3 1/2 csg as per program. Float check, fill all jts, circ at 7 5/8 shoe. Csg = 3 1/2, 9.2#, IBT, L80 5 1/2, 15.5#, BTC M, L80 115:00 - 16:30 1.50 CASE P PROD1 Circ with hgr landed. Can not recip csg. Note. 100% returns. Circ 5 bpm @ 1100 psi. 116:30 - 19:00 2.50 CASE P PROD1 Make up cmt hd, test lines, commence cmt csg as follows: Pump 10 bbl CW 100, test lines 4000 psi, pump addtnl 10 bbls CW 100. DRop btm plug, pump 40 bbls Mud Push XL 1 1.2 PPg. Pump 102 bbls 12 ppg Lite Crete slurry @ 5 bpm. Drop top plug, flush lines 10 bbls H2o. Displace with rig pumps 183 bbls sea water. 2629 strokes. Bump plug 2 bpm at 2100 psi and holding. Final circ press 1700 psi. 2 bpm. Plug bumped at 1900 hrs. 19:00 - 20:00 1.00 CASE P PROD1 Bleed press, floats holding, rig dn all related cmt equip. Release cmt unit. 20:00 - 22:30 2.50 CASE P PROD1 Install packoff/test to 4000 psi / 15 min. Will not hold press. Pull, re-run, re-test. Test successful. 22:30 - 00:00 1.50 RUNCOI~' COMP Flow test, PJSM, rig up and rih 3 1/2 comp string as per program. Comp assy = seal assy, GLMs, X nipples, 3 1/2, 9.2#, LB0, IBT 8/16/2001 00:00 - 04:00 4.00 RUNCOI~ COMP Cont rih 3 1/2 tbg to 2700 ft. Receive cmt compressive strengh test results. 04:00 - 05:00 1.00 RUNCOI~ COMP Perform LOT 5 1/2 X 7 5/8 annulus. Results = 12.65 EMW, 301 psi, 2577' TVD. 05:00 - 07:00 2.00 RUNCOI~ COMP Resume rih 3 1/2 tbg. while bullhead 67 bbls 10.4 mud dn 5 1/2 X 7 5/8 annulus. Inj rate = 127 gpm @ 770 psi Follow with 34 bs dead crude. Identical injection rate. 07:00 - 09:00 2.00 RUNCOI~' COMP Place Control line equip on floor, rig up same, test lines 5000 psi. 09:00 - 09:30 0.50 RUNCOI~ COMP Test csg to 4000 psi / 30 min. test good. Printed: 8/21/2001 4:00:44 PM BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: DRILL+COMPLETE Start: 8/3/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours ActivityCode NPT Phase Description of Operations 8/16/2001 09:30 - 13:30 4.00 RUNCOI~ COMP Resume rih 3 1/2 tbg. Slow going with control lines. 13:30 - 16:00 2.50 RUNCOI~!3 COMP Circ 20 spm while stab into PBR. Note 200 psi press increase. Stop pump and bleed. Note 10.5 ft seal stab in. Space out, record measurements, make up pups / tbg hgr. 16:00 - 17:00 1.00 RUNCOr~I~ COMP Attach control lines, test to 5000 psi. 17:00 - 19:30 2.50 RUNCOi~!3 COMP Take up / dn wts, Up 100, Dn 90. Reverse circ btms up, displace annulus with inhibited seawater. 19:30 - 21:00 1.50 RUNCOI~ COMP Land tbg, lock down hgr. Test tbg to 4000 psi/30 min. Bleed tbg to 2000 psi. Test 3 1/2 X 5 1/2 annulus to 4000 psi / 30 min. Bleed tbg slowly, RP shears at 2700 differential. 21:00 - 22:30 1.50 RUNCOI~' COMP Install TWC, test below check to 2800 psi. Bleed all pressures. All tests successful. No re-rest. 18/1 22:30 - 00:00 1.50 RUNCOI~ COMP Prepare and nipple dn bope. Set back bop. 7/2001 00:00 - 02:00 2.00 WHSUR P COMP Connect control lines, test to 5000 psi / 15 min. Lay out test equip. 02:00 - 04:00 2.00 WHSUR P COMP Install prod tree, test 250 / 5000 / 15 min. Test successful. No re-tests. 04:00 - 05:30 1.50 WHSUR P COMP Pull TWC, rig up for freeze protect. 05:30 - 08:00 2.50 WHSUR P COMP Test lines, PJSM, commence pump dn 5 1/2 X 3 1/2 annulus, 36.8 bbls diesel. Plugged RP valve. Cease operation. Job incomplete. Rig dn hot oil unit and release. Notify prod office. 08:00 - 09:00 1.00 WHSUR P COMP Install BPV, secure well, release rig. Release Nabors rig 9-ES, this date, 0900 hrs. Printed: 8/21/2001 4:00:44 PM Well: L-114 Rig Accept: 08/03/01 Field: Prudhoe Bay Field / Borealis Pool Rig Spud: 08/04/01 APl: 50-029-23032-00 Rig Release: 08/17/01 Permit: 201-136 Drilling Ri(]: Nabors 9ES POST- RIG WORK 08/18/01 RP shear valve plugged up during Drilling's freeze protect operation. Pulled dummy SSSV at 2193' and RP shear valve from station #4. 08/19/01 Reset 3-1/2" dummy SSSV in nipple at 2193'. 08/20/01 Freeze protect tubing and IA with 30 bbls of diesel. 08/27/01 Pulled dummy SSSV at 2193'. 08/28/01 Tag TD with 2.5" dummy gun at 8138' sim, set bottom latch dummy gas lift valve in GLM #4. Test IA to 3500 psi for 30 minutes. Good test. 09/13/01 Completed jewelry log and initial perfs. Shot 46' interval (7704' - 7750') with 2-1/2" Powerflow HMX at 6 spf, 60 degrees phased guns. Made two gun runs. 09/16/01 Static survey with Petradat. This static will be reran. 09/17/01 Run in hole with tandem Petradat gauges. 09/18/01 Reran static survey with tandem Petradat gauges. Average pressure and temperature at 6600ss' = 3442 psi and 160°F. Set C-Sub. Pull dummy gas lift valve from station #1. Set SPMG in station #1 (bottom latch). MITIA to 3500#, good test. Pull C-Sub. Attempt to set frac sleeve. 09/19/01 Set frac sleeve at 2174' sim. Use short core and skirt to pull. Pump down CL lines to test, good test. 09/20/01 Pump 50 bbls YF130LG fluid data frac. Spotted fluid to perfs at 5bpm then increase to 25bpm. Formation broke at 5104 psi, ISIP = 1870 psi. Time to closure 12 minutes, fluid eft. = 72%, redesigned frac to 50 bbl Pad (5% pad) ramp sand from .5 ppa to 10 ppa. Flushed with 50 bbls 20# slick before NWB screen out, placed 191,937# 16/20 carbolite into formation. N2 pop-off went at 7800 psi. Left 4925# sand in well bore. Top of sand is approximately at 5750' MD. Left half of the treesaver cups in the hole. L-114, Post Drill Summary Page 2 09/26/01 Attempt to fish tree saver cup from tubing. Tag ice at 34' sim. 09/27/01 Make up 2.25" DJN, hit ice plug at 455', work down to 910' and broke free. Cleanout to top of frac sleeve at 2188'. Pull out of hole. Rig up slickline and pull frac sleeve. Run in hole and cleaned well bore. 09/28/01 Cleaned out to 8158' ctd using 2% KCL slickwater and Biozan. Leave diesel in well bore. 10/01/01 Drift tubing with centralizer and sample bailer to 166'. Work through to 222' and then worked down to 229', very sticky. Got stuck, pulled out of hole with sample of hydrates. Attempted to melt ice plug with approximately 1.5 bbls of Methanol and 2000 psi without success. Left 2000 psi of pressure on well with Methanol on top of ice plug. 10/08101 Move in and rig up. Tag hydrates at 250', jet through at 700', tag again at 1550' and jet through at 1800'. Continue jet as running in hole. Dry tag TD at 8120' ctd. Pull out of hole and freeze protect well with 80 bbls of Methanol to 2500'. ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Prudhoe Bay Well ..................... : L-114 API number ............... : 50-029-23032-00 Engineer ................. : Nutter COUNTY ........ : 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 Tally GL above permanent ....... : 47.80 ft KB above permanent ....... : N/A DF above permanent ....... : 76.30 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 290.43 degrees 12-Aug-2001 22:10:32 Page 1 of 4 Spud date ................ : 03-Aug-01 Last survey date ......... : 12-Aug-01 Total accepted surveys...: 90 MD of first survey ....... : 0.00 ft MD of last survey ........ : 8270.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 03-Aug-2001 Magnetic field strength..: 1148.98 HCNT Magnetic dec (+E/W-) ..... : 26.28 degrees Magnetic dip ............. : 80.74 degrees MWD survey Reference Criteria Reference G .............. : 1002 68 mGal Reference H .............. : 1148 98 HCNT Reference Dip ............ : 80 75 degrees Tolerance of G ........... : (+/-) 2 50 mGal Tolerance of H ........... : (+/-) 6 00 HCNT Tolerance of Dip ......... : (+/-) 0 45 degrees Corrections Magnetic dec (+E/W-) ..... : 26.29 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.29 degrees (Total az corr= magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_10] ANADRILL SCHLUMBERGER Survey Report 12-Aug-2001 22:10:32 Page 2 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 101.61 0.54 338.39 3 187.00 0.72 338.39 4 288.50 0.49 342.89 5 379.85 0.53 336.22 6 473.31 0.70 1.02 7 566.23 0.82 15.09 8 658.74 1.00 25.58 9 750.79 1.70 350.72 10 842.32 2.43 342.76 11 936.56 3.67 338.27 12 1030.18 5.23 338.98 13 1123.45 6.46 341.49 14 1217.69 7.36 336.55 15 1311.30 6.86 334.54 16 1404.38 6.96 315.31 17 1497.27 8.16 300.44 18 1591.02 10.18 294.57 19 1684.85 9.40 292.09 20 1778.61 10.40 288.00 21 1871.21 11.96 284.86 22 1963.32 14.78 281.99 23 2057.75 15.57 284.13 24 2150.89 16.75 284.36 25 2245.70 16.54 284.71 26 2338.78 16.67 284.83 27 2431.83 16.43 285.10 28 2524.54 16.26 285.02 29 2596.17 16.04 284.37 30 2740.48 18.30 286.74 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 0.00 0.00 0.00 0.00 0.00 101.61 101.61 0.32 0.45 -0.18 85.39 186.99 0.95 1.32 -0.52 101.50 288.49 1.64 2.33 -0.88 91.35 379.83 2.17 3.09 -1.17 93.46 473.29 2.66 4.05 -1.33 92.92 566.20 2.92 5.26 -1.15 92.51 658.70 2.90 6.63 -0.63 92.05 750.72 3.51 8.70 -0.50 91.53 842.19 5.37 11.89 -1.30 94.24 936.30 8.61 16.60 -3.01 93.62 1029.63 13.45 23.37 -5.65 93.27 1122.42 19.56 32.31 -8.84 94.24 1215.97 27.08 42.88 -12.92 93.61 1308.86 35.25 53.43 -17.71 93'.08 1401.28 44.36 62.46 92.89 1493.37 55.96 69.80 93.75 1585.92 70.77 76.62 93.83 1678.38 86.70 82.95 93.76 1770.74 102.81 88.44 92.60 1861.59 120.71 93.48 _. 92.11 1951.19 141.84 98.37 94.43 2042.33 166.35 103.97 93.14 2131.79 192.12 110.35 94.81 2222.62 219.13 117.17 93.08 2311.82 245.60 123.95 93~05 2401.02 271.99 130.79 92.71 2489.98 297.97 137.57 71.63 2558.78 317.79 142.63 144.31 2696.65 360.23 154.10 -24.07 -33.71 -46.98 -61.62 -76.77 -93.99 -114.71 -138.79 -163.91 -190.20 -215.92 -241.53 -266.72 -285.99 -327.01 DLS Srvy Tool (deg/ tool qual i00f) type type 0.00 0.00 0.00 TIP - 0.48 338.39 0.53 MWD - 1.42 338.39 0.21 MWD - 2.49 339.17 0.23 IFR MSA - -- 3.30 339.24 0.08 IFR MSA - 4.27 341.78 0.33 IFR MSA - 5.39 347.66 0.24 IFR MSA - 6.66 354.57 0.26 IFR MSA - 8.72 356.69 1.14 IFR MSA - 11.96 353.77 0.86 IFR MSA - 16.87 349.74 1.34 IFR MSA - 24.04 346.42 1.67 IFR MSA - 33.50 344.71 1.35 IFR MSA - 44.78 343.23 1.14 IFR MSA - 56.29 341.66 0.60 IFR MSA - 338.93 334.22 328.48 323.39 319.04 314.84 310.61 306.84 303.95 301.63 66 93 77 51 89 88 103 33 117 11 132 57 151 12 173 41 197.60 223.39 299.86 298.44 297.28 296.51 295.23 248.97 274.67 300.11 319.58 361.50 2.48 2.46 2.37 0.94 1.30 1.81 3.14 1.03 1.27 0.25 0.14 0.27 0.18 0.40 1.64 IFR MSA - IFR MSA - IFR MSA - -- IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - -- [(c)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2832.43 20.01 291.50 32 2929.81 23.83 291.11 33 3022.65 26.62 293.91 34 3115.75 28.12 291.86 35 3208.46 30.07 289.59 36 3301.14 33.00 291.09 37 3396.31 35.95 291.73 38 3490.87 39.42 293.13 39 3583.64 44.22 294.68 40 3677.62 48.62 296.61 41 3771.30 50.13 295.80 42 3865.08 50.83 293.93 43 3956.19 52.41 292.65 44 4051.66 54.97 290.85 45 4135.29 53.82 291.99 46 4232.98 53.61 289.54 47 4328.48 52.74 286.71 48 4421.67 50.36 288.05 49 4515.29 48.65 288.63 50 4608.19 47.58 291.33 51 4701.00 45.21 291.96 52 4794.52 44.62 293.66 53 4890.40 43.98 293.75 54 4983.40 42.70 296.00 55 5077.70 41.47 294.78 56 5170.58 40.64 294.06 57 5264.43 39.64 296.02 58 5357.86 39.10 295.66 59 5450.84 38.16 294.94 60 5544.28 37.42 294.55 12-Aug-2001 22:10:32 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) Page 3 of 4 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 91.95 2783.52 390.37 164.03 -355.47 391.49 97.38 2873.84 426.71 177.22 -389.34 427.78 92.84 2957.82 466.24 192.41 -425.86 467.31 93.10 3040.50 508.99 209.03 -465.29 510.09 92.71 3121.51 554.06 224.96 -507.46 555.08 92.68 95.17 94.56 92.77 93.98 3200.49 3278.94 3353.76 3422.88 3487.66 3548.65 3608.33 3664.90 3721.43 3770.12 3827.94 3885.18 3943.13 4003.92 4065.95 4129.96 4196.19 4264.81 4332.45 4402.43 4472.47 4544.22 4616.45 4689.08 4762.92 93.68 93.78 91.11 95.47 83.63 602.53 241.83 -552.89 656.38 261.50 -603.03 714.14 283.58 -656.44 775.86 308.67 -712.96 843.63 338.17 -774.30 914.37 369.56 -838.09 986.49 399.97 -903.72 1057.82 428.20 -969.32 1134.72 456.68 -1040.78 1202.70 481.51 -1104.07 1281.44 1357.81 1430.68 1501.82 1570.97 509.42 -1177.69 533.21 -1250.33 555.00 -1319.98 577.39 -1387.55 601.01 -1452.54 1638 1704 1770 1834 1897 .15 .12 .97 .60 .56 625.79 -1515.01 651.38 -1575.87 678.30 -1637.19 705.13 -1695.09 732.24 -1752.18 1958 2018 2077 2135 2192 .42 .72 .72 .55 .65 757.46 -1807.72 783.05 -1862.54 808.89 -1915.87 833.69 -1968.35 857.66 -2020.35 97.69 95.50 93.19 93.62 92.90 92.81 93.52 95.88 93.00 94.30 603.46 657.29 715.08 776.91 844 . 92 915.95 988.28 1059.69 1136.56 1204.50 1283.15 1359.28 1431.91 1502.89 1571.97 1639.16 1705.19 1772.14 1835.90 1899.03 1960.00 2020.45 2079.63 2137.63 2194.86 294.77 294.47 294.31 294.19 293.91 293.62 293.44 293.36 293.41 293.59 293.80 293.87 293.83 293.69 293.56 293.39 293.10 292.80 292.59 292.48 292.44 292.46 292.50 292.59 292.68 292.73 292.80 292.89 292.96 293.00 92.88 93.85 93.43 92.98 93.44 2.52 3.93 3.27 1.90 2.42 3.27 3.12 3.78 5.29 4.91 1.74 1.71 2.05 3.08 1.77 2.03 2.54 2.79 1.89 2.45 2.60 1.43 0.67 2.16 1.57 1.03 1.72 0.63 1.12 0.83 IFR MSA - IFR MSA - IFR MSA - -- IFR MSA - IFR MSA - IFR MSA - -- IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - -- IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - [(C)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report 12-Aug-2001 22:10:32 Page 4 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5637.37 39.71 292.97 62 5730.99 40.53 288.52 63 5822.21 40.66 288.83 64 5915.86 41.86 286.63 65 6009.09 40.59 286.70 66 6104.12 38.91 287.20 67 6196.73 37.23 286.77 68 6291.54 35.62 287.44 69 6384.02 35.56 284.29 70 6479.43 35.15 283.35 71 6572.19 32.61 284.09 72 6664.95 29.43 282.88 73 6759.37 26.49 283.44 74 6850.80 26.28 284.48 75 6942.69 25.95 284.87 76 7035.85 25.64 284.38 77 7128.20 25.31 284.61 78 7222.68 24.40 286.93 79 7316.64 22.50 287.01 80 7409.24 20.55 286.65 81 7503.48 18.76 286.18 82 7595.72 16.78 287.69 83 7688.95 15.03 288.03 84 7782.48 14.57 286.07 85 7877.39 13.78 285.01 86 7970.87 12.58 285.68 87 8064.10 11.59 288.66 88 8157.52 10.55 292.58 89 8213.60 9.77 297.37 Final Projected Survey: 90 8270.00 9.77 297.37 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 93.09 4835.71 2250.57 881.02 -2073.46 2252.88 93.62 4907.31 2310.87 902.36 -2129.86 2313.12 91.22 4976.58 2370.20 921.37 -2186.09 2372.32 93.65 5046.98 2431.88 940.16 -2244.91 2433.83 93.23 5117.10 2493.18 957.78 -2303.77 2494.93 95.03 92.61 94.81 92.48 95.41 92.76 92.76 94.42 91.43 91.89 93 . 16 92.35 94.48 93.96 92.60 94.24 92.24 93.23 93.53 94.91 93.48 93.23 93.42 56.08 56.40 5190.16 5263.06 5339.35 5414.56 5492.38 5569.38 5648.87 5732.25 5814.16 5896.67 5980.55 6063.92 6149.65 6235.84 6321.98 6410.73 6498.56 6588.22 6678.65 6770.67 6861.68 6952.85 7044.53 7099.73 7155.31 Srvy Tool tool qual type type 293.02 2.68 IFR MSA - 292.96 3.19 IFR MSA - 292.85 0.26 IFR MSA - 292.72 2.01 IFR MSA - -- 292.57 1.36 IFR MSA - 2553.83 975.49 -2361.89 2555.41 292.44 1.80 2610.84 992.17 -2416.50 2612.26 292.32 1.84 2667.03 1008.72 -2470.31 2668.32 292.21 1.75 2720.67 1023.43 -2522.07 2721.81 292.09 1.98 2775.51 1036.62 -2575.67 2776.45 291.92 0.71 2826.86 2874.30 2918.21 2958.58 2998.82 3039.16 3078.66 3118.24 3155.56 3189.46 3221.08, 3249.18 3274.70 3298.55 3321.70 1048.88 -2625.90 2827.63 1060.04 -2672.38 2874.94 1070.11 -2715.48 2918.73 1079.91 -2754.91 2959.01 1090.16 -2794.04 2999.18 1100.39 -2833.26 3039.45 1110.34 -2871.72 3078.90 1121.11 -2909.93 3118.43 1132.03 -2945.70 3155.73 1141.87 -2978.21 3189.61 1!50.83 -3008.62 3221.21 1159.01 -3035.55 3249.29 1166.84 -3059.87 3274.80 1173.85 -3082.70 3298.63 1180.08 -3105.09 3321.78 IFR MSA - IFR MSA - IFR MSA - IFR MSA - IFR MSA - 291.77 2.77 IFR MSA - 291.64 3.49 IFR MSA - 291.51 3.13 IFR MSA - 291.40 0.56 IFR MSA - 291.31 0.40 IFR MSA - 3342.93 3362.41 3380.34 3390.19 291.23 0.40 IFR MSA - 291.14 0.37 IFR MSA - 291.07 1.41 IFR MSA - 291.02 2.02 IFR MSA - -290.98 2.11 IFR MSA - 290.93 1.91 IFR MSA - 290.90 2.20 IFR MSA - 290.87 1.88 IFR MSA - 290.85 0.73 IFR MSA - 290.81 0.88 IFR MSA - 1185.72 -3125.65 3342.99 290.77 1.29 1191.46 -3144.30 3362.47 290.75 1.25 1197.74 -3161.09 3380.39 290.75 1.37 1201.90 -3170.05 3390.25 290.76 2.05 3399.76 290.78 0.00 3399.69 1206.30 -3178.55 IFR MSA - IFR MSA - IFR MSA - IFR MSA - Projected Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1475 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 9/25/2001 Field: Borealis Well Job # Log Description Date Color Sepia BL CD L-114 21376 LWD IMPULSE & ADN (PDC) 08111101 1 L-114 21376 VISION RESISTIVITY MD 08/11101 I 1 L-114 21376 VISION RESISTIVITY TVD 08/11/01 1 1 L-t14 21376 VISION DENSITY NEUTRON MD 08/11/01 1 1 L-114 21376 VISION DENSITY NEUTRON 1'VD 08/11/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED SEP 2 8 2001 Al~ia 0il & Gas Cons. Commission An~.orage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie 9/11/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57tl ATTN: Sherrie NO. 4430 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 400 Anchorage, AK 99504 Field: Borealis Well Job # Log Description Date Color Sepia BL CD L-114 ~,,~F)I- I,~o 24373 PROCESSED CMR (SCHRADER) 08/t3/01 L-446 ~"~O/" /~¢~ 24372 FRAC ADVISOR TVD ZONED OUTPUT 07/14/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED S£P 1 z12001 Alaska 0il & Gas Co~s. Comm~aon A~chora~e Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie bp Date: 08-20-2001 Transmittal Number:92209 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Lo[/Run Depth Bottom Depth Log Type L-110 07-28-2001 ANA I 0 9020.00 DIRECTIONAL SURVEY; L-I,,I~, 08-12-2001 ANA 1 3 8270.00 DIRECTIONAL SURVEY; Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn :. LiSa.Weepie (AOGCC)!.., Attn: Sandy Lemke (Phillips Alaska) Attn: Susan Nisbet (Exxon Mobil Production Co.) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Aug-Og-ZO01 1Z:$g From-NABORS 9ES +907'-659-4833 T-99Z Rig: Nabors 9ES I{ Field: Prudhoe Bay Location: X = 583,072.24' Y = 5.978,0~ Well: L-114 Company: BP Exploration (AiaskaI Inc. Location Elevation IMPulse 2 inch Realtim P.001/001 F-408 DEAL Version: tD6_1C_1O <TVD> VerticalScale: 2" per lOO' ........ _-.,.%,, ..~ MPULSE Gamma Ray, Real-Time (GR_ .................. INP_RT') , (,6API) ....... 156 ROP*5 (.~O__PS) Create, 03:33 r~ [ ARC5 Phase-Shift Resistivity 34-in. at 2 MHz, Real-Time (P34H ~ bo (F/HR) o, 0.2 ............. ("~'~ ~ ~'~ ...... 2~"~ .................. ~RiTl~i"('~l~';~ ...................... '. /............... ~:~'~Fi~-i:;;;;;:~'~i'~"i~;~i;;ii;ii~:':i gi;;:";~'~ ='ii,.,' ~;;F+i';;';"i~i~'~:'~P ....... '(GAPI) 150, ~7~ ~oHMM) . '-" ~ . .... ;.'..'...,.~. ~': ..:.:,'. :::.:. ~::: ::7~.::" ::.: ........... ~ '-" ~ ~- ~ ........ /~600 I lllJI I I I II1 TVD 2800 ~D 2900 TVD 3000 TVD II 31 O0 TVD IVU 3200 ~D 3300 TVD 3400 TVD 3500 TVD 3600 TVD 3700 TVD 3800 ~O 3900 TVD 4100 TVD 4200 4300 44OO TVD GR IMP FIT Of~c 4700 TVD 48O0 TVD 490O 5OOO TVD ALASKA OIL AND GAS CONSERVA~ION C0~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage Alaska 99519-6612 Re: PBU L-114 BP Exploration (Alaska), Inc. Permit No: 201-136 Sur Loc: 2346' NSL, 3844' WEL, Sec. 34, T12N, R11E, UM Btmhole Loc. 3616' NSL, 1857' WEL, Sec. 33, T12N, R11E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the permit to Drill application for PBU L-114. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~ t>'/~ day of July, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. PERMIT TO DRILL 20 AAC 25.005 Ia. Type of work [] Drill [] Redrill 1 lb. Type of well I-I Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Uultipl.e.Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 77' Prudhoe Bay Field / Borealis 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028239 4. Location of well at surface .~ ~' /~/__. 7. Unit or Property Name 11. Type Bond (See 20 A~,c 25.025) 2346' NSL, 3844' WEL, SEC.,3~, T12N, R11 E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3584' NSL, 1771' WEL, SEC. 33, T12N, R11 E, UM L-114 Number 2S100302630-277 At total depth 9. Approximate spud date 3616' NSL, 1857' WEL, SEC. 33, T12N, R11E, UM 07/29/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047449, 3421' MDI No Close Approach 2560 8300' MD / 7104' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 600' MD Maximum Hole Angle 45 o Maximum surface 2823 psig, At total depth (TVD) 6459'/3468 psig 18. Casing Program Specifications Setting Depth gi[~ TO~ Bot;gm Quantitv of Cement Hole Casino W~ioht Grade Co~Plirlo Length MP TVD MD TVD (in(;Igde stac~e data) 30". 20" 91.5# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arctic Set (Approx.) 9-7/8" 7-5/8" 29.7# L-80 BTC 2839' Surface Surface 2612' 2577' 281 sx Articset Lite, 168 sx Class 'G' 6-3/4" 5-1/2" 15.5# L-80 BTC-M 7493' Surface Surface 7493' 6316' 5-1/2,,x 3-1/2. cement Listed Below 6-3/4" 3-1/2" 9.2# L-80 I BT-M 807' 7493' 6316' 8300' 7104' 105 sx LiteCrete ..~ ,, 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 Length Size Cemented MD TVD Structural Conductor Surface Intermediate RECEIVED Production Liner JUL 0 3 Z001 Alaska Oil & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Nell Magee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564'4628 21. I hereby certify that the//)bregoing is true and correct to the best of my knowledge Signed Dan Stone~~,~(J/ //'~~~ ~);~.~ Title Senior Drilling Engineer Date "7-3--,~ i Pe';'~nit ~U~i~er' '"'":' .............. "'"='"'1' "~I~'I"'NU'~'i~e; '"'"'"'"'" "~" '"" '~"' "" ..... '=" '"" "" "' '"" """"' ""' "' "'"" ...... I"""" '" '~'~pj~'~i'.D~z~.i';',''' I 'S'ee ~:°v'er letter'" ..... " ~__~?-./.~ Js0-o-z-~- ~---~-?~::>~.;L-. , J. "7_'//_~..O~/ I for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log/'R"equire"d [] Yes [] No Hydrogen Sulfide Measures [] Yes I~ No Directional Survey Required [] Yes [] No Pressure forBOPE []2K []3K ~.4K []5K []10K []15K [] 3.5K psi for CTU Required Working Othor:ORIGIN~LSI~NEDBY by order of ~,~ Approved By D Taylor Seerr)o~mf Commissioner the commission Date -~ / Form 10-401 Rev. 12-01-85 ORI6tNAL . ,licate I Well Name: I L-1 14 Drill and Complete Plan Summary I Type of Well (service / producer /injector): I Producer Surface Location' As-Built Target Location: Top Kuparuk Bottom Hole Location: X = 583,072.24' Y = 5,978,066.52' 2346' FSL (2933' FNL), 3844' FEL (1434' FWL), Sec. 34, T12N, R11E X = 579,849.99' Y = 5,979,269.97' 3584' FSL (1694' FNL), 1771' FEL (3508' FWL), Sec. 33, T12N, R11E X = 579,763.07' Y = 5,979,301.26' 3616' FSL (1662' FNL), 1857' FEL (3421' FWL), Sec. 33, T12N, R11E I AFENumber: 15M4026 I Estimated Start Date: 1 7/29/2001 1~:1~300' I I TVD:I710~' I Ri~l: I Nabors9ES I Operating days to complete: 113.7 I BF/MS: 130' I RKB: 177.0' I Well Design (conventional, slimhole, etc.): I Microbore (Iongstring) I Objective: I Kuparuk Formation Mud Program: 9-7/8" Surface Hole (0-2612' · Fresh Water Surface Hole Mud Density Viscosity Yield Point APl FL PH (ppg) (seconds) (Ib/lOOftz) (mls/3Omin) Initial 8.5 - 8.6 300 50 - 70 15 - 20 8.5 - 9.5 below Permafrost 9.3 - 9.5 200-150 30 - 45 < 10 8.5 - 9.5 interval TD 9.6 max 150 25 - 35 < 10 8.5 - 9.5 6 3A,, Intermediate / Production Hole (2612' - 8300'): Fresh Water LSND Interval Density Tau o ~'P PV ' pH APl HTHP (ppg) Filtrate Filtrate Upper 9.1-9.5 4-7 20-25 8-14 8.5-9.5 4-6 Interval Top of 10.8 5-8 20-25 8-14 8.5-9.5 3-5 < 10 by HRZ HRZ L-114 Permit to Drill Page 1 Directional: Ver. Sperry WP-05 KOP: 600' Maximum Hole Angle: 45° at 3354' MD Close Approach Wells: All wells pass major risk criteria. Logging Program: Surface Intermediate/Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res/NEU / DEN Open Hole: CMR- MDT, Cuttings samples Cased Hole: USIT cement evaluation (contingency) Formation Markers: Formation Tops MDbkb TVDss SV5 1465 SV4 1610 Base Permafrost 1775 SV3 195O SV2 2120 SVl 2440 UG4A 2740 UG3 3095 UG1 357O Ma 3790 WS2 (N sands) 4050 Not hydrocarbon bearing WS1 (O sands) 4200 Not hydrocarbon bearing Obf Base 4575 CM2 (Colville) 4854 THRZ 6155 BHRZ (Kalubik) 6380 K-1 6417 TKUP 6459 Hydrocarbon Bearing 3468 psi, 10.3 ppg Kuparuk C 6484 LCU Kuparuk B Kuparuck A TMLV (Miluveach) 6850 TD Criteria 8300' 7104 150' below Miluveach top L-114 Permit to Drill Page 2 Casinq/'i'ubinq Proc ram: Hole Csg! Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 80/80 9-7/8" 7 5/8" 29.7# L-80 BTC 2839' GL 2612'/2577' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 7493' GL 7493'/6316' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 807' 7493'/6316' 8300'/7104' Tubing 3-1/2" 9.2# L-80 IBT-mod 7493' GL 7493'/6316' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casinc. Basis: Size 17-5/8" Surface Lead: Based on 1861' of annulus in the permafrost @ 175% excess and 201' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 550' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At ~2062' MD Lead 223 bbl / 1251ft~ / 281 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 cf/sk. Tail 35bbl/196 ftc/168 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 cf/sk. Casing Size~15'l/2"x3-1/2"L°ngstring Production I Basis: I Lead: Based on TOC 1000' above top of Kuparuk formation & 30% excess + 80' shoe. I Lead TOC: 6638' MD, 5552' TVDbkb Total Cement Volume: I Lead 145 bbls / 252 ftc/105 sks of Dowell LiteCrete at 12.0 I I ppg and 2.39 cf/sk. L-114 Permit to Drill Page 3 Well Control: Surface hole will be drilled with diverter. The intermediate 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 calculations below BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3468 psi @ 6459' TVDss- Kuparuk Sands 2823 psi @ surface (based on BHP and a full column of gas @ 0.10 psi/ft) · Planned BOP test pressure: 4000 psi (for future frac stimulation treatments) · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg Diesel A majority of the L-Pad development will have "kick tolerances" in the 25 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. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. L-114 Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in p/ace. 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. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. 4. Operations: MIRU Nabors 9ES. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2612' MD / 2577' TVD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sand. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 6-3/4" drilling assembly with MWD/GR/NEU/DENS/RES and RIH to float collar. Test the casing to 4000 psi for 30 minutes. _,.~.~-_~. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below shoe and perform Leak Off Test. 8. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for liner and POOH. 9. Run and cement the tapered production casing as required from TD to 1000' above the Kuparuk. Displace the casing with seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. 10. Test the casing to 4000 psi for 30 min. 11. Run the 3-1/2", 9.2#, L-80 gas lift completion assembly. Sting seal assembly into tieback receptacle and test to 4000 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 12. Install TWC and nipple down the BOPE. Nipple up and test the tree to 5000 psi. 13. Freeze protect the well to ~2200' and secure the well. 14. Rig down and move off. Estimated Spud Date: 7-29-2001 L-114 Permit to Drill Page 5 L-114 Well Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: Gas hydrates were observed in both NWE offset wells. These are expected to be encountered near the base of the Permafrost at 1850' and near the TD hole section as well. Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: · The production section will be drilled with a recommended mud weight of 10.8 ppg to ensure shale stability in the HRZ shale. Read the Shale Drilling Recommended Practice. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. FAULTS: The well trajectory is expected to intersect a fault at approximately 6020' TVD ss. The fault has an estimated throw of 60'. Consult Lost Circulation Decision Tree for recommended LCM treatments. KICK TOLERANCE: With 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.8 ppg at the surface casing shoe, 10.8 ppg mud in the hole, kick tolerance is 25 bbls. A majority of the L-Pad development will have "kick tolerances" in the 25 bbl range or less. 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. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent wells NEW 1-01 and NEW 1-02 did not report H2S as being present. 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 ! of 1 L-114 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies > L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. (Confirmed per J. Copen.) As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. > The closest wellhead locations are NWE1-01, NWE1-02 and L-10. All are greater then 75' from well L-114. No surface shut-in's will be required. Reference RPs Operational Specifics Job 2: Drillinq Surface Hole Hazards and Contingencies No faults are expected to be penetrated by L-114 in the surface interval. There are no close approach issues in the surface hole. All wells pass major risk criteria. Gas hydrates were observed bythe NWE1-01and NWE1-02 wells. These were encountered near the base of the Permafrost at 1795' and 1730' TVD. L-01 surface interval encountered hydrates from the base of permafrost to TD in the SV1 sand. Expect to encounter hydrates from the base of permafrost to the surface shoe setting depth. Hydrates will be treated at surface with appropriate mud products. Refer to Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) ~ No faults are mapped in the direction of the planned wellbore Reference RPs Operational Specifics L-114 Permit to Drill Page 6 Job 3: Install surface Casin,q Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at _+1000'MD to allow a secondary circulation as required. Reference RPs Operational Specifics Job 7: Drillinq Intermediate ! Production Hole Hazards and Contingencies KICK TOLERANCE: Assuming a 10.3 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.8 ppg at the surface casing shoe, 10.8 ppg mud in the hole, kick tolerance is 25 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Note: MDT data from L-01 indicates a formation pressure in the Kuparuk of 10.1 ppg EMW. Until further MDT's are conducted the kick tolerance will be based on the elevated formation pressure of 10.3 ppg EMW. ~ FAULTS: There well trajectory is expected to intersect a fault at approximately 6020' TVD ss. The fault has an estimated throw of 60'. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ There are no close approach issues with the production hole interval of L-114. Well L-110 is expected to pass within 67' at a depth of 872'. The actual close approach will have to be reviewed on completion of the L-110 well. Reference RPs Operational Specifics Job 8: Loq Production Hole Hazards and Contingencies ~ Ensure the hole is in very good condition to avoid a stuck tool string ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 5 Y2"x 3 Y2" Iongstring casing. Reference RPs Operational Specifics L-114 Permit to Drill Page 7 Job 3: Install surface Casinq Hazards and Contingencies :> It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at +IO00'MD to allow a secondary circulation as required. Reference RPs Operational Specifics Job 7: Drillinq Intermediate / Production Hole Hazards and Contingencies ;> KICK TOLERANCE: In the worst case scenario of 10.3 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.5 ppg at the surface casing shoe, 10.8 ppg mud in the hole, kick tolerance is 19 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 13.5 ppg. Note: MDT data from L-01 indicates a formation pressure in the Kuparuk of 10.1 ppg EMW. Until further MDT's are conducted the kick tolerance will be based on the elevated formation pressure of 10.3 ppg EMW. FAULTS: There well trajectory is expected to intersect a fault at approximately 6020' TVD ss. The fault has an estimated throw of 60'. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. There are no close approach issues with the production hole interval of L-114. Well L-110 is expected to pass within 67' at a depth of 872'. The actual close approach will have to be reviewed on completion of the L-110 well. Reference RPs Operational Specifics Job 8: Loq Production Hole Hazards and Contingencies > Ensure the hole is in very good condition to avoid a stuck tool string > If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 5 Y2"x 3 Y2" Iongstring casing. Reference RPs Operational Specifics L-114 Permit to Drill Page 7 Job 9: Case & Cement Production Hole Hazards and Contingencies ~. The 5-1/2" casing will be cemented to 1000' above the Kuparuk sand, the upper most hydrocarbon bearing zone. The top of the hydrocarbon interval should be verified with LWD resistivity log. Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting the 5 1/2" x 7-5/8" casing annulus with 33 bbls of dead crude. The hydrostatic pressure will be 10.0 ppg or .3 ppg less than the maximum anticipated pore pressure if the cement has not reached compressive strength. Ensure a minimum hydrostatic equivalent of 10.8 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. Reference RPs Operational Specifics Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics 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 Operational Specifics L-114 Permit to Drill Page 8 TREE: 3-1/8" - 5M CIW L-80 WELLHEAD: 11" - 5M FMC G5 Borealis L-114: Proposed Completion Cellar Elevation = 47' RKB - MSL = 77' 3-1/2" 'X' SCSSSV with 2.813"seal bore. I 2200' I 7-5/8", 29.7 #/fi, L-80, BTC 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. MD Size Valve Type TBD 1" DV TBD 1" DV TBD 1" DV TBD 1" DV 3-1/2" 9.2# IBT Mod L-80, Tubing 5-1/2", 15.5 #/fi, L-80, BTC-Mod 3-1/2" 'X' Landing Nipple with 2.813" seal bore, 1 joint above PBR 3-1/2" Seal Asembly 3-1/2" PBR 5-1/2"x3-1/2" XO placed above Kuparuk 7493'I Plug Back Depth 3-1/2", 9.2 #/ft, L-80,1BT Mod 3-1/2" 'X' Landing Nipple with 2.813" seal bore ID 3-1/2" 'X' Landing Nipple with 2.813" seal bore ID.+/- 150' above Kuparuk 7573'I Date Rev By 6-26-01 NM Comments Proposed Seal Bore Completion ~ WP5 Final Proposed Completion Borealis WELL: L-114 APl NO: 50-029-????? BP Alaska Drilling & Wells BP Amoco Anticollision Report Company: BP Amoco Date: 7/2/2001 Time: 11:54:29 Page: 1 Field: Prudhoe Bay Reference Site: PB L Pad Ce-ordinate(NE) Reference: Well: L-114, True North Reference Well: L-114 Vertical (TV])) Reference: L-114 76.3 Reference Wellpath: Plan L-114 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISGWSA Ellipse Depth Range: 28.50 to 8271.25 ft Scan Method: Tray Cylinder North Maximum Radius: 1000.00 ff Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 2/8/2001 Validated: No Version: 8 Planned From To Survey Toolcode Tool Name ft ft 77.00 500.00 Planned: Plan #5 V1 CB-GYRO-SS Camera based gyro single shots 500.00 8271.25 Planned: Plan #5 V1 MWD MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ff in in , 2612.15 2576.30 7.625 8.750 7 5/8" 8271.25 7075.50 5.500 6.750 5 1/2 Summary EX NWE#1 delete me NWE1-01/~IWE1-01A V4 374.25 375.00 181.78 7.62 174.17 EX NWE#1 NWE1-01 NWE1-01 V3 374.25 375.00 181.92 7.62 174.31 EX NWE#1 NWE1-01 NWE1-01A V0 374.25 375.00 181.92 7.62 174.31 EX NWE#1 NWE1-02 NWE1-02 V2 474.07 475.00 183.57 9.35 174.23 PB L Pad L-01 L-01 V12 748.41 750.00 193.96 13.33 180.63 PB L Pad L-110 Plan L-110 V5 Plan: PI 871.91 875.00 67.26 15.67 51.59 PB L Pad L-116 Plan L-116 V4 Plan: PI 1245.74 1250.00 104.92 25.62 79.31 Site: EX NWE#1 Well: delete me NWE1-01A Wellpath: NWE1-01A V4 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Rule Assigned: Major Risk Inter-Site Error: 0.00 ft .... tllOWable: : : 'i==!:=:':DiS~nce?=Area "=;i =:': Deviation : warning ';i:;:;.' ft ':, ;:fi::: ::, :', : 31.80 31.80 32.51 32.51 0.01 0.00 297.56 297.56 179.63 0.74 178.90 Pass 49.29 49.29 50.00 50.00 0.05 0.03 297.56 297.56 179.64 1.12 178.52 Pass 74.29 74.29 75.00 75.00 0.11 0.04 297.56 297.56 179.65 1.59 178.06 Pass 99.29 99.29 100.00 100.00 0.16 0.06 297.56 297.56 179.68 2.05 177.64 Pass 124.29 124,29 125.00 125.00 0.25 0.07 297.55 297.55 179.73 2.58 177.15 Pass 149.29 149,29 150.00 150.00 0.33 0.07 297.54 297.54 179.79 3.11 176.68 Pass 174.29 174.29 175.00 175.00 0.42 0.08 297.53 297.53 179.86 3.63 176.22 Pass 199.29 199.29 200.00 200.00 0.50 0.10 297.51 297.51 179.94 4.20 175.74 Pass 224.29 224.29 225.00 225.00 0.56 0.13 297.48 297.48 180.05 4.70 175.35 Pass 249.29 249.29 250.00 250.00 0.61 0.16 297.41 297.41 180.20 5.20 175.00 Pass 274.29 274.29 275.00 275.00 0.67 0.18 297.32 297.32 180.40 5.69 174.71 Pass 299.33 299.33 300.05 300.04 0.72 0.20 297.19 297.19 180,66 6.17 174.50 Pass 324.27 324.27 325.00 324.98 0.77 0.24 297.03 297.03 180.98 6.66 174.32 Pass 349.26 349.26 350.00 349.97 0.82 0.27 296.83 296.83 181.35 7.14 174.21 Pass 374.25 374.25 375.00 374.96 0.86 0.30 296.59 296.59 181.78 7.62 174.17 Pass 399.23 399.23 400.00 399.94 0.91 0.33 296.31 296.31 182.27 8.10 174.18 Pass 424.20 424.20 425.00 424.91 0.93 0.36 295.99 295.99 182.79 8.50 174.29 Pass 449.17 449.17 450.00 449.88 0.94 0.39 295.64 295.64 183.33 8.89 174.45 Pass 474.13 474.13 475.00 474.84 0.96 0.42 295.25 295.25 183.90 9.28 174.63 Pass 499.09 499.09 500.00 499.80 0.98 0.45 294.82 294.82 184.51 9.69 174.85 Pass 524.02 524.02 525.00 524.73 0.98 0.49 294.32 294.32 185.23 10.06 175.19 Pass 548.94 548.94 550.00 549.65 0,99 0.53 293.75 293.75 186.06 10.43 175.65 Pass 573.84 573.84 575.00 574.55 0.99 0.56 293.11 293.11 187.00 10.79 176.25 Pass 598.71 598.71 600.00 599.42 0.99 0.61 292.41 292.41 188.10 11.20 176.95 Pass I4 0 0 -40 -30 301 -20 0 270 f l 0 20 30 24( -40 --50 21 50 --60 64 18{ Trav~]lh'lg C v~i,,der ,{:~imuth (~'FO I ~Zf} [O~g] v~ (entre t~ ('¢nta'e S~Par~tJo~ From Co{our To MD 30 -- 300 300 -- 600 600 -- 900 900 -- 1200 1200 ~'~-- 1500 1500 -- 2000 2000 2500 2500 -- 3000 00 3500 -- 4500 -- 5500 ,0 9O 20 COMPANY DETAILS BP Amoco Calculation ~,{¢thock ]~{~linlnnCut'.'m'Ul~ Error Syste~: ISCWSA Scan Method: High Side + Paimum Error Surface: Elliptical + Casing Warning bielhod: Ruk~ 13a~ed REFEKENC E INFORIdATION Co-ordinate (N.~E) Ref¢i'~nc¢: Well Cenln:: Plan L-114 SW, Tree Norlh Vertical OX'D) Reference: Ternp Plan ek~afion 7777.0 Section tVS) Reference: Slot- S-C (0.00:0.00) Mea~uled Deplh Reference: Terrlp plan eletation 77 T'LO Calculation b.(elllod: Mil'fin~im Our,-alul~ ANNOTATIONS No. TVD MD Annotation 1 600.00 600.00 Start Dir 1°/100': 600' MD, 600'TVD 2 1099.371100.00Start Dir 1.5°/100': 1100' MD, 1099.37'TVD 3 1756.411763.91End Dir: 1763.91'MD, 1756.42'TVD 4 1950.001961.82Start Dir 3°/100': 1961.82' MD, 1950'TVD 5 2079.342095.15End Dir : 2095.15' MD, 2079.35' TVD 6 2600.002636.79Start Dir4°/100': 2636.79' MD, 2600'TVD 7 3213.003354.69End Dir: 3354.69' MD, 3213' TVD 8 5261.826237.90Start Dir 2°/100.: 6237.9' MD, 5261.82'TVD 9 7104.428300.54Total Depth: 8300.55' MD 7104.42' TVD 1500 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1542.001545.79SV5 2 1687.001693.07SV4 3 1852.001861.63Base Permafrost 4 2027.002040.91SV3 5 2197.002217.55SV2 6 2517.002550.45SV1 7 2817.002868.93UG4A 8 3202.003339.29UG3 9 3727.004078.02UG1 10 3967.004415.76WS2 (N Sands) ll 4257.004823.86WSI (O Sands) 12 4767.005541.56CM3 (Colville Shales) 13 6416.007598.69Kalubik 14 6536.007723.69TKUP 15 6561.007749.54Kupamk C 16 6955.008150.55TMLV (Miluveach) CASING DETAILS No.TVD MD Name Size I 2577.002612.867 5/8" 7.62 2 7104.428300.545 1/2" 5.50 ~ L ll4Fault 4000 ",_ :::::::::::::::::::::::::::::::::::::::::::::::::::::: (N S .""0 ............ ~",~WS I il ~ Sands) 5.ooo .. .............................................. ~ ........... ~--- · CMS~(Gol~it[e Shales) {-~0!I E':~. ~ : ...... ;-..:~..: ..................... ................ 7000 · b.-~d~ik 8000 ....... ................................................. 5 1/2" x 3 I/2" ........... SURVEY PROGRAM Depth Fm Depth To Sun-cyiPlan 77.00 500.00 Planned: SW L-114 ,agO5 VI 500.00 8300~5 Planned: SW L-114 'al:OS VI I'hn: SW L-114 ~T,05 (Plan I.-114 SW/Phn I,-114 SW) Tool ('teated By: AutNni~_'d IJ~r Dale: 2QI/2001 CB-bLAG-SS ( 'hocked: l)alc: Reviewed: Dale: -- -~nnrm'nl' WF. LL DEl'AILS Name *N'-S *E/-W Northing I~sling Laliludc I~,ngiludc Slot Plan L-1141b~.94 73.99 5978065.64 583O72.6'/ 70"21 ~O. 171N 149"Ig'H.97gW S-C ]'ARGE~- DI:'TAI LS Natm TVD -N'-S'Fd-W NorthinsI'X~lilt~ Shal~ L-114 Fault 3517.00 494.05 -867.33 5978M9.99 5a2200.m Point P_L_I0 6536.c~ 1240.10 -32(Y9.4~ 5979269.97 579~49.09 Polygon SECTION DETAILS Sec MD lnc Azi TVD NIS EIW DLeg TFace VSec T~get 1 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 2 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 3 1100.005.00 345.00 1099.37 21.06 -5.64 1.00 345.00 12.85 4 1763.9112.00 290.44 1756.42 73.24 -77.99 1.50 281.62 99.13 5 1961.8212.00 290.44 1950.00 87.61 -116.54 0.00 0.00 140.28 6 2095.1516.00 290.44 2079.35 98.87 -146.76 3.00 0.00 172.52 7 2636.7916.00 290.44 2600.00 151.01 -286.66 0.00 0.00 321.81 8 3354.6944.72 290.44 3213.00 276.38 -623.10 4.00 0.00 680.82 9 6237.9044.72 290.44 5261.82 984.70 -2524.02 0.00 0.00 2709.29 10 7723.6915.00 290.44 6536.00 1240.10 -3209.43 2.00 180.00 3440.68 P_L_I0 11 8150.556.46 290.44 6955.00 1267.83 -3283.84 2.00 180.00 3520.08 12 8300.553.46 290.44 7104.42 1272.36 -3296.00 2.00 180.00 3533.06 All TVD depths are ssTVD plus 77' for RKBE 3000 4500 6000 7500 9000 10500 12000 13500 Vertical Set'lion at 291.11 o [ 1500fffin] COMPANY DE~FAILS BP Am~¢o Cak-ulation Method: /~{~linlnn Cut~ul~ Etxor System: 1SC~,VSA Scan Method: High Skil: + Az~nu~h Enur Surface: Elliptkal + Cashg Warning M¢lhod: Rules Ba~d ANNOTATIONS No. TVD MD Annotation 1 600.00 600.00 Start Dir 1°/100': 600' MD, 600'TVD 2 1099.371100.00StartDirl.5°/100': I100'MD, 1099.37'TVD 3 1756.411763.91End Dir : 1763.91'MD, 1756.42'TVD 4 1950.001961.82Start Dir 3°/100': 1961.82' MD, 1950'TVD 5 2079.342095.15End Dir: 2095.15' MD, 2079.35' TVD 6 2600.002636.79Start Dir 4°/100': 2636.79' MD, 2600'TVD 7 3213.003354.69End Dir: 3354.69' MD, 3213' TVD 8 5261.826237.90Start Dir 2°/100.: 6237.9' MD, 5261.82'TVD 9 7104.428300.54Total Depth: 8300.55' MD, 7104.42' TVD -4000 REFERENCE INFORMATION Co-ordinate (N,E) Reference: Well Centn:: Plan L-114 SV~ Tree. Noah Vertical {~/D) Referenoe: 'letup Plan ele~ation 77 '/7.0 Section (VS} Rcfcrcnoe: Slot- S-C (0.00,0.00) b. lc~su/ed l)cplh Reference: Ten~ Plan ek~'ation 77 77.0 Cak~ulalion Method: Minhnlma CUl~Um: FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1542.001545.79SV5 2 1687.001693.07SV4 3 1852.001861.63Base Perma~ost 4 2027.002040.91SV3 5 2197.002217.55SV2 6 2517.002550.45SVI 7 2817.002868.93UG4A 8 3202.003339.29UG3 9 3727.004078.02UGI 10 3967.004415.76WS2 (N Sands) 11 4257.004823.86WSI (O Sands) 12 4767.005541.56CM3 (Colville Shales) 13 6416.007598.69Kalubik 14 6536.007723.69TKUP 15 6561.007749.54Kuparuk C 16 6955.008150.55TMLV(Miluveach) CASING DETAILS No. TVD MD Name S~e I 2577.00 2612.867 5/8" 7.62 2 7104.42 8300.545 1/2x 3 1/2" 5.50 SURVEY PROGRAM Depth Fm Depth To Survey/Plan 77.OO 50O.OO planned: SW L-114 ~p05 V 1 _¢~0.00 830~.55 plan~k SW L-114 ~p05 VI Plan: SW I.-I 14 V,T, O5 (l'lart L-114 SWq'l;m I.-114 Tool ('reared By: Autl~}riscd ll~..r IXdc: 2/21/2~1 C~bIA~ Checked: Dale: Reviewed: Date: .~nnrm'rd' N~ ~NcS +~-W ~i~ I~ing I.alit~I.ongit~ Slot Pl~ L-114~ 73.~9 5~5.~ 58~7Z67 7ff'21 ~.17IN 14~'1~31.978W TARGI~ DE-I'AII.S Name ]WD -N'-S - I'Y-W N,n~hing I ~.,lireg Shape P_L_I0 6536.00 1240.10 -~209.43 5979269.97 579~49.1~) SECTION DETAILS Sec MD Inc Azi TVD N/S E/W DLeg TFace VSec Target I 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 2 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 3 1100.005.00 345.00 1099.37 21.06 -5.64 1.00 345.00 12.85 4 1763.9112.00 290.44 1756.42 73.24 -77.99 1.50 281.62 99.13 5 1961.8212.00 290.44 1950.00 87.61 -116.54 0.00 0.00 140.28 6 2095.1516.00 290.44 2079.35 98.87 -146.76 3.00 0.00 172.52 7 2636.7916.00 290.44 2600.00 151.01 -286.66 0.00 0.00 321.81 8 3354.6944.72 290.44 3213.00 276.38 -623.10 4.00 0.00 680.82 9 6237.9044.72 290.44 5261.82 984.70 -2524.02 0.00 0.00 2709.29 10 7723.6915.00 290.44 6536.00 1240.10 -3209.43 2.00 180.00 3440.68P_L_I0 11 8150.556.46 290.44 6955.00 1267.83 -3283.84 2.00 180.00 3520.08 12 8300.553.46 290.44 7104.42 1272.36 -3296.00 2.00 180.00 3533.06 All TVD depths are ssTVD plus 77' for RKBE ! ! i : i ! 3000 i ~ i : 2000 , i ~ lO00 ......................................................................... -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 West(-)/East(+) [500fgin] BP Amoco Planning Report- Geographic Company: BPAmoco Date: 2/21/2001 Time: 15:45:11 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-114 SW, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-114 SW Section (VS) Reference: Well (0.00E,0.00N,291.11Azi) Wellpath: Plan L-114 SW Plan: SW L-114 wp05 Field: Prudhoe Bay ' , North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: PB L Pad UNITED STATES · North Slope Site Position: Northing: 5978232.73 ft Latitude: 70 21 1.823 N From: Map Easting: 582996.83 ft Longitude: 149 19 34.141 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.63 deg Well: Plan L-114 SW Slot Name: S-C Surface Position: +N/-S -167.94 ft Northing: 5978065.64 ft Latitude: 70 21 0.171 N +E/-W 73.99 ft Easting: 583072.67 ft Longitude: 149 19 31.978 W Position Uncertainty: 0.00 ft Reference Point: +N/-S -167.94 ft Northing: 5978065.64 ft Latitude: 70 21 0.171 N +E/-W 73.99 ft Easting: 583072.67 ft Longitude: 149 19 31.978 W Measured Depth: 77.00 ft Inclination: 0.00 deg VerticaIDepth: 77.00 ft Azimuth: 0.00 deg Wellpath: Plan L-114 SW Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: Temp Plan elevation 77 Height 77.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/8/2001 Declination: 26.43 deg Field Strength: 57446 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 291.11 Plan: SW L-114 wp05 Date Composed: 2/13/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information ~-~.~'--'~I'~ lnci Azim TVD +N/,S +Ei.W. · DLs. · Build. ' Turn· TFO Target ft deg. 'deg ft ft .'. ft deg/100ft degll00ft deg/100ft deg . 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 1100.00 5.00 345.00 1099.37 21.06 -5.64 1.00 1.00 0.00 345.00 1763.91 12.00 290.44 1756.42 73.24 -77.99 1.50 1.05 -8.22 281.62 1961.82 12.00 290.44 1950.00 87.61 -116.54 0.00 0.00 0.00 0.00 2095.15 16.00 290.44 2079.35 98.87 -146.76 3.00 3.00 0.00 0.00 2636.79 16.00 290.44 2600.00 151.01 -286.66 0.00 0.00 0.00 0.00 3354.69 44.72 290.44 3213.00 276.38 -623.10 4.00 4.00 0.00 0.00 6237.90 44.72 290.44 5261.82 984.70 -2524.02 0.00 0.00 0.00 0.00 7723.69 15.00 290.44 6536.00 1240.10 -3209.43 2.00 -2.00 0.00 180.00 P L 10 8150.55 6.46 290.44 6955.00 1267.83 -3283.84 2.00 -2.00 0.00 180.00 8300.55 3.46 290.44 7104.42 1272.36 -3296.00 2.00 -2.00 0.00 180.00 Section 1 : Start · "'MD: Incl Azim TVD ." ':'+N/-S · +E/-W VS : DLS ".-B-~i~-"-~'-';~'~'~- ............... ;~'-(~'"""": ..... 'Ti ....................... ~--:- ....... " · ft ' ' deg"' ' deg. :' ft ' : · ' ' .ft. ' .' ft ft" .... deg/100ft.deg/~00ft degil00ft 'd'eg · .' ' ':' · 77.00 0.00 0.00 77.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 100,00 0,00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/21/2001 Time: 15:45:11 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-114 SW, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-114 SW Section (VS) Reference: Well (0.00E,0.00N,291.11Azi) We!!Pat, h!., P,la_n. L:.! 14 SW _P!,a_n: ...................... s_WrL:l_l_4 ~p05 Section 2: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 700.00 1.00 345.00 699.99 0.84 -0.23 0.51 1.00 1.00 0.00 0.00 800.00 2.00 345.00 799.96 3.37 -0.90 2.06 1.00 1.00 0.00 0.00 900.00 3.00 345.00 899.86 7.58 -2.03 4.63 1.00 1.00 0.00 0.00 1000.00 4.00 345.00 999.68 13.48 -3.61 8.23 1.00 1.00 0.00 0.00 1100.00 5.00 345.00 1099.37 21.06 -5.64 12.85 1.00 1.00 0.00 0.00 Section 3: Start ft deg deg ft ft ft ft degl100ft deg/100ft deg/100ft deg 1200.00 5.50 329.49 1198.96 29.40 -9.20 19.17 1.50 0.50 -15.51 -78.38 1300.00 6.33 317.27 1298.43 37.58 -15.37 27.88 1.50 0.82 -12.21 -62.93 1400.00 7.37 308.17 1397.71 45.59 -24.15 38.95 1.50 1.04 -9.10 -50.78 1500.00 8.54 301.44 1496.75 53.42 -35.53 52.39 1.50 1.18 -6.74 -41.75 1600.00 9.81 296.37 1595.47 61.08 -49.50 68.18 1.50 1.27 -5.07 -35.07 1700.00 11.13 292.48 1693.81 68.56 -66.05 86.31 1.50 1.32 -3.90 -30.07 1763.91 12.00 290.44 1756.42 73.24 -77.99 99.14 1.50 1.36 -3.18 -26.19 Section 4: Start ft deg deg · ft ' ft ft ' ft deg/100ft deg/100ft deg/100ft deg ~-~-~-(~ ......... ~-~.~ .......... ~-~7 ..... ~T----CZ~ ....... :-~Z ..... ~-~:67- ..... ~.~)-~--;:)76~- ........ ~¥~- ......................... 1900.00 12.00 290.44 1889.54 83,12 -104.50 127.43 0.00 0.00 0.00 0.00 l._,_!._9.61.82 12.00 290.44 1950.00 87.61 -116.54 140.27 0.00 0.00 0.00 0.00 Section 5: Start 2000.00 1~:~-~- .... ~-~'~-:'~-~4- .......... i'~-~-~ ......... ~-~.-~-:~ ........ ---~;~-.-~ ........ ~'~:~-~- ....... -~'~------~:~)- ........ -~.~'~-- ...... 2095.15 16.00 290.44 2079.35 98.87 -146.76 172.52 3.00 3.00 0.00 0.00 Section 6: Start MD InCl Azim TVD ' +N/-S +E/-W VS : .DLS Build Turn· TFO ft deg deg ft ' ft ft ft deg/100ft deg/100ft deg/100ft deg 2100.00 16.00 290.44 2084.01 99.34 -148.01 173.86 0.00 0.00 0.00 0.00 2200.00 16.00 290.44 2180.14 108.96 -173.84 201.42 0.00 0.00 0.00 0.00 2300.00 16.00 290.44 2276.26 118.59 -199.67 228.98 0.00 0.00 0.00 0.00 2400.00 16.00 290.44 2372.39 128.21 -225.50 256.54 0.00 0.00 0.00 0.00 2500.00 16.00 290.44 2468.52 137.84 -251.33 284.10 0.00 0.00 0.00 0.00 2600.00 16.00 290.44 2564.64 147.47 -277.15 311.67 0.00 0.00 0.00 0.00 2636.79 16.00 290.44 2600.00 151.01 -286.66 321.81 0.00 0.00 0.00 0.00 Section 7: Start · ft. deg deg. ft. ft ft ft deg/100ft deg/100ft deg/100ft deg 2700.00 18.53 290.44 2660.36 157.56 -304.24 340.57 4.00 4.00 0.00 0.00 2800.00 22.53 290.44 2753.99 169.80 -337.09 375.63 4.00 4.00 0.00 0.00 2900.00 26.53 290.44 2844.95 184.30 -375.98 417.13 4.00 4.00 0.00 0.00 3000.00 30.53 290.44 2932.79 200.98 -420.73 464.87 4.00 4.00 0.00 0.00 3100.00 34.53 290.44 3017.08 219.75 -471.10 518.63 4.00 4.00 0.00 0.00 3200.00 38.53 290.44 3097.42 240.53 -526.86 578.14 4.00 4.00 0.00 0.00 3300.00 42.53 290.44 3173.41 263.22 -587.74 643.10 4.00 4.00 0.00 0.00 3354.69 44.72 290.44 3213.00 276.38 -623.10 680.83 4.01 4.01 0.00 0.00 Section 8: Start · MD . Inc!· Azim TVD . · +N/-S +E/-W .. VS . .DLS . Build Turn TFO. ... ft deg deg ft' ft ft ft deg/l'00ft deg/100ft deg/100ft · deg ............................ ~ .......................... : ................................. ' ....................... :- ................................. " ................................................................. - ............... :...::._.d....; .......................................... : ...................... : ........................ ~ .............................................. ; ....... 3400.00 44.72 290,44 3245.20 287.51 -652.97 712.71 0.00 0.00 0.00 180.00 3500.00 44.72 290.44 3316,25 312.09 -718.91 783.07 0.00 0.00 0.00 180.00 BP Amoco Planning Report- Geographic Company: BP Amoco Date: 2/21/2001 Time: 15:45:11 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-114 SW, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-114 SW Section (VS) Reference: Well (0.00E,0.00N,291.11Azi) Wellpath: Plan L-114 SW Plan: SW L-114 wp05 Section 8: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 3600.00 44.72 290.44 3387.31 336.66 -784.84 853.42 0.00 0.00 0.00 180.00 3700.00 44.72 290.44 3458.36 361.23 -850.78 923.78 0.00 0.00 0.00 180.00 3800.00 44.72 290.44 3529.42 385.81 -916.71 994.14 0.00 0.00 0.00 180.00 3900.00 44.72 290.44 3600.47 410.38 -982.64 1064.50 0.00 0.00 0.00 180.00 4000.00 44.72 290.44 3671.53 434.95 -1048.58 1134.86 0.00 0.00 0.00 180.00 4100.00 44.72 290.44 3742.58 459.53 -1114.51 1205.22 0.00 0.00 0.00 180.00 4200.00 44.72 290.44 3813.64 484.10 -1180.45 1275.58 0.00 0.00 0.00 180.00 4300.00 44.72 290.44 3884.69 508.67 -1246.38 1345.94 0.00 0.00 0.00 180.00 4400.00 44.72 290.44 3955.75 533.24 -1312.32 1416.30 0.00 0.00 0.00 180.00 4500.00 44.72 290.44 4026.80 557.82 -1378.25 1486.66 0.00 0.00 0.00 180.00 4600.00 44.72 290.44 4097.86 582.39 -1444.18 1557.02 0.00 0.00 0.00 180.00 4700.00 44.72 290.44 4168.92 606.96 -1510.12 1627.38 0.00 0.00 0.00 180.00 4800.00 44.72 290.44 4239.97 631.54 -1576.05 1697.74 0.00 0.00 0.00 180.00 4900.00 44.72 290.44 4311.03 656.11 -1641.99 1768.10 0.00 0.00 0.00 180.00 5000.00 44.72 290.44 4382.08 680.68 -1707.92 1838.46 0.00 0.00 0.00 180.00 5100.00 44.72 290.44 4453.14 705.26 -1773.85 1908.82 0.00 0.00 0.00 180.00 5200.00 44.72 290.44 4524.19 729.83 -1839.79 1979.18 0.00 0.00 0.00 180.00 5300.00 44.72 290.44 4595.25 754.40 -1905.72 2049.54 0.00 0.00 0.00 180.00 5400.00 44.72 290.44 4666.30 778.98 -1971.66 2119.89 0.00 0.00 0.00 180.00 5500.00 44.72 290.44 4737.36 803.55 -2037.59 2190.25 0.00 0.00 0.00 180.00 5600.00 44.72 290.44 4808.41 828.12 -2103.52 2260.61 0.00 0.00 0.00 180.00 5700.00 44.72 290.44 4879.47 852.69 -2169.46 2330.97 0.00 0.00 0.00 180.00 5800.00 44.72 290.44 4950.52 877.27 -2235.39 2401.33 0.00 0.00 0.00 180.00 5900.00 44.72 290.44 5021.58 901.84 -2301.33 2471.69 0.00 0.00 0.00 180.00 6000.00 44.72 290.44 5092.64 926.41 -2367.26 2542.05 0.00 0.00 0.00 180.00 6100.00 44.72 290.44 5163.69 950.99 -2433.19 2612.41 0.00 0.00 0.00 180.00 6200.00 44.72 290.44 5234.75 975.56 -2499.13 2682.77 0.00 0.00 0.00 180.00 6237.90 44.72 290.44 5261.82 984.70 -2524.02 2709.28 0.00 0.00 0.00 180.00 Section 9: Start MD Incl Azim TVD · +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft' ft ft deg/100ft deg/100ft deg/100ft deg 6300.00 43.48 290.44 5306.42 999.79 -2564.51 2752.50 2.00 -2.00 0.00 180.00 6400.00 41.48 290.44 5380.17 1023.37 -2627.79 2820.02 2.00 -2.00 0.00 180.00 6500.00 39.48 290.44 5456.23 1046.04 -2688.61 2884.93 2.00 -2.00 0.00 180.00 6600.00 37.48 290.44 5534.51 1067.77 -2746.92 2947.14 2.00 -2.00 0.00 180.00 6700.00 35.48 290.44 5614.91 1088.53 -2802.62 3006.58 2.00 -2.00 0.00 180.00 6800.00 33.48 290.44 5697.34 1108.30 -2855.66 3063.19 2.00 -2.00 0.00 180.00 6900.00 31.48 290.44 5781.70 1127.05 -2905.98 3116.88 2.00 -2.00 0.00 180.00 7000.00 29.48 290.44 5867.88 1144.76 -2953.50 3167.59 2.00 -2.00 0.00 180.00 7100.00 27.48 290.44 5955.77 1161.42 -2998.18 3215.27 2.00 -2.00 0.00 180.00 7200.00 25.48 290.44 6045.28 1176.98 -3039.96 3259.85 2.00 -2.00 0.00 180.00 7300.00 23.48 290.44 6136.28 1191.45 -3078.78 3301.28 2.00 -2.00 0.00 180.00 7400.00 21.48 290.44 6228.68 1204.81 -3114.60 3339.51 2.00 -2.00 0.00 180.00 7500.00 19.48 290.44 6322.36 1217.02 -3147.38 3374.49 2.00 -2.00 0.00 180.00 7600.00 17.48 290.44 6417.20 1228.09 -3177.08 3406.18 2.00 -2.00 0.00 180.00 7700.00 15.48 290.44 6513.09 1238.00 -3203.66 3434.54 2.00 -2.00 0.00 180.00 7723.69 15.00 290.44 6536.00 1240.10 -3209.43 3440.68 2.02 -2.02 0.00 180.00 Section 10: Start ft .'. deg · · deg ft . ft · 'ft ..' ft'. .deg/100ft deg/100ft degll00ft · deg ................................................................. '...- ............. ; .............................................................................................. £ ...................................................... : ................................................................... i 7800.00 13.47 290.44 6609.96 1246.65 -3227.01 3459.45 2.00 -2.00 0.00 180.00 7900.00 11.47 290.44 6707.60 1254.20 -3247.25 3481.04 2.00 -2.00 0.00 180.00 8000.00 9.47 290.44 6805.93 1260.54 -3264.29 3499.22 2.00 -2.00 0.00 180.00 8100.00 7.47 290.44 6904.83 1265.69 -3278.09 3513.95 2.00 -2.00 0.00 180.00 8150.55 6.46 290.44 6955.00 1267.83 -3283.84 3520.08 2.01 -2.01 0.00 180.00 BP Amoco Planning Report- Geographic Company: BP Amoco Date: 2/21/2001 Time: 15:45:11 Page: Field: Prudhoe Bay Co-ordinate(~E) Reference: Well: Plan L-114 SW, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-114 SW Section (VS) Reference: Well (0.00E,0.00N,291.11Azi) Wellpath:..Plan 7174SW ............................................. ~lan: ............................... S_w ~7! !.4_.W_p05 Section 11: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 8200.00 5.47 290.44 7004.18 1269.62 -3288.66 3525.22 2.00 -2.00 0.00 180.00 8300.55 3.46 290.44 7104.42 1272.36 -3296.00 3533.06 2.00 -2.00 0.00 180.00 Survey Map Map <B. Latitude --> <-- Longitude ~--> MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ff deg deg ft ft ft ft ff 77.00 0.00 0.00 77.00 0.00 0.00 5978065.64 583072.67 70 21 0.171 N 149 19 31.978 W 1000,00 4,00 345,00 999,68 13,48 -3,61 5978079,07 583068,91 70 21 0,304 N 149 19 32,084 W 1100,00 5,00 345,00 1099,37 21,06 -5,64 5978086,63 583066,80 70 21 0,379 N 149 19 32,143 W 1200,00 5,50 329,49 1198,96 29,40 -9,20 5978094,93 583063,14 70 21 0,461 N 149 19 32,247 W 1300,00 6,33 317,27 1298,43 37,58 -15,37 5978103,04 583056,88 70 21 0,541 N 149 19 32,428 W 1400,00 7,37 308,17 1397.71 45.59 -24,15 5978110,95 583048,01 70 21 0,620 N 149 19 32,684 W 1500,00 8,54 301,44 1496,75 53,42 -35,53 5978118,66 583036,55 70 21 0,697 N 149 19 33,017 W 1600,00 9,81 296.37 1595,47 61,08 -49,50 5978126,16 583022,50 70 21 0,772 N 149 19 33,425 W 1700,00 11,13 292,48 1693,81 68,56 -66,05 5978133,45 583005,86 70 21 0,846 N 149 19 33,909 W 1763,91 12,00 290,44 1756,42 73,24 -77,99 5978138,00 582993,88 70 21 0,892 N 149 19 34,258 W 1800,00 12,00 290,44 1791,72 75.86 -85,02 5978140,54 582986,82 70 21 0,917 N 149 19 34,463 W 1900,00 12,00 290,44 1889,54 83,12 -104,50 5978147,59 582967,26 70 21 0,989 N 149 19 35,032 W 1961,82 12,00 290,44 1950,00 87,61 -116,54 5978151,94 582955,18 70 21 1,033 N 149 19 35,384 W 2000,00 13,15 290,44 1987,26 90,51 -124,33 5978154,76 582947,36 70 21 1,062 N 149 19 35,612 W 2095,15 16,00 290,44 2079,35 98,87 -146,76 5978162,86 582924,84 70 21 1,144 N 149 19 36,267 W 2100,00 16.00 290.44 2084,01 99.34 -148,01 5978163,32 582923,58 70 21 1,148 N 149 19 36,304 W 2200,00 16,00 290,44 2180,14 108,96 -173,84 5978172,65 582897,65 70 21 1,243 N 149 19 37,059 W 2300,00 16,00 290,44 2276.26 118.59 -199,67 5978181,99 582871,72 70 21 1,338 N 149 19 37,814 W 2400,00 16,00 290,44 2372,39 128,21 -225,50 5978191,33 582845,78 70 21 1,432 N 149 19 38.569 W 2500,00 16,00 290,44 2468,52 137,84 -251,33 5978200,67 582819,85 70 21 1,527 N 149 19 39,323 W 2600,00 16,00 290,44 2564,64 147,47 -277,15 5978210,01 582793,92 70 21 1,622 N 149 19 40,078 W 2636,79 16,00 290,44 2600,00 151,01 -286,66 5978213,44 582784,38 70 21 1,657 N 149 19 40,356 W 2700,00 18,53 290,44 2660,36 157,56 -304,24 5978219,80 582766,73 70 21 1,721 N 149 19 40,870 W 2800,00 22,53 290,44 2753,99 169,80 -337,09 5978231,68 582733,75 70 21 1.841 N 149 19 41.830 W 2900,00 26,53 290,44 2844,95 184,30 -375,98 5978245,74 582694,70 70 21 1,984 N 149 19 42,966 W 3000,00 30,53 290,44 2932,79 200,98 -420,73 5978261,92 582649,78 70 21 2,148 N 149 19 44,274 W 3100,00 34,53 290,44 3017,08 219,75 -471,10 5978280,13 582599,20 70 21 2,332 N 149 19 45,746W 3200,00 38,53 290,44 3097,42 240,53 -526,86 5978300,29 582543,22 70 21 2,537 N 149 19 47,376W 3300,00 42,53 290,44 3173,41 263,22 -587,74 5978322,30 582482,10 70 21 2.760 N 149 19 49,155W 3354,69 44,72 290,44 3213,00 276,38 -623,10 5978335,07 582446,60 70 21 2,889 N 149 19 50,189W 3400,00 44,72 290,44 3245,20 287,51 -652,97 5978345,87 582416,61 70 21 2,999 N 149 19 51,062W 3500,00 44,72 290,44 3316,25 312,09 -718,91 5978369,71 582350,41 70 21 3,240 N 149 19 52,989W 3600,00 44,72 290,44 3387,31 336,66 -784,84 5978393,54 582284,21 70 21 3,482 N 149 19 54,916W 3700,00 44,72 290,44 3458.36 361,23 -850,78 5978417,38 582218,02 70 21 3,724 N 149 19 56,843W 3800,00 44,72 290,44 3529,42 385,81 -916,71 5978441,22 582151,82 70 21 3,965 N 149 19 58.770W 3900,00 44,72 290,44 3600,47 410,38 -982,64 5978465,06 582085,63 70 21 4,207 N 149 20 0,697W 4000,00 44,72 290,44 3671,53 434,95 -1048,58 5978488,90 582019,43 70 21 4,448 N 149 20 2.624W 4100,00 44,72 290,44 3742,58 459,53 -1114,51 5978512,74 581953,23 70 21 4,690 N 149 20 4,551 W 500,00 0,00 0,00 500,00 0,00 0,00 5978065,64 583072,67 70 21 0,171 N 149 19 31,978W 600,00 0,00 0,00 600,00 0.00 0.00 5978065,64 583072,67 70 21 0,171 N 149 19 31,978W 700,00 1,00 345,00 699,99 0,84 -0,23 5978066,48 583072,43 70 21 0,180 N 149 19 31,985W 800,00 2,00 345,00 799,96 3,37 -0,90 5978069,00 583071,73 70 21 0,205 N 149 19 32,005W 900,00 3,00 345,00 899.86 7,58 -2,03 5978073,20 583070.55 70 21 0,246 N 149 19 32,038W 100,00 0,00 0,00 100,00 0,00 0,00 5978065,64 583072,67 70 21 0.171 N 149 19 31,978W 200,00 0,00 0,00 200,00 0,00 0,00 5978065,64 583072,67 70 21 0,171 N 149 19 31,978W 300,00 0,00 0,00 300,00 0,00 0,00 5978065,64 583072,67 70 21 0,171 N 149 19 31,978W 400,00 0,00 0,00 400,00 0,00 0,00 5978065,64 583072,67 70 21 0.171 N 149 19 31,978W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/21/2001 Time: 15:45:11 Page: 5 Field: Prudhoe Bay Coordinate(NE) Reference: Well: Plan L-114 SW, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-114 SW Section (VS) Reference: Well (0.00E,0.00N,291.11Azi) Wellpath: Plan L-114 SW Plan: SW L-114 wp05 Survey Map Map <--- Latitude ---> <-- Longitude ---> MD lnc! Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft deg deg ft ft ft ff ff 4200.00 44.72 290.44 3813.64 484.10 -1180.45 5978536.57 581887.04 70 21 4.932 N 149 20 6.478 W 4300.00 44.72 290.44 3884.69 508.67 -1246.38 5978560.41 581820.84 70 21 5.173 N 149 20 8.405 W 4400.00 44.72 290.44 3955.75 533.24 -1312.32 5978584.25 581754.64 70 21 5.415 N 149 20 10.333 W 4500.00 44.72 290.44 4026.80 557.82 -1378.25 5978608.09 581688.45 70 21 5.656 N 149 20 12.260W 4600.00 44.72 290.44 4097.86 582.39 -1444.18 5978631.93 581622.25 70 21 5.898 N 149 20 14.187W 4700.00 44.72 290.44 4168.92 606.96 -1510.12 5978655.77 581556.06 70 21 6.139 N 149 20 16.114W 4800.00 44.72 290.44 4239.97 631.54 -1576.05 5978679.60 581489.86 70 21 6.381N 149 20 18.041W 4900.00 44.72 290.44 4311.03 656.11 -1641.99 5978703.44 581423.66 70 21 6.622 N 149 20 19.968W 5000.00 44.72 290.44 4382.08 680.68 -1707.92 5978727.28 581357.47 70 21 6.864 N 149 20 21.896W 5100.00 44.72 290.44 4453.14 705.26 -1773.85 5978751.12 581291.27 70 21 7.105 N 149 20 23.823W 5200.00 44.72 290.44 4524.19 729.83 -1839.79 5978774.96 581225.07 70 21 7.347 N 149 20 25.750W 5300.00 44.72 290.44 4595.25 754.40 -1905.72 5978798.80 581158.88 70 21 7.588 N 149 20 27.677W 5400.00 44.72 290.44 4666.30 778.98 -1971.66 5978822.64 581092.68 70 21 7.830 N 149 20 29.605W 5500.00 44.72 290.44 4737.36 803.55 -2037.59 5978846.47 581026.48 70 21 8.071 N 149 20 31.532W 5600.00 44.72 290.44 4808.41 828.12 -2103.52 5978870.31 580960.29 70 21 8.313 N 149 20 33.459W 5700.00 44.72 290.44 4879.47 852.69 -2169.46 5978894.15 580894.09 70 21 8.554 N 149 20 35.386W 5800.00 44.72 290.44 4950.52 877.27 -2235.39 5978917.99 580827.90 70 21 8.796 N 149 20 37.314W 5900.00 44.72 290.44 5021.58 901.84 -2301.33 5978941.83 580761.70 70 21 9.037 N 149 20 39.241 W 6000.00 44.72 290.44 5092.64 926.41 -2367.26 5978965.67 580695.50 70 21 9.279 N 149 20 41.168W 6100.00 44.72 290.44 5163.69 950.99 -2433.19 5978989.50 580629.31 70 21 9.520 N 149 20 43.096W 6200.00 44.72 290.44 5234.75 975.56 -2499.13 5979013.34 580563.11 70 21 9.762 N 149 20 45.023W 6237.90 44.72 290.44 5261.82 984.70 -2524.02 5979022.21 580538.12 70 21 9.852 N 149 20 45.751 W 6300.00 43.48 290.44 5306.42 999.79 -2564.51 5979036.85 580497.47 70 21 10.000 N 149 20 46.934W 6400.00 41.48 290.44 5380.17 1023.37 -2627.79 5979059.72 580433.94 70 21 10.232 N 149 20 48.784W 6500.00 39.48 290.44 5456.23 1046.04 -2688.61 5979081.71 580372.87 70 21 10.454 N 149 20 50.562W 6600.00 37.48 290.44 5534.51 1067.77 -2746.92 5979102.79 580314.34 70 21 10.668 N 149 20 52.266W 6700.00 35.48 290.44 5614.91 1088.53 -2802.62 5979122.93 580258.41 70 21 10.872 N 149 20 53.895W 6800.00 33.48 290.44 5697.34 1108.30 -2855.66 5979142.11 580205.16 70 21 11.066 N 149 20 55.445W 6900.00 31.48 290.44 5781.70 1127.05 -2905.98 5979160.30 580154.64 70 21 11.250 N 149 20 56.9~6W 7000.00 29.48 290.44 5867.88 1144.76 -2953.50 5979177.48 580106.93 70 21 11.424 N 149 20 58.305W 7100.00 27.48 290.44 5955.77 1161.42 -2998.18 5979193.64 580062.08 70 21 11.588 N 149 20 59.612W 7200.00 25.48 290.44 6045.28 1176.98 -3039.96 5979208.74 580020.13 70 21 11.741N 149 21 0.833W 7300.00 23.48 290.44 6136.28 1191.45 -3078.78 5979222.78 579981.15 70 21 11.883 N 149 21 1.968W 7400.00 21.48 290.44 6228.68 1204.81 -3114.60 5979235.73 579945.19 70 21 12.014 N 149 21 3.015W 7500.00 19.48 290.44 6322.36 1217.02 -3147.38 5979247.58 579912.28 70 21 12.134 N 149 21 3.973W 7600.00 17.48 290.44 6417.20 1228.09 -3177.08 5979258.32 579882.46 70 21 12.243 N 149 21 4.841 W 7700.00 15.48 290.44 6513.09 1238.00 -3203.66 5979267.93 579855.78 70 21 12.340 N 149 21 5.618W 7723.69 15.00 290.44 6536.00 1240.10 -3209.43 5979269.97 579849.99 70 21 12.361N 149 21 5.787W 7800.00 13.47 290.44 6609.96 1246.65 -3227.01 5979276.33 579832.33 70 21 12.425 N 149 21 6.301W 7900.00 11.47 290.44 6707.60 1254.20 -3247.25 5979283.64 579812.01 70 21 12.499 N 149 21 6.893W 8000.00 9.47 290.44 6805.93 1260.54 -3264.29 5979289.80 579794.91 70 21 12.562 N 149 21 7.391 W 8100.00 7.47 290.44 6904.83 1265.69 -3278.09 5979294.79 579781.05 70 21 12.612 N 149 21 7.794W 8150.55 6.46 290.44 6955.00 1267.83 -3283.84 5979296.87 579775.28 70 21 12.633 N 149 21 7.962W 8200.00 5.47 290.44 7004.18 1269.62 -3288.66 5979298.61 579770.44 70 21 12.651N 149 21 8.103W 8300.55 3.46 290.44 7104.42 1272.36 -3296.00 5979301.26 579763.07 70 21 12.678 N 149 21 8.318W Targets '.:.' : ·: ...... ' :" · · "· ' · ' ' : ' 'i ' ":;: ' MaP 'Map .= < .... Latitude ----> <-- Longitude ---> I Name ' '.' .: ' · Description TVD · · +N/-S'.. · -FE/-W NOt,thing .. · 'Easting : · .Deg Min · Sec . Deg.Min Sec" ,.. .. .i: . i: 'ft .' . .ft .': ft.." '~'. ft... .:ft...:i~. ' i: . ... --ffolygon I 6536.00 1450.09 -3657.17 5979474.96 579399.99 70 21 14.424 N 149 21 18.877 W I -Polygon 2 6536.00 801.08 -3304.31 5978829.96 579759.99 70 21 8.043 N 149 21 8.555 W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/21/2001 Time: 15:45:11 Page: 6 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-114 SW, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-114 SW Section (VS) Reference: Well (0.00E,0.00N,291.11Azi) Wellpath: Plan L-114 SW Plan: SW L-114 wp05 Targets Map Map <--- Latitude --> <~- Longitude Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec -Polygon 3 6536.00 1214.12 -2669.63 5979249.98 580389,99 70 21 12.107 N 149 20 50.009 W -Polygon4 6536.00 1709.17 -3119.22 5979739.97 579934.98 70 21 16.975 N 149 21 3.156 W -Plan hit target L-114 Fault 3517.00 494.05 -867,33 5978549.99 582200.00 70 21 5.030 N 149 19 57.327 W -Plan out by 118.73 at 3517.00 381.51 -905.19 5978437.05 582163.39 70 21 3.923 N 149 19 58.433 W ! DATE ! CHECK NO. I VENDOR ALi~,SKAO I LA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NE-Jr )&OlO1 CKO&OIO1L 100. O0 100.00 PYMT COMMENTS: PER~IT TO DRILL FEE HANDLINO INST: S/H - TERRIE HUBBLE X4&~8 IE ATrACHED CHECK IS lN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~e]~i1~ :~ 1OO_ OO ZOO. OO_ BP:EXPLORATION, (ALASKA)iNC.' RO. BOX 196612 ANCEORAGE, AlaSKA 99519~6612 FIRST NATIOI AN 'AFFILIATE OF NATIONAL CITY BANK- CLEVELAND, OHIO 56-389 412 IDATED COMMERCIAL. ACCOUNT PAY To The ORDER ?: _ 0~ 00~ ONE HUNDRED?.:... ~ OO/1 SUITE TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 CHECK WHAT APPLIES STANDARD LETTER "CLUE" DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISP~AL ( \?~o ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS The permit is for a new wellbore segment of existing well .. , Permit No, ~ API No. ~. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and AP1 number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... ( ) YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. 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. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST FIELD & POOL ~ ~D / 3 COMPANY /4~,~ WELL NAME .~_..-/,,/Z/ INIT CLASS ADMINISTRATION 1. APPR D~TE 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. Well located proper distance from other wells .......... 7. Sufficient acreage available' in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. ~.~ DATE 26. ~'~/~. ~[{'% 27. 28. 29, GEOLOGY 30. 31 32. APER DATE 33. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons ..... ' ..... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... PROGRAM: exp GEOL AREA _,~ ? ~ dev ~,J~' redrll APPR 'DATE serv N N N N wellbore sag UNIT# , , ann. disposal para req ON/OFF SHORE If a re-drill, has a 10-403 for abandonment been approved... -N- Adequate wellbore separation proposed ....... ; ...... iN .... If diverter required, does it meet regulations .......... N Drilling .fluid program schematic & equip list adequate ..... N BOPEs, do they meet regulation ......... ,. ~:'"'... 'N' BOPE press rating appropriate;test to ~,~k._bsig. ,,N ~,~c~'~ ~.~,~.~ (~ ,~ Choke manifold complies W/APl RP-53 (May 84) ......... ~ . Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Permit can be issued wlo hydrogen sulfide measures ..... Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones .............. Seabed condition survey (if off-shore) ............. · Contact name/phone for weekly progress reports [exploratory on Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; ' (C) will not impair mechanical integrity of the well used for diSposal; Y. N (D). will not damage producing formation or impair recovery from a Y N... pool; and (E.) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UIC/~,nnular , , , GEOLOGY: COMMISSION: '8 s Comments/Instructions: c:~msoffice\wordian~iana\checklist (rev. 111011100) .,
