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Home My WebLink About205-0437. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-124 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-043 50-029-23255-00-00 10774 Conductor Surface Intermediate Liner Liner 6485 80 3197 8459 2442 8547 20" X 34" 9-5/8" 7" 4-1/2" 6482 31 - 111 30 - 3227 28 - 8487 8285 - 10727 31 - 111 30 - 2602 28 - 6465 6377 - 6482 8546, 8564, 9197 770 3090 5410 7500 None 2280 5750 7240 8430 8398 - 10778 3-1/2" 9.2# L-80 26 - 8290 6430 - 6485 Structural 3-1/2" Baker Premier Packer 8231 6349 Torin Roschinger Area Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, Borealis Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028239 26 - 6380 N/A N/A 143 255 702 863 24 24 800 950 400 380 N/A 13b. Pools active after work:Borealis Oil No SSSV 8231, 6349 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:13 am, Aug 28, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.28 06:34:23 - 08'00' Torin Roschinger (4662) RBDMS JSB 090324 DSR-9/5/24WCB 10-3-2024 ACTIVITY DATE SUMMARY 8/17/2024 ***WELL FLOWING ON ARRIVAL*** PULLED DREAM CATCHER 8191'MD (empty) DRIFTED w/30' x 1.56'' DMYGUNS TO 8546'MD ***WELL LEFT S/I ON DEPARTURE*** 8/18/2024 ***WELL ONLINE ON ARRIVAL*** OBJECTIVE: ELINE PERF MIRU YJ ELINE, PT PCE 300 PSI / 3000 PSI HIGH CORRELATED TO HALLIBURTON MEMORY 24 ARM CALIPER LOG DATED 29- JAN-23 RIH W/ GUN #1 20' X 1.56 GEO RAZOR CHARGES, 6 SPF 60 DEG PHASE PERF INTERVAL 8486 - 8506 OFFSET 12, CCL STOP 8474 ALL SHOTS FIRED RIH W/ GUN #2 10' X 1.56 GEO RAZOR CHARGES, 6 SPF 60 DEG PHASE PERF INTERVAL 8476 - 8486 OFFSET 9.5, CCL STOP 8466.5 ALL SHOTS FIRED JOB COMPLETE WELL SHUT IN ON DEPARTURE 8/18/2024 T/I/O=1120/1300/100 Temp=S/I (Assist E-Line with load and pump down) Pumped 75 BBLS of crude down TBG for load. Pumped an additional 17 BBLS of crude down TBG to get E-Line unstuck. E-Line in control of well upon departure Final WHPS=690/1500/100 8/19/2024 ***WELL S/I ON ARRIVAL***(perforating) BRUSHED/DRIFTED TBG DOWN TO X-NIPPLE @ 8191' MD W/ 3-1/2" BRUSH & 2.80" GAUGE RING.(no issues) SET 3-1/2" DREAM CATCHER ASSY IN X-NIPPLE @ 8191' MD. CONFIRMED GOOD SET W/ 3-1/2" CHECKSET.(sheared) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU L-124 PERF INTERVAL 8476 - 8486 PERF INTERVAL 8486 - 8506 Adperfs are shown correctly on WBS, below. -WCB 1.9.2023 By Meredith Guhl at 3:43 pm, Jan 09, 2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.01.09 15:04:45 -09'00' Monty M Myers RBDMS JSB 011023 DSR-1/9/23WCB 10-25-2023 ACTIVITYDATE SUMMARY 11/25/2022 T/I/O= 500/250/0 Temp=S/I (TFS Unit 4 Assist SL with TBG Obstruction) Pumped 4 bbls of 60/40 followed by 3 bbls of Crude down TBG in attempt to Clear Obstrution. Obstrction not Cleared. Rigged up to IA and Pumped 2 bbls of 60/40 followed by 58 bbls of Crude to verify flow path. Final WHPS= 500/450/0 SL on well upon departure. 11/25/2022 ***WELL S/I ON ARRIVAL*** ATTEMPT TO DRIFT TO DEVIATION W/ 20' OF 2.70" DMY WHIPSTOCK SD HIGH @ 939' SLM RAN S.BAILER TO 939' SLM, OBTAINED SAMPLE OF ICE PLUG. ATTEMPT TO CHOP THRU PLUG W/ 1.70" G.RING WHILE T-BIRD PUSHED ICE PLUG TO 945' SLM. T-BIRD PUMPED DOWN IA ESTABLISHED GOOD FLOW PATH DOWN BACK SIDE. ***JOB TICKET SUSPENDED, SLICKLINE RETURN AT LATER DATE*** 11/26/2022 ** WELL THAW ** T/I/O= 1076/326/64 Pumped 3 bbls 60/40 and 237 bbls 190* crude down IA for well thaw. Pumped a total of 1 bbls 60/40 and 5 bbls Crude into TBG. *** Job postponed due to SL *** 11/27/2022 T/I/O= 974/518/71. LRS 72 Thaw TBG Hydrates (HOT OIL TBG WASH). Pumped 2 bbls of 60/40 MeOH into the F/L. Pumped 0.3 bbls of 60/40 MeOH into the TBG. Pressured up to 2500 psi. Pumped 180 bbls of 180*F crude into the IA. Bled thermal expansion off TBG as needed. Final T/I/O= 500/800/165. 11/28/2022 T/I/O= 370/540/80. LRS 72 Hot Oil Treatment/ Hydrate Thaw. Pumped 2 bbls of 60/40 MeOH and 13 bbls of crude into the F/L. Pumped 4 bbls of 60/40 MeOH to pressure the TBG to 2990 psi. Pumped 395 bbls of 180*F crude into the IA. Bled thermal off TBG as needed. *** Job continued to 11-29-2022 *** 11/29/2022 T/I/O= 790/650/112. LRS 72 Continue Hydrate Thaw (HOT OIL TBG WASH). Pumped 0.5 bbls of 140*F crude into the TBG to pressure up to 2500 psi. Pumped 382 bbls of 180*F crude into the IA. Job postponed due to being pulled to assist SL. FWHP's = 1376/2210/320 11/29/2022 *** Job continued from 11-28-2022 *** Hot Oil Treatment/ Hydrate Thaw. Pumped 52 bbls 180* Crude into IA for thaw. Job postponed due to V-234. FWHP's = 2149/2108/260 11/30/2022 T/I/O = 291/605/93. Temp - SL. Conduct Hot Oil Treatment. Pumped .5 bbls 60/40 into TBG, pressured up to 2495 psi. Pumped 2 bbls 60/40 and 83 bbls 180* Crude into IA for Thaw. *** Job continued to 12-01-2022 *** 12/1/2022 *** Job continued from 11-30-2022 *** LRS 72 Conduct Hot Oil Treatment; Hydrate/Ice Plug. Pumped 111 bbls 180* Crude into IA for Thaw till SL on loction. SL tagged Ice at 1960'. Continue with Thaw. Pumped 330 bbls 180* Crude into IA. TBG still plugged. Pumped 220 bbls of 200*F 2% KCl into the IA. Pumped 100 bbls 180* crude down Tbg. Pumped 36 bbls 180* crude down IA. ***Job Cont to 12-2-2022 WSR*** 12/1/2022 ***WELL S/I UPON ARRIVAL*** (ctd) TAGGED ICE W/ 2.50" SAMPLE BAILER @ 1964' SLM ***LRS IN CONTROL OF WELL UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 12/2/2022 ***WELL S/I ON ARRIVAL*** (Pre CTD) POLLARD #60 ON WEATHER HOLD DUE TO HIGH WINDS (In Pollard yard). ***JOB IN PROGRESS, CONTINUED ON 12/3/22 WSR*** 12/2/2022 Weather Standby Daily Report of Well Operations PBU L-124 Daily Report of Well Operations PBU L-124 12/2/2022 ***Job Cont from 12-01-2022 WSR*** (WELL THAW) Pumped 34 bbls 180* crude (70 bbls total) down IA to freeze protect IA after pumping water. Pumped 18 bbls crude down FL for FP. Pressured up FL to 1500 psi. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 12/3/2022 LRS 72 Weather Standby 12/3/2022 ***CONTINUED FROM 12/2/22 WSR*** (Pre CTD) POLLARD #60 WEATHER HOLD DUE TO HIGH WINDS (In Pollard yard). JOB CHANGED FROM DS12-13 TO L-124. ***DECISION MADE TO COMPLETE MAINTENANCE BEFORE HEADING OUT WEST*** 12/4/2022 ***WELL S/I ON ARRIVAL*** (Pre CTD) POLLARD #60 WEATHER HOLD DUE TO HIGH WINDS. ***JOB IN PROGRESS, CONTINUED ON 12/5/22 WSR*** 12/5/2022 ***CONTINUED FROM 12/4/22 WSR*** (Pre CTD) DRIFT TO 3-1/2" WFD PATCH AT 8,114' MD W/ 3-1/2" BRUSH, 2.75" G-RING. PULL 1.781" R-LOCK W/ NORTHERN SOLUTIONS JET PUMP FROM 8,130' MD. PULL COMPLETE UPPER 3-1/2" WFD WP STRADDLE PATCH FROM 8,114' MD. ***JOB IN PROGRESS, CONTINUED ON 12/6/22 WSR*** 12/6/2022 ***CONTINUED FROM 12/5/22 WSR*** (Pre CTD) PULL COMPLETE 3-1/2" WFD WP ANCHOR PACKER FROM 8,144' MD. DRIFT TO DEVIATION AT 8,530' SLM W/ 3-1/2" BRUSH, 2.75" CENT, S-BLR (No issues). SET 3-1/2" PX PLUG BODY & BAITED P-PRONG IN X-NIPPLE AT 8,278' MD. TB PUMPED 260 BBLS OF 1% KCL W/ 88 BBL DIESEL FREEZE PROTECT FOR CIRC OUT. THUNDERBIRD PERFORMED SUCCESSFUL CMIT-T x IA TO 2388 PSI. PULL RKP-FLOW SLEEVE FROM ST #1 & SET RK-DGLV AT ST #1 (8,132' MD). THUNDERBIRD PERFORMED SUCCESSFUL MIT-T TO 4524 PSI. TB PERFORMED SUCCESSFUL MIT-IA TO 4560 PSI (Held ~2000 psi on tubing for test). PULL BAITED P-PRONG FROM 3-1/2" PX PLUG BODY AT 8,278' MD. ***JOB IN PROGRESS, CONTINUED ON 12/7/22 WSR*** 12/6/2022 T/I/O= 533/356/0 (TFS unit 4 assist SL (CTD) ) Pumped 3 bbls of 60/40 followed by260 bbls of 1 Percent KCL down TBG taking returns up IA to L-101 FL. Further pumped 88 bbls of DSL down TBG for Freeze Protect. U-Tubed TxIA for ~3.5 hrs until circulation stopped. CMIT TxIA ****PASSED**** Max applied pressure=2500. Target Pressure=2250. Pumped 2 bbls of DSL down TBG/IA to reach max appled pressure. 1st 15 Min TBG/IA lost 65/59 psi. 2nd 15 Min TBG/IA lost 31/29 psi. TBG/IA lost 96/88 psi in 30 Min test. Bled back 2.2 bbls. MIT-T *****PASSED***** Max applied pressure=4700. Target Pressure=4500. Pumped 1 bbl of DSL down TBG to reach max applied pressure. 1st 15 Min TBG lost 136 psi. 2nd 15 Min TBG lost 38 psi. TBG lost 174 psi in 30 Min test. Bled TBG down to 1800 psi. . MIT-IA ***PASSED*** to 4560 psi. pumped 4 bbls DSL to Reach max applied psi of 4700 with a target psi of 4500. 1st 15 min IA lost 94 psi. 2nd 15 min IA lost 35 psi for a total loss of 129 psi in 30 min. Bled back 4 bbls dsl. Tags hung on WV & IAC. SL in control of well upon Departure FWHP= 500/550/0 () PULL COMPLETE 3-1/2" WFD WP ANCHOR PACKER FROM 8,144' MD. ) SET 3-1/2" PX PLUG BODY & BAITED P-PRONG IN X-NIPPLE AT 8,278' MD. THUNDERBIRD PERFORMED SUCCESSFUL MIT-T TO 4524 PSI. TB PERFORMED SUCCESSFUL MIT-IA TO 4560 PSI MIT-T *****PASSED***** PULL 1.781" R-LOCK W/ NORTHERN SOLUTIONS JET PUMP FROM 8,130' MD PULL COMPLETE UPPER 3-1/2" WFD WP STRADDLE PATCH FROM 8,114' MD. MIT-IA ***PASSED*** to 4560 psi CMIT TxIA ****PASSED**** Daily Report of Well Operations PBU L-124 12/7/2022 ***CONT FROM 12/6/22 WSR*** (CTD) PULL 3-1/2" PX PLUG BODY FROM X-NIPPLE AT 8,278' MD. DRIFT TO DEVIATION AT 8,533' SLM W/ 2.74" x 20' DUMMY WHIPSTOCK. ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** DRIFT TO 3,100' SLM W/ 2.74" x 20' DUMMY WHIPSTOCK FOR SUBSIDENCE SURVEILLANCE. 12/10/2022 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP RAN GUN GAMMA TO 8597' MD, STOPPED DUE TO DEVIATION. CORRELATED TO COIL FLAG 25-NOV-2015. MAKE 1 ATTEMPT TO SET WHIPSTOCK, SAT DOWN AT 5038' & 5400' MD WHILE RUNNING IN HOLE. ABLE TO WORK BY SPOT EASILY, TOOL FELL FREELY TO 8550' CCL DEPTH, TOOLS WERE ERATIC IN LINER BUT WORKED IN TUBING. TROUBLESHOOT DOWNHOLE AND RETURN TO SURFACE TO INSPECT. TROUBLESHOOT TRACTORS/DC-MOT TOOLS. NO IMEDIATE ISSUES FOUND, REHEAD, SWAP TO BACKUP TRACTOR & DC-MOT FOR MORNING START. ***CONTINUED ON 12/11/2022*** 12/11/2022 ***CONTINUED FROM 12/10/2022 WSR*** PRESSURE TEST PCE 250LP-3000HP SET BAKER GEN II DELTA FLOW THRU 3.5" X 4.5" WHIPSTOCK(15' OAL, TRAY LENGTH 9.50', 2.65" MAX OD) CCL STOP DEPTH=8550.5' MD, CCL TO TOW=14.5'. TOW SET DEPTH=8565' MD WEDGE ORIENTED AT 35 ROHS AND 28 ROHS AFTER SETTING. CORRELATED TO COIL FLAG 25-NOV-2015. ***WELL LEFT S/I, PAD OP NOTIFIED*** 12/17/2022 T/I/O=SI/0/0. Pre CDR. Remove 4" chemical blind companion flow cross. Install kill line. Remove 4" tree cap assembly. Install 4" tapped blind. Install slip blind between WV and FL. ***change out with day shift*** 12/18/2022 T/I/O=SI/0/0. Torque Kill Line & Tapped Blind Flange to API specs. PT kill line & flange against MV. 300 psi low & 5000 psi high (PASSEDED). RD C spoil. Install tapped blind flanges on IA valve & line. Torque to specs. ***JOB COMPLETE***. Final WHP's=SI/0/0. SL finished its work here. -WCB TOW SET DEPTH=8565' MD SET BAKER GEN II DELTA FLOW THRU 3.5" X 4.5" WHIPSTOCK DRIFT TO DEVIATION AT 8,533' SLM W / 2.74" x 20' DUMMY WHIPSTOCK () PULL 3-1/2" PX PLUG BODY FROM X-NIPPLE AT 8,278' MD. Activity Date Ops Summary 12/20/2022 Spot main rig sub. Spot Pits. Rig accept 10:00. Perform rig up checklists. RU ancillary equipment. Open well with 619 psi. Monitor flowline pressure. Perform LTT to 3500#. N/D 3 1/16" x 7" spool. N/U 4 1/8" x 7" spool. N/U BOPE. Inspect tree nuts/bolts. Grease and service all BOPE and choke/kill valves. Inspect and change coil pack offs. Pump eline slack forward with rig water at max rate. Fluid pack all rig surface lines. R/U test pump to test BOPE. Troubleshoot and thaw frozen test pump line. Test IRV and coil pack-offs to 3500 psi per PTD. Pass. Line up to pressure test PDL's. Pass. Clear and clean rig floor. R/U test joint. 12/21/2022 Prep floor and test joint to test BOPE. Test 1: IRV, Stripper, C7, C9, C10, C11. Test 2: Blind/Shear, Romeo 2, Bleeder 2, Charlie 15. Test 3: Annular, TIW #1, Bravo #1, Bravo #4. Test 4: Upper 2" Pipe/Slips, TIW #2, Bravo #2, Bravo #3. Test 5: Lower 2" Pipe/Slips, Charlie 5, Charlie 6, Charlie 8, Test Valve 2. Test 6: Choke A, Choke C. Test 7: Upper 2" Pipe/Slips, Charlie 1, Charlie 4, Test Valve 1. F/P on Test Valve #1. Greased and tested good. Perform Drawdown test on accumulator with passing results. Test 8: 2-3/8" Pipe/Slips, Charlie 2, Charlie 3, Test Valve 2. Test 8 had a F/P on the 2-3/8" Pipe/Slips rams with testing while the accumulator was off and relieved of pressure. Changed out brass on auto locking mechanisms and appears elements are leaking with the path of the leak. Blow down test pump lines. Remove test joint from stack checking connections, Blow down BOPE stack, Swap out 2-3/8" Pipe/Slips rams. Re-test and pass. All tests witnessed by AOGCC representative Guy Cook. L/D BOP test joint and clear floor. L/D BOP test riser. M/U Drilling riser. M/U BHI Floats. Test floats to 3500 psi. Pass. Open well with 630 psi shut in pressure. Bullhead kill well. 10 bbls MeOH. 195 bbls 1% slick KCL. Circ pressure 1550 psi at 5.13 bpm. Pressure Deploy BOT window milling assembly. BHA #1. 12/22/2022 Pressure deploy BHA #1. window milling. RIH with BHA #1. Baker window milling assembly. In Rate = .4 bpm, Out Rate = .7 bpm. In MM = 8.77 ppg, Out MM = 8.38 ppg. IA = 713 psi, OA = 23 psi. WHP = 258 psi. At 8550' circ well to 8.8ppg PowerPro taking oil and gas returns to tiger tank pumping 2 BPM in and getting 1.2 BPM out with 2657psi. pump pressure. Returns routed back inside and confirmed good mud back. Vac out Tiger Tank and freeze protect line. Log CCL from 8275' to get correction with gamma between 8400' and 8500' of 11.5'. Light tag pinchpoint at 8567' corrected, TOW at 8565' P/U 36K S/O 16K. Mill 2.80 window in 3.5 liner per BOT from 8567' md to 8574' md Full exit. Free spin: 2750 psi, 1.50 bpm. Rate: 1.50 bpm in, 1.31 bpm out. Circ pressure: 2877. 2939 psi. Mud weight: 8.80 ppg in, 8.82 ppg out, Window ECD: 10.07ppg. Choke is wide open. Milling rathole 8574'. 8584'. Free spin: 2750 psi, 1.50 bpm. Rate: 1.50 bpm in, 1.35 bpm out. Circ pressure: 2705- 2793 psi. Mud weight: 8.8 ppg in, 8.81 ppg out, Window ECD: 10.09 ppg. Choke is wide open. WOB: 0.7K to 1K. Perform reaming passes with slight motor work increase on passes. Conduct 7 reaming passes until clean. Dry drift is clean, Tag end of rathole at 8588'. IA = 910 psi, OA = 29 psi. Open EDC, POOH keeping 10.0 ppg ECD at window. Rate: 2.76 bpm in, 2.46 bpm out. Circ pressure: 4200. 4600 psi. Mud weight: 8.81 ppg in, 8.81 ppg out, Window ECD: 10.00 ppg. Tag stripper and space out. PJSM on Undeploying BHA. Undeploy BHA #1 window mill. Mill and reamer are 2.81" Go 2.80" NoGo. M/U nozzle and stinger, jet stack. Pressure deploy BHA #2. Build BHA. RIH with BHA #2. Build BHA. In Rate = .6 bpm, Out Rate = .8 bpm. In MM = 8.77 ppg, Out MM = 8.77 ppg. IA = 645 psi, OA = 24 psi. WHP = 526. Log Tie In from 8410' @ 5 fpm. Correct.13'. Close EDC and RIH through window. Drill build section from 8591'. In Rate = 1.8 bpm, Out Rate = 1.5 bpm. In MM = 8.78 ppg, Out MM = 8.79 ppg. Circ pressure = 3331, ECD @ window = 10.39. IA = 719 psi, OA = 25 psi. 10 bph loss rate. Appear to track liner with build BHA. ROP in excess of 150 fph with little WOB. Drill to 8657' and build angle is same as original wellbore. Drop pump rate to 1.5 bpm and attempt to put more weight on BHA. Drill from 8667' with 3.5k WOB. 12/23/2022 Drill build section from 8680' to 8750'. In Rate = 1.5 bpm, Out Rate = 1.4 bpm. In MM = 8.79 ppg, Out MM = 8.8 ppg. Circ pressure = 2961 psi, WOB = 3.13 ROP. 25 fph. Wiper trip to window from 8750'. In Rate = 1.8 bpm, Out Rate = 1.6 bpm. In MM = 8.80 ppg, Out MM = 8.81 ppg. Circ pressure = 3537 psi. 8k overpull noted pulling through window. Open EDC and circulate bottoms up with Lo/High vis sweeps. Correct +2.5'. Close EDC and RIH through window. 1k set down through window. Drill build section from 8750' to 8825'. In Rate = 1.8 bpm, Out Rate = 1.6 bpm. In MM = 8.8 ppg, Out MM = 8.8 ppg. Circ pressure = 3771 psi, WOB = 1.6k to 3.13k. ROP. 25. 100 fph. Land build section at 8825'. POOH for lateral BHA. Pull through window and open EDC. In Rate = 2.7 bpm, Out Rate = 2.2 bpm. In MM = 8.79 ppg, Out MM = 8.84 ppg. Tag up and space out for undeploy. PJSM, Undeploy BHA #2 Build BHA. Remove motor and bit from BHA #2, Break off bit and observe broke nozzle and plugged jet, Grade 1-2. B/D mud motor. P/U and M/U agitator, mud motor with AKO 0.8 and make up new HCC 2.75" X 3" Bi-center bit. PJSM, Deploy BHA #3 Lateral BHA. Tag up, set depth and RIH with BHA #3 Lateral 3.00" BHA. Shallow test agitator @ 300' md, Close EDC Pump at 1.5 to 1.8 BPM and confirm working as designed. Open EDC and continue RIH. Mud weight: 8.80ppg in, 8.82ppg out, ECD at window 10.52ppg with 132 psi on choke. Log down for tie-in F/ 8410' T/ 8481'. with.14' correction. POOH T/ bit depth of 8250' and record CCL log down T/ 8540'. Close EDC, Pass through window with no pump and 5K bobble down. Bring pump up to 0.2 BPM with 1300 psi and RIH T/ 8825'. Drill 3.00" lateral from 8825' MD to 8939' MD, Stop for BU sample. Free spin: 3414 psi, 1.80 bpm. Rate: 1.70 bpm in, 1.57 bpm out. Circ pressure: 3478. 3810 psi. Mud weight: 8.80 ppg in, 8.83 ppg out, Window ECD: 10.45 ppg. ROP: 76 avg fph, WOB: .46. 3.18 KLBS. P/U 35k, S/O 14K reciprocate while Geo catches and determines geology from B/U samples. 373' total drilled from top of window. Geo confirmed B/U samples have shale and the formation is dipped further than projected. Plan is to open hole sidetrack with an anchor billet. POOH with Lateral BHA #3 through window and drift back through window to 8900' since top of Billet will be set at 8795'. POOH with Lateral BHA # 3 P/U 35K S/O 14K. Open EDC Keeping 10.61ppg ECD at window. When pulling through window at min rate observed 5K overpull once, RIH and change pump rate to 0.2 BPM and came right through. PJSM, Undeploy BHA # 3 Lateral BHA. Bit graded 1:1. M/U and pressure deploy 2.625" Baker anchor billet. RIH with BHA #4. Anchor Billet. In Rate = .4 bpm, Out Rate = .3 bpm. In MM = 8.83 ppg, Out MM = 8.84 ppg. Circ pressure = 1431, WHP = 537. IA = 802, OA = 30. Log Tie In from 8410' at 5 fpm. Correct.13' Close EDC and RIH through window. PUW above window = 36k. 8579' Tag with 3.5k down Pick up and see 3k overpull. Pull BHA free. Open EDC and discuss plan forward with Drilling Engineer. POOH for Baker whipstock. 50-029-23255-60-00API #: Well Name: Field: County/State: PBW L-124L1 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 12/25/2022Spud Date: Perform reaming passes with slight motor work increase on passes Milling rathole 8574'. 8584'. Conduct 7 reaming passes until clean. Dry drift is clean Tag end of rathole at 8588'. Milled casing and drilled rat hole are the end of the 10-404. -WCB TOW at 8565' P/U 36K S/O 16K. Mill 2.80 window in 3.5 liner per BOT from 8567' md to 8574' md Full exit All tests witnessed by AOGCC representative Guy Cook 12/24/2022 POOH for whipstock. In Rate = .8 bpm, Out Rate .4 bpm. In MM = 8.8 ppg, Out MM = 8.84 pps. Circ pressure = 1658 psi, WHP = 384 psi. Pressure undeploy BHA #4. Anchor billet. Inspect coiled tubing. Rig maintenance while waiting for Baker whipstock. M/U Baker 3 1/2" x 4 1/2" through tubing whipstock and deploy. RIH W/ BHA #5 Baker 3-1/2" X 4-1/2" through tubing whipstock maintaining 10.60ppg at the window with whipstock oriented at 160 ROHS. Log tie in from 8410', Correct depth. 14'. P/U 33K S/O 15K. Close EDC and RIH T/ Set Gen II Baker Whipstock with TOWS @ 8546' at 160 ROHS P/U to 30K, stop and set WS with bit depth at 8559.30'. Pressure up, WS sheared at 3200psi, Set down 4.5K WOB with no movement. Pull up hole and close EDC. POOH with whipstock setting tool. Window ECD @ 10.60ppg. MW in 8.80ppg at .92 BPM, Out 8.83ppg at .45 BPM. Pulling at 100 FPM. PJSM. Undeploy BHA # 5 Whipstock setting assembly. Crew Change, PJSM, B/D Whipstock setting assembly, M/U and deploy BHA #6 window milling assembly. RIH with BHA #6 2.80" Window milling assembly. Tie-in depth W/ GR @ 5'/min from 8410' depth correction. 14'. RIH to 8482' and close EDC. Lightly tag pinch point at 8547' corrected. P/U 36K S/O 16K. Mill 2.80 window in 3.5 liner per BOT from 8547' md to 8551' MD. Free spin: 2850 psi, 1.50 bpm. Rate: 1.54 bpm in, 1.47 bpm out. Circ pressure: 2877. 3039 psi. Mud weight: 8.80 ppg in, 8.80 ppg out, Window ECD: 10.39ppg. Choke is wide open. WOB: 0.10 to 2K. Mill 2.80 window in 3.5 liner per BOT from 8551' MD. Free spin: 2850 psi, 1.50 bpm. Rate: 1.55 bpm in, 1.46 bpm out. Circ pressure: 2877. 3039 psi. Mud weight: 8.80 ppg in, 8.80 ppg out, Window ECD: 10.33 ppg. Choke is wide open. WOB: 0.10 to 2K. Stall at 8553.3'. Pick up and resume window milling to 8553.7'. Free spin: 2850 psi, 1.50 bpm. Rate: 1.53 bpm in, 1.42 bpm out. Circ pressure: 2877. 3039 psi. Mud weight: 8.80 ppg in, 8.81 ppg out, Window. ECD: 10.30 ppg. Choke is wide open. WOB: 0.10 to 2K. Stall at 8553.7' and continue to work through. Free spin: 2850 psi, 1.50 bpm. Rate: 1.53 bpm in, 1.45 bpm out. Circ pressure: 2877. 3039 psi. Mud weight: 8.80 ppg in, 8.81 ppg out, Window ECD: 10.33 ppg. WOB: 0.10 to 2K. 12/25/2022 Stall at 8553.7' and continue to work through bottom of window. Free spin: 2850 psi, 1.50 bpm. Rate: 1.53 bpm in, 1.45 bpm out. Circ pressure: 2877. 3039 psi. Mud weight: 8.80 ppg in, 8.81 ppg out, Window ECD: 10.33 ppg. WOB: 0.10 to 2K. Attempt to push on it at 8558.9' and stall. Mill through and continue milling rat hole to 8566'. In Rate = 1.6 bpm, Out Rate = 1.6 bpm. In MM = 8.80 ppg, Out MM = 8.80 ppg. Back ream window @ 1 fpm until no motor work observed. Confirm formation sand in bottoms up sample. Dry drift window from 8532' to 8560' and set 7k down. Continue reaming passes until able to drift with no pumps clean. Rat hole milled to 8566'. Open EDC @ 8541' and POOH with window mill assembly. Tag up and RIH 1.4'. PJSM, Undeploy BHA # 6 Window Milling Assembly. L/D BHA #6 with pilot mill and reamer both gauged at 2.80" Go, 2.79" No-Go. M/U swizzle stick and wash BOPE stack. Replace choke B and calibrate same. M/U BHA #7 Build drilling assembly and deploy. RIH with BHA #7 Build section drilling assembly. ECD at window 10.84ppg, MW in 8.80 out 8.83, Flow in .52 bpm out .78 bpm. Tie-in depth W/ GR @ 5'/min from 8410' depth correction. 9'. RIH to 8476' and close EDC. P/U 37K S/O 16K. Pass through window with no bobble or problem. Drill build section F/ 8566' T/ 8683'. In Rate = 1.70 bpm, Out Rate = 1.71 bpm. In MM = 8.81 ppg, Out MM = 8.81 ppg. Free Spin = 3170psi. Circ pressure = 3200 to 3360 psi, WOB = .5 to 2K. ROP. 117 fph. Wiper trip F/ 8683' T/ 8565'. Run back to bottom and continue drilling Build section F/ 8683' T/ 8904'. In Rate = 1.40 bpm, Out Rate = 1.10 bpm. In MM = 8.80 ppg, Out MM = 8.83 ppg. Free Spin = 2710psi. Circ pressure = 2720 T/ 2800psi, WOB = .02 T/ .07K. ROP. 117 fph. No weight on bit and appear to be tracking original hole. Drop pump rate and RIH freely. Confirm we are in original hole with survey. POOH from 8904'. Pull through window clean. Open EDC and continue POOH. POOH for OH sidetrack BHA. In Rate 2.0 bpm, Out Rate = 1.5 bpm. In MM = 8.81 ppg, Out MM = 8.83 ppg. OOH. PJSM and pressure un-deploy build BHA. M/U and pressure deploy OH sidetrack BHA w/1.65 degree motor bend and 2.74" R60 sidetrack bit. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UN BORE L-124 JBR 01/26/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:5 2"x2 3/8" combo test joint used for testing. Test #7 the upper 2" rams failed on a high. Cycle rams and purge air from the system and retested for a fail. Troubleshoot and find Piper valve TV1 to be leaking. Service valve and retest for a pass. Audible for the micro-motion not working. Appears to be a software issue and they are working with techs in town to get it fixed. They will notify when the repair is complete. Test #8 the rams were tested while testing the ram autolocks. The rams failed on a high. Pressured back up the accumulator system and continued the high test for a pass. Worked on autolocks for the 2 3/8" pipe/slips. Replaced the damaged brass wedges and eventually replaced the 2 3/8" pipe/slips as well. Also replaced the 2 3/8" portion of the test joint as it had some fairly deep tong marks that could be contributing to the failure. The 2 3/8" pipe/slips passed with autolocks engaged and pressure bled off of the accumulator. I did not witness the testing for the inside reel valve. Test Results TEST DATA Rig Rep:T. Henson/N. WheelerOperator:Hilcorp North Slope, LLC Operator Rep:R. Burnett/J. Murphy Rig Owner/Rig No.:Nabors CDR2AC PTD#:2050430 DATE:12/21/2022 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopGDC221220062028 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 17.5 MASP: 2738 Sundry No: 322-596 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2"P Annular Preventer 1 7 1/16" 5000 P #1 Rams 1 Blind/Shear P #2 Rams 1 2" Pipe slip FP #3 Rams 1 2 3/8" Pipe sli FP #4 Rams 1 2" Pipe slip P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 2 2 1/16" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA BOP Misc 3 see remarks FP System Pressure P3000 Pressure After Closure P2275 200 PSI Attained P16 Full Pressure Attained P54 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10@1935 ACC Misc NA P PTrip Tank P PPit Level Indicators P FFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 NT Annular Preventer P4 #1 Rams P3 #2 Rams P3 #3 Rams P2 #4 Rams P3 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 FP FP FP F NT passed with autolocks engaged and pressure bled off of the accumulator. I did not witness the testing for the inside reel valve. 2"x2 3/8" combo test joint used for testing. Test #7 the upper 2" rams failed on a high. Cycle rams and purge air from the system and retested for a fail. Troubleshoot and find Piper valve TV1 to be leaking. Service valve and retest for a pass. system and retested for a fail. Troubleshoot and find Piper valve TV1 to be leaking. Service valve and retest for a pass. Audible for the micro-motion not working. Appears to be a software issue and they are working with techs in town to get it fixed. They will notify when the repair is complete. Test #8 the rams were tested while testing the ram autolocks. The rams failed on They will notify when the repair is complete. Test #8 the rams were tested while testing the ram autolocks. The rams failed on a high. Pressured back up the accumulator system and continued the high test for a pass. Worked on autolocks for the 2 3/8" pipe/slips. Replaced the damaged brass wedges and eventually replaced the 2 3/8" pipe/slips as well. Also replaced the 2 3/8" 6HW:KLSVWRFNIRU/DWHUDO 10.11.2022 By Anne Prysunka at 4:11 pm, Oct 11, 2022 'LJLWDOO\VLJQHGE\0RQW\00\HUV '1FQ 0RQW\00\HUVF 86 R +LOFRUS$ODVND//&RX 7HFKQLFDO 6HUYLFHV$.'ULOOLQJ HPDLO PP\HUV#KLOFRUSFRP 5HDVRQ,DPDSSURYLQJWKLVGRFXPHQW 'DWH 0RQW\0 0\HUV '650*52&7'/% ; %23(WHVWWRSVL *&: Jessie L. Chmielowski Digitally signed by Jessie L. 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Development Exploratory Service 5 Permit to Drill Number:205-043 6.50-029-23255-00-00 PRUDHOE BAY, BOREALIS OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10774 10725 6482 8231 9197 None 6348 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" X 34" 31 - 111 31 - 111 2280 770 Surface 3197 9-5/8" 30 - 3227 30 - 2602 5750 3090 Intermediate 8459 7" 26# 28 - 8487 28 - 6465 7240 5410 Production Perforation Depth: Measured depth: 8398 - 10684 feet True vertical depth:6430 - 6481feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# L-80 26 - 8290 26 - 6380 8231 6349Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker Premier Ret. Pkr Liner 2440 4-1/2" 8287 - 10727 6378 - 6482 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 32313104209 4394601 1079 796 1891 345 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brodie Wages david.wages@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907-564-5006 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured6485 Sundry Number or N/A if C.O. Exempt: 320-045 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Install Jet Pump Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028239 PBU L-124 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Jody Colombie at 3:25 pm, Aug 06, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.06 14:33:50 - 08'00' Stan Golis 8/6/2020MGR07AUG2020 RBDMS HEW 8/6/2020 ACTIVITY DATE SUMMARY 7/1/2020 ***WELL S/I ON ARRIVAL, NOTIFY PAD OP & FILL OUT PERMIT*** MAKE MAKE 4 RUNS TO TRY & CUT PARAFFIN BETWEEN 1394' SLM to 1851' SLM, UNABLE TO WORK TOOLS DEEPER, LRS PUMP 1/2 BBL OF CRUDE DOWN TBG & PRESSURE UP TO 2500psi, LRS PUMP HOT CRUDE DOWN IA TO WARM UP TBG RUN 1.98" CENT, WIRE SCRATCHER (13 x 2.35" pins), POCKET POKER (2 x 1.75" pins) TO 3500' SLM, LRS PUMP HOT DOWN TBG RUN 1.98" CENT, WIRE SCRATCHER (13 x 2.75" pins), 2.50" GAUGE RING TO 3500' SLM, LRS PUMP HOT DOWN TBG BRUSH & FLUSH TBG TO 8200' SLM W/ 3-1/2" BLB & 2.80" GAUGE RING ***CONTINUE JOB ON 07-02-20*** 7/1/2020 T/I/O= 1250/1800/50. LRS Unit 72. Assist Slickline with Brush and Flush. Pumped 0.5 bbls of crude into the TBG, It pressured up to 2500 psi. Pumped 226 bbls of 180* F crude into the IA. Pumped 80 bbls of 180* F crude into the TBG while SL brushed. Final T/I/O= 740/60/80. SL had control of the well and DSO notified upon departure. 7/1/2020 T/I/O= 1250/1800/50. LRS Unit 72. Assist Slickline with Brush and Flush. Pumped 0.5 bbls of crude into the TBG, It pressured up to 2500 psi. Pumped 226 bbls of 180* F crude into the IA. Pumped 80 bbls of 180* F crude into the TBG while SL brushed. Final T/I/O= 740/60/80. SL had control of the well and DSO notified upon departure. 7/2/2020 ***CONTINUE JOB FROM 07-01-20, WELL S/I ON ARRIVAL, NOTIFY PAD OP & FILL OUT PERMIT*** SET 3-1/2" X-LOCK CATCHER (OAL = 37") IN X-NIPPLE @ 8174' SLM / 8190' MD, STILL IN WELL PULL 1.5" RK-SOGLV FROM STA #1 @ 8119' SLM / 8132' MD, EMPTY POCKET PULL 1.5" RK-LGLV (16/20 port, 1550# TRO) & SET 1.5" RK-DGLV IN STA #2 @ 7041' SLM / 7056' MD PULL 1.5" RK-LGLV (16/20 port, 1566# TRO) & SET 1.5" RK-DGLV IN STA #4 @ 5355' SLM / 5368' MD PULL 1.5" RK-LGLV (12/20 port, 1536# TRO) & SET 1.5" RK-DGLV IN STA #6 @ 3209' SLM / 3222' MD ***CONTINUE JOB ON 07-03-20*** 7/3/2020 T/I/O= 680/660/10. LRS Unit 72. Assist Slickline (JET PUMP). Pumped 225 bbls of crude into the IA. SL set last dummy valve. MIT-IA to 3000 psi PASSED at 3131 psi (3300 psi max applied pressure). IA lost 73 psi during the first 15 minutes and 15 psi during the second 15 minutes. IA lost a total of 88 psi during the 30 minute test. Pumped 2.69 bbls of 60* F crude to achieve test pressure. Bled back 4 bbls to T/I/O= 707/9/12. SL pulled dummy and set flowsleave. Pumped 50 bbls of crude into the IA, through the sleave at 2.5 bpm and 1000 psi. Final T/I/O= 950/1000/16. HES Slickline had control of the well and DSO notified upon departure. IA/OA are OTG. Daily Report of Well Operations PBU L-124 Daily Report of Well Operations PBU L-124 7/3/2020 T/I/O= 680/660/10. LRS Unit 72. Assist Slickline (JET PUMP). Pumped 225 bbls of crude into the IA. SL set last dummy valve. MIT-IA to 3000 psi PASSED at 3131 psi (3300 psi max applied pressure). IA lost 73 psi during the first 15 minutes and 15 psi during the second 15 minutes. IA lost a total of 88 psi during the 30 minute test. Pumped 2.69 bbls of 60* F crude to achieve test pressure. Bled back 4 bbls to T/I/O= 707/9/12. SL pulled dummy and set flowsleave. Pumped 50 bbls of crude into the IA, through the sleave at 2.5 bpm and 1000 psi. Final T/I/O= 950/1000/16. HES Slickline had control of the well and DSO notified upon departure. IA/OA are OTG. 7/3/2020 ***CONTINUE JOB FROM 07-02-20, WELL S/I ON ARRIVAL, NOTIFY PAD OP & FILL OUT PERMIT*** RUN 1.75" LIB TO STA #2 @ 7041' SLM / 7056' MD, HAVE IMPRESSION OF LATCH SET 1.5" RK-DGLV IN STA #1 @ 8119' SLM / 8132' MD, LRS MIT-IA TO 3000psi, GOOD TEST PULL 1.5" RK-DGLV & SET 1.5" RKP- FLOW SLEEVE IN STA #1 @ 8119' SLM / 8132' MD LRS PUMP 50BBLs OF CRUDE @ 2.5bpm DOWN IA THROUGH FLOW SLEEVE, T/IA/OA = 950/1000/16, GOOD FLOW RATE TEST PULL 3-1/2" X-LOCK CATCHER SUB FROM X-NIPPLE @ 8174' SLM / 8190' MD, EMPTY **JOB COMPLETE, NOTIFY PAD-OP WELL LEFT S/I FOR E-LINE UPON DEPARTURE** 7/4/2020 ***WELL SHUT IN ON ARRIVAL*** (lower patch section - jet pump) SET WEATHERFORD LOWER WIPEPAK LE PACKER MID-ELEMENT AT 8,148', TOP OF SECTION AT 8,146'. BOTTOM OF PACKER 8149'. OAL = 6.9'. MIN ID = 1.81". CORRELATED TO TBG TALLY 13-MAY-2005. ***JOB COMPLETE. WELL SHUT IN ON DEPARTURE*** 7/19/2020 T/I/O = SSV/600/0 Temp - SI. LRS Unit 42 assist DSO with IA. Pumped 10 bbls Neat Meoh into IA. DSO notified upon job completion. SSV/WV/SV (closed), IA/OA (OTG). FWHP's = SSV/485/0 7/26/2020 ****WELL S/I UPON ARRIVAL**** SET UPPER 3 1/2" NS/WFT JET PUMP STRADDLE PACKER (OAL32.53', 2.72"MAX OD MIN ID 0.875" ). @ 8146' MD TOP OF PATCH AT 8114' MD. SHIFT NS/WFD SLIDING SLEEVE IN UPPER STRADDLE PACKER @ 8130' MD. (UP TO OPEN) ***JOB CONTINUED ON 7/27/2020*** 7/26/2020 T/I/O=700/700/20 Temp=SI Assist Slickline (JET PUMP) MIT-IA to XX psi ***PASS*** Target psi=3000 Max Applied psi=3300 Pumped 3.2 bbls crude down IA to take pressure to 3316 psi. IA lost 126 psi in 1st 15 mins and 29 psi in 2nd 15 mins for a total loss of 155 psi in 30 min test. PASS. Bled IA to 500 psi and got back 4 bbls. SL in control of well per LRS departure. FWHP's=700/500/20 IA,OA-OTG **Tags hung on IA 7/27/2020 T/I/O=700/700/20 Temp=SI Assist Slickline (JET PUMP) Pumped 50 bbls crude down IA, up Tbg and down FL to prove jet pump set. Pumped at ~1.36 bpm at 2080 psi. Slickline in control of well per LRS departure. FWHP's=800/800/20 IA,OA=OTG Daily Report of Well Operations PBU L-124 7/27/2020 ***JOB CONTINUED FROM 7/26/2020*** SET 2 3/8" R-LOCK AND NS JET PUMP( G-14) IN UPPER STRADDLE PACKER SLIDING SLEEVE @ 8130' MD. TOP PATCH @ 8114'. ME @ 8118' MD. OAL LENGTH OF STRADDLE PACKER 35.06' (8114' MD - 8149' MD) ***WELL S/I ON DEPARTURE*** THE STATE °fALASKA GOVERNOR MIKE DUNLEAVI Cale Peru Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU L-124 Permit to Drill Number: 205-043 Sundry Number: 320-045 Dear Mr. Peru: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aflaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such filrther time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. SinrPrPly DATED this day of February, 2020. IBDMSK-'�j FE8 0 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 11 u V 411p G'__ 3 'w 3_ L.? h, 075 if3/ZO 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Install Jet Pump 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number 205.043 ' 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6 API Number: 50-029.23255-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU L-124 ' 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028239 PRUDHOE BAY, BOREALIS OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (8): Total Depth TVD(ff): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD)'. Junk (MD): 10774 6485 10725 6482 None 9197 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" X 34" 31 - 111 31 - 111 Surface 3197 9-5/8" 30-3227 30-2602 5750 3090 Intermediate 8459 7" 28-8487 1 28-6465 7240 5410 Production Liner 2440 4-1/2" 8287-10727 6378-6482 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grade: 1 Tubing MD (8): 1 8398-10684 6430-6481 3-1/2" 9.2# L-80 26-8290 Packers and SSSV Type: 3-1/2" Baker Premier Rel. Pur Packers and SSSV MD (ft) and TVD (8): 8231/6348 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 7, 2020 15. Well Status after proposed work: Oil 0 WNJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date. GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name. Pew, Cale be deviated from without prior written approval. Contact Email: Cale.Pew@bp.eom Authorized Name: Peru, Cale Contact Phone: +1 9075644522 Authorized Title: Petroleum Engi Ar Authorized Signature: Date:/ la COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ L1/ Other: 1BDMS±'5-/FEH 0 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No 0 Spacing Exception Required? Yes No KI Subsequent Form Required: �Q „yQ APPROVED BYTHE Approved by: ` COMMISSIONER COMMISSION Date. (� p't Form 10-403 Revised 04/2017 4517,D ORIGINAL Approved application is valid for 12 months from the date of approval. 7. 2r, Submit Form and Attachments in Duplicate 10-403 Sundry Application for Well PBU L-124 PTD #205-043 Expected Start Date: February 7, 2020 Current condition of well: Gas Lift Producer, Operable, Offline: Oil Rate: 209 BOPD Gas Rate: 796 Mscf/Da Water Rate: 4 BWPD Tubing Pressure: 323 psi -Flowing Shut-in Wellhead Pressure: -2000 psi Reservoir Pressure: 2613 psi Program History and Objective(s): L-124 is a low fluid rate, low temp Kuparuk well. It has paraffin issues and has had dozens of HOT's and brush and flushes in the past to keep it online. The objective is to convert this well from gas lift into a jet pumped well. The warmer power fluid should solve the paraffin issue in the tubing and result in an increase of its on-time by warming it up. Proposed Program: 1) B&F. Purpose is to make sure a -line doesn't have issues setting firsts ddle run. 2) Set catcher. Dummy #6,4,2. Load IA. Pull SO/set dmy. MIT -IA to 3000 psi (max power fluid supply pressure = 2300 psi). Pull dmy in #1 and set flow sleeve (SCS -15 with an RKP latch, has 1/2" port at bottom and top of valve) in #1. Pull catcher. 3) Confirm we can pump 2.5 bpm down IA through the flow sleeve (with crude), this is about what our power fluid rate will be. If more than 2100 psi is required to do this pull the flow sleeve and leave the mandrel with nothing in it. IA should be close to fluid packed when we start, 50 bbl of crude should be adequate. 4) Set run #1 of straddle, elements at -8,145'. 5) Set upper straddle (sliding sleeve closed). 6) 2) MIT -IA to 3000 psi (max power fluid supply pressure = 2300 psi). 7) Open sliding sleeve. 8) Set jet pump with check valve at 8127'. Size G-14. 9) Pump -50 bbl's of crude down IA (-2.5 bpm) to confirm we are getting fluid through the jet pump before leaving. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU L-124 PTD #205-043 Current Wellbore Schematic: TREE • OMV WE.LhEAD= FMC ACTUATOR= BAKER KB. ELEV = 76.8 BF. ELEV = 48.38' KOP= 300 Max Angle = 94.08810 D4Wm MD= 8646' Ntw ND= 6600 SS 4-12• TBG. 1288. L-80. 6T ST -M. 0152 bpf. D = 3 958' S rre• C30,404. L-60. -� BT - M, D = 8 835' Minimum ID = 2.813" @ 2016' 3-112" HES X NIPPLE PHSORATION SUMMARY TVD REP LOG MWD LAD ON 05/11105 ANGLE AT TOP PEW. PORTI MleRefer o Production OB for b'st4roal pert data S¢E I S('F I 24TERVAL OWSgZ DATE 412' SLTD 83.9869- - 9102 SLOT 05/12/05 4112' SLID 92 10306 SLOT 0512/05 412' SLTD 10431-10684 SLOT 05112105 3-1/2' TW. 92X, LA. 131-M, F 8290' .0087 bpl. D = 2.992- L-124 SAFETYNOTES: zeu' GAS LFT MAfCRU-S ST_ AD TVD DLIVITYPrl VLV LATCH PORTI DC1E 7 231811990 48 Md(' falx RC 0 11/18/15 6 3122 2598 46 AL1G WAl RC 12 122]115 5 440513397 48 MNG CMI RK 0 05/13105 4 5368 4088 34 MNG DOA£ R( 16 1227/15 3 6217 4]98 34 AL1(' DMI R( 0 06501/05 2 7054 5491 33 AM(- DOW R( 16 1227!15 1 8132 6292 50 MNG So RK 22 M11118 8212' FESGUAGE CAFFZBi w / UBLE TO SUB'ACE MV N, 0=29201 BYIt' 7'%}12'BKA. PRBA PKA D=2.875• 8268' 1-1312!£5% D = 2.813• 8303' I-(7'XSBKRHCLIRHGR1D=443• ` I MELOUr WIDOW(L-124) 8467'-4499 I I fcsrl3cx (aSBr>ro5) 8487 I 9182'_-RATAG FES QSV (05106105) 8500' � ` \1K/\ 10383 bpf, D=6278- FfRFIXtATDN SLIAL4ARY REF LOG'. ANGLEAT TOP F133. 73' 40 8520' ` 10306' RA TAG . 10725' - PUTD FSH TND B• RUBBER919T EL STFFENat Rr4G 11223115) 4-12' LNR, 12 ON, L DR M. 0157 bPf. D = 3.95&' 10727 PRU HOE BAY Ilii V4aL. L-124 PER M4T w `N50130 ARN3 56079-7325500 SM 34, T12K R1 IE 2521' FSL & 1391' FWL BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU L-124 PTD #20S-043 Proposed Wellbore Schematic: 3LWAD= FTC 'F1IAMR- BAI(BtC I ELEV = 768 _ ELEV = 4&3P oP= 300' s Angle= 9PQ881P t m MO -. 8646' twn TVD= 860955 612' TBG. 12 81, L-80, —Cj 6T -- BT-ML 0152 W. D = 7 958' 4518' CSG. 401. L-80, 9227' BT-M,D-8835' 9)x71 3ti Pnn( Minimum 10 = 2.813" @ 2016' ✓t*/kit v+IJ1-' 3412" HES X NIPPLE -PIJ/— g19SStr4Adk-�: �" :{iAi^r :It.Vt. 1 F6FDRATION SU&4%R9 MD I83 LOG'. MAZY LAD ON 05111105 ANGLEAT TOPFEW Pair Note. Refer To Roo=tion DB for S'slacN wtf 4e 1 2318 1990 48 MRM DW W SLID 8398-9102 SLOT 0Y12105 SLTD Ila 9269.10306 SLOT 05/11% SLID 10431-10684 SLOT 05112/05 3-12' TBG, 9.M. 0067 OPf. D - 2.892' 6276' REF LOG'. ANGLEATTOPPEW. 73' 085M L-124 1 --- ...-._. Sr 4-1rz'%O Y1rz'.D•2.99Y 11H6' 1 1171ES %FF.D=2.&1J' 5T MD TVD DEV TYPE VLV LATCH Pair DATE 1 2318 1990 48 MRM DW W 0 11M8n5 6 3222 2598 46 MMi DOME W 12 12/17/15 5 4405 3197 48 MM9 DW W a 0511305 4 5368 4088 34 MAD DOME W 16 12Jr27115 3 6217 4798 34 MSC DMI IN 0 060105 2 7054 5491 33 MM3 DOME FM 16 1227115 1 8132 6292 54 MIO SO W 22 0W16118 CABLE TO SLMACE N N, D - 2.920' 2 813' .TP W I TEIK SLV, D= 2.950' I� 8310' 115'%4-1/2'X0, D=7.9YI ML LOU/AT-IDOW(L-124)8487'-8499 I ` � 9102' fZA r&G 10706' RA TAG 6' 14418887 9197 \ ` ` ` ` 10725FEB & ONE Mx3 (12231/5) \\ DATE FIEV BY COM9AFM5 DATE REV BY 00&lQ:S 05n&VS FBB9 1NTIAL COMPLETION 06119118 G JMD GLV GO (001016) 0120716 0120716 TMJMO FCDIR11 BFfR I(1223Ii F�CZZ GLVGD(1227115) 0125116 JIM'JMD SET PX R -W (0421/16) 0503116 MSS/JM0 KILLED RC PLLIG(05102116) n/(MI/1 I:IK.MI ll• V tRl�il/////�� BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 FF41Lt1DE BAY MT A8L LA24 FEFUT W •1050470 AR W 50-029-2325500 SFC N, T12N R11E 2521' FSL & 1391' F W- BP Rnlnrl nIAM4kxl STATE OF ALASKA py j t OLASKA OIL AND GAS CONSERVATION COMMI 2 4 4 REPORT OF SUNDRY WELL OPERATIO .R 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 2 Exploratory ❑ 5. Permit to Drill Number: 205-043 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-23255-00-00 7. Property Designation (Lease Number): ADL 0028239 8. Well Name and Number: BRLS L-124 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, BOREALIS OIL 11. Present Well Condition Summary: ft i1 „ -�,■V- L 1 V E Total Depth: measured 10774 feet Plugs measured 9031 /9197 feet true vertical 6485 feet Junkmeasured 9197 feet JAN 21 2016 Effective Depth: measured 9031 feet Packer measured 8233 feet true vertical 6484 feet Packer O� .�( _` _ A /�/�/+� true vertical 6349.38 feet {y Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" X 34" 215.5# A 31 -110 31 -110 0 0 Surface 3199 9-5/8" 40# L-80 30-3229 30-2603 5750 3090 Intermediate 9070 7" 26# L-80 28-9098 28-6481 7240 5410 Production Liner 2442 4-1/2" 12.6# L-80 8287-10729 6378-6482 8430 7500 Perforation Depth: Measured depth: 8398-8520 feet 8520 - 8550 feet 8550 - 9031 feet 9031 - 9102 feet 9269 - 10306 feet 10431 - 10684 True vertical depth: 6430-6475 feet 6475 - 6483 feet 6483 - 6484 feet 6484 - 6481 feet 6479 - 6468 feet 6470-6481 Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and See Attachment See Attachment See Attachment true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): X14 Ndllif j i °7(tj LU! Treatment descriptions including volumes used and final pressure: 6Zoz 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 83 533 0 1318 283 Subsequent to operation: 1469 822 64 1348 429 14. Attachments: (required Per 20 AAc 25.070.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations B Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 2 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ 00 11411 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 315-681 Contact Catron, Garry R (Wipro) Email Garry.Catron@bp.com Printed Name Catron, Garry R (Wipro) Title PDC Principal Engineer 1 Signature y ",17 Phone +1 907 564 4424 Date 1/20/16 -.- Form 10-404 Revised 5/2015 3/1��2At'6 RBDMS LL JAN 2 2 2916 EO Submit Original Only 0 Casing / Tubing Attachment BRLS L-124 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20" X 34" 215.5# A53 31 - 110 31 - 110 SURFACE 3199 9-5/8" 40# L-80 30 - 3229 30 - 2603 5750 3090 INTERMEDIATE 9070 7" 26# L-80 28 - 9098 28 - 6481 7240 5410 LINER 2442 4-1/2" 12.6# L-80 8287 - 10729 6378 - 6482 8430 7500 TUBING 43 4-1/2" 12.6# L-80 26 - 69 26 - 69 8430 1 7500 TUBING 8223 3-1/2" 9.2# L-80 69 - 8292 69 1 - 1 6381 10160 1 10530 0 0 Packers and SSV's Attachment BRLS L-124 SW Name Type MD TVD Depscription L-124 TBG PACKER 8232.96 6349.38 3-1/2" Baker Premier Ret. Pkr L-124 PACKER 8298.51 6383.84 5" Baker ZXP Top Packer Daily Report of Well Operations BRLS L-124 ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL*** (Fracturing) UNABLE TO PASS 825' SLM W/ 3-1/2" BRUSH, 2.80" G -RING (Paraffin on tools). RAN 2.50" SAMPLE BAILER TO 850' SLM (Recovered sample of paraffin & hydrates). BRUSH & FLUSH (Hot) FROM SURFACE TO 1,207' SLM W/ 3-1/2" BRUSH, 2.80" G -RING. HEAVY BUILD UP FROM 1,050' TO 1,207' SLM (Still making hole just slowed way down). BRUSH & FLUSH (Hot) FROM 1,206' TO 1,409' SLM W/ 3-1/2" BRUSH, 2.25" G -RING. BRUSH & FLUSH (Hot) FROM 1,409' TO 1,425' SLM W/ 3-1/2" BRUSH, 1.90" G -RING. CURRENTLY FLOWING WELL FORA COUPLE HOURS BEFORE CONTINUING B&F. 11/16/2015 ***JOB IN PROGRESS, CONTINUED ON 11/17/15 WSR*** T/1/0=1964/2017/186 Temp=Sl Assist SSL (Brush & Flush) Pumped 3 bbls of Meth followed by 83 bbls of 180*f DSL down TBG while S/L brushed S/L to flow well to flowline ** JOB CONTINUED 11/16/2015 ON WSR 11-17-15 ** ***CONTINUED FROM 11/16/15 WSR*** (Fracturing) BRUSH & FLUSH (Hot) FROM SURFACE TO 8,350' SLM W/ 3-1/2" BRUSH, 1.90" G -RING. HEAVY PARAFFIN BUILD UP FROM 850' TO 2,500' SLM (Had to flow back twice). DRIFT TO DEVIATION AT 8,543' SLM W/ 2.80" CENT, S-BLR (No sample or issues). SET 2.813" PX PLUG BODY & P -PRONG AT 8,270' SLM / 8,278' MD. SET 3-1/2" WHIDDON CATCHER SUB ON 2.813" PX PLUG AT 8,278' MD. PULL RK-OGLV FROM ST #1 (8,132' MD). PULL RK-LGLV'S FROM ST #2 (7,054' MD), ST #4 (5,368' MD), & ST #7 (2,318' MD). 11/17/2015 ***JOB IN PROGRESS, CONTINUED ON 11/18/15 WSR*** T/I/0= 1000/960/0 Temp=Sl Assist SSL (Pre -Frac) PJSM with SSL & Start barriers list, Called 11/17/2015 off job FWHP= 1000/960/0 T/I/0= 1000/960/0 Temp= S/I Assist SSL MIT -T to 4500 psi ***Inconclusive*** (FRACTURING) Pumped 5 bbls of Meth followed by 325 bbls of 80*f 9.8 Brine down TBG up IA taking returns down FL of L-112. Pumped 17 bbls of DSL down TBG. Let DSL U-tube to FP TBG & IA to 500 ft. Pumped 2 bbls of Meth followed by 14 bbls of DSL down L-112 FL to FP. Pumped .75 bbls 35* diesel down TBG to reach test pressure, Thermal expansion effected test, Test inconclusive continued on 11/18/2015 ***WSR Continued on 11-19-15*** ***CONTINUED FROM 11/17/15 WSR*** (Fracturing) SET RK-DGLV'S AT ST #7 (2,318' MD), ST #4 (5,368' MD), & ST #2 (7,054' MD). SET RKP-FLOW SLEEVE AT ST #1 (8,132' MD). LRS PUMPED 325 BBLS OF 9.8# BRINE DOWN IA TAKING RETURNS OUT TUBING TO L-112. PULL RKP-FLOW SLEEVE FROM ST #1 & SET RK-DGLVAT ST #1 (8,132' MD). LRS CURRENTLY ATTEMPTING TO MIT -T TO 4500 PSI. 11/18/2015 ***JOB IN PROGRESS, CONTINUED ON 11/19/15 WSR*** F-1 L Daily Report of Well Operations BRLS L-124 ***WSR Continued from 11-18-15*** Temp= S/I Assist SSL MIT -T to 4500 psi**"PASSED***on 5th attempt MIT -IA to 4500 psi***PASSED**on 2nd attempt (Pre Frac) Pumped 1.31 bbls of DSL down TBG to establish test pressure for MIT -T to 4500 psi while maintaining 0-5 psi on IA for DP. 1st 15 min TBG lost 20 psi. 2nd 15 min TBG lost 18 psi for a total loss of 38 psi in a 30 min test, *PASS*. Bled back -V.4 bbls from 4495 psi to 2470 psi. Pumped a total of 4.9 bbls of DSL down IA to establish test pressure for MIT -IA to 4500 psi while maintaining a minimum of 2500 psi on TBG. 1 st 15 min IA lost 23 psi. 2nd 15 min IA lost 9 psi for a total loss of 32 psi in a 30 min test, *PASS*. Bled back —2.6 bbls FWHP=461/416/19 SV,WV,SSV,MV=SSL IA,OA=OTG SSL on well upon 11/19/2015 departure Tags hung on WV,IA & MV AFE sign hung on MV Pad -op notified upon departure ***CONTINUED FROM 11/18/15 WSR*** (Fracturing) LRS PERFORMED SUCCESSFUL MIT -T TO 4500 PSI. LRS PERFORMED SUCCESSFUL MIT -IA TO 4500 PSI (2500 psi held on tbg for test). PULL 3-1/2" WHIDDON CATCHER SUB FROM 8257' SLM. PULL P -PRONG & 2.813" PX PLUG BODY FROM 8,270' SLM / 8,278' MD. DRIFT TO DEVIATION AT 8,603' SLM W/ 2.50" x 24' DUMMY GUN (No issues). ***JOB IN PROGRESS, CONTINUED ON 11/20/15 WSR*** ***DRIFT TO 2,200' SLM W/ 2.70" x 20' DUMMY WHIPSTOCK FOR SUBSIDENCE 11/19/2015 SURVEILLANCE*** ***CONTINUED FROM 11/19/15 WSR*** (Fracturing) RIG DOWN SWCP 4516 AFTER SUBSIDENCE SURVEILLANCE DRIFT. 11/20/2015 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** CTU#6 1.75" CT Job Scope: Drift / Perforate / Set IBP / Sand Dump MIRU CTU. MU PDS GR/CCL logging tools w/ 2.50" nozzle and RIH. Tag TD at 10724'ctmd. Log at 60fpm from 10724' up to 8100', paint flags at 8499.6' and 9199.9'ctmd. POOH. Tie-in using SLB Vision Service MDL dated 26 -April -2005, +3' correction. MU 2"x30ft PF HMX perf gun and RIH. Shoot perf interval from 8520-8550'. POOH. 11/25/2015 ***In Progress*** CTU#6 1.75" CT Job Scope: Drift / Perforate / Set IBP / Sand Dump MU & RIH w/ Baker 2.5" IBP (CAL = 11.04'/ 1.38" Fish Neck). Correct depth at flag. Set IBP center element at 9200.1'. Top of IBP at 9197'. Pooh. Flag pipe at 8199.3'e. RIH w/ 2" sand dump BHA. Load well down backside with 113 bbl 1% KCL. Injectivity: 1130 psi @ 1 bpm, 1760 psi @ 3 bpm. Follow KCL with diesel for hydrostatic underbalance. 11/26/2015 ***In Progress*** E 9 Daily Report of Well Operations BRLS L-124 CTU#6 1.75" CT Job Scope: Drift / Perforate / Set IBP / Sand Dump Continue RIH w/ 2" BDJSN. Pumped total of 53 bbl diesel for hydrostatic underbalance. Correct depth at flag. RIH to 9190' (IBP set at 9200'). Pump 3 bbl clean HEC gel + 19.5 bbl 20/40 carbolite slurry (3200 Ib 20/40 Carbolite) + 3 bbl clean HEC gel + 3 bbl KCL spacer + 60/40 displacement. Lay in carbolite slurry from 9190'- 7650'. NOTE: Pumped 3200 Ib of carbolite per program, but extra HEC gel; Pumpers had some trouble with mixing and fluid swap. PUH to Safety. Let carbolite settle out for 1.5 hr. Tag sand top at 8395'. Shallow. Suspect dunes/bridges. Re -tag same depth after settling for another 30 minutes (2 hr total). Pump 23 bbl diesel down CTBS and push sand top down 40' to 8435'. Jet into sand to 8475'. Wait 1 hr, tag sand at 8500'. Jet into sand to 8530', wait 30 mins. Tag sand at 8538'. Jet into sand to 8590', wait 30 mins. Tag sand at 9180' ( — 20' above IBP), majority of sand went out the slots and most likely around the plug. Pump 2nd stage 13 bbl sand slurry (3200 lbs). Wait 1 hr. Tag sand at 9173' ( -V 24' above IBP). Puh and wait another hr. Tag at 9171', same depth. Batch stage #3 and lay in 13 bbl slurry ( —3200 lbs) from 9150'- 8290'. Wait 1 hr. Dry tag at 9040'. Start pulling heavy at 8584'. Have to pump down coil to get out of. Puh to safety and wait 1 hr. 11/27/2015 ***In Progress*** • Daily Report of Well Operations BRLS L-124 CTU#6 1.75" CT Job Scope: Drift / Perforate / Set IBP / Sand Dump Continue RIH w/ 2" BDJSN. Pumped total of 53 bbl diesel for hydrostatic underbalance. Correct depth at flag. RIH to 9190' (IBP set at 9200'). Pump 3 bbl clean HEC gel + 19.5 bbl 20/40 carbolite slurry (3200 Ib 20/40 Carbolite) + 3 bbl clean HEC gel + 3 bbl KCL spacer + 60/40 displacement. Lay in carbolite slurry from 9190'- 7650'. NOTE: Pumped 3200 Ib of carbolite per program, but extra HEC gel; Pumpers had some trouble with mixing and fluid swap. PUH to Safety. Let carbolite settle out for 1.5 hr. Tag sand top at 8395'. Shallow. Suspect dunes/bridges. Re-tag same depth after settling for another 30 minutes (2 hr total). Pump 23 bbl diesel down CTBS and push sand top down 40' to 8435'. Jet into sand to 8475'. Wait 1 hr, tag sand at 8500'. Jet into sand to 8530', wait 30 mins. Tag sand at 8538'. Jet into sand to 8590', wait 30 mins. Tag sand at 9180' ( — 20' above IBP), majority of sand went out the slots and most likely around the plug. Pump 2nd stage 13 bbl sand slurry (3200 lbs). Wait 1 hr. Tag sand at 9173' ( — 24' above IBP). Puh and wait another hr. Tag at 9171', same depth. Batch stage #3 and lay in 13 bbl slurry ( —3200 lbs) from 9150'- 8290'. Wait 1 hr. Dry tag at 9040'. Start pulling heavy at 8584'. Have to pump down coil to get out of. Puh to safety and wait 1 hr. RIH, performing frequent clean weight checks from 8200 - 9000'. Dry tag at 9031'. PUH. Pull heavy again at 8636'. Took 1 hr to work through. Heel of well; 85 deg inclination, 16 deg DLS. Carbolite is duning up in heel of well. Call ANC PE; call this good. POH. FP well with 23 bbl 60/40. Perform injectivity test. Did not re-tag sand top after injectivity test due to risk of getting stuck. RDMO. ***Have —170' solid carbolite above IBP (hard sand top at 9031'), and dunes of carbolite in heel of well around 8600'. Injectivity: 1 bpm @ 1350 psi, 2 bpm @ 2000 psi*** 11/27/2015 ***Job Complete*** Heat upright of fresh water to 100* (Fracturing) Job cancelled, Vac truck to off load upright and 12/2/2015 upright to be moved for different job ****WELL S/I ON ARRIVAL**** (fracturing) RIG UP SWCP 4519 12/7/2015 ***CONTINUE ON 12/8/2015*** T/1/0=200/91/35. Injectivity test. (Pre frac) Pumped 150 bbls dsl at 6 bpm @ 2500-2600 psi. (see 12/8/2015 log). Monitor TP for 1 hour FWHP=800/0/10 Casing valves OTG. S-Line on location upon departure ***CONTINUE FROM 12/7/2015*** RAN 3-1/2" X-LINE DRIFT FOR CORRECTION ON LOWEST X NIPPLE AT AT 8,265' SLM 8,278' MD, GET 13' CORRECTION DRIFTED W/ 11' x 2" DUMMY WHIP STOCK & 1-1/2" SAMPLE BAILER 8,540' SLM (corrected to 8,553' MD) WITH NO ISSUES. RUN SLB MEMORY P/T/GR/CCL AS PER PROGRAM (DATA GOOD) 12/8/2015 ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** EJ 0 Daily Report of Well Operations BRLS L-124 Assist Frac (FRACTURING) 12/10/2015 Rolled 4 out of 6 frac tanks. All tanks @ Temp. **** Job continued on 12/11/15 **** ***SLB Frac Crew*** Job Scope: Single Stage Fracture Treatment in Kuparulk C Sands <<< InterAct Publishing >>> Rig up SLB frac equipment. Performed equipment testing per GP 10-45 Pressure Testing CRT. Shut down for day due to field wide communications blackout. 12/11/2015 <<<In Progress>>> ***Job continued from 12/10/15 WSR*** LRS roll frac tanks/Heat LVT to 80* F. Assist SLB with Frac. 12/11/2015 **** Job continued on 12/12/15 **** ***SLB Frac Crew*** Job Scope: Single Stage Fracture Treatment in Kuparulk C Sands <<< InterAct Publishing >>> Rig up SLB Pod to frac equipment. LRS holding 3000 psi on IA. Inj test. Pump Data Frac. Pump Proppant Fracture Stage per below. Total of 196,000 lbs 16/20 carbolite behind pipe. 1200 lbs left in liner (2 bbls). Proppant Frac Stage: Pumped 201,000 lbs 16/20 Carbolite into open heel perfs at 150 bbls YF128FlexD Pad 100 bbls 0.5 PPA Scour 150 bbls Pad 50 bbls 1 PPA 16/20 Carbolite YF128FlexD 50 bbls 2 PPA 50 bbls 3 PPA 50 bbls 4 PPA 50 bbls 5 PPA 90 bbls 6 PPA 90 bbls 7 PPA 100 bbls 8 PPA 100 bbls 9 PPA 125 bbls 10 PPA 70 bbls 11 PPA 82 bbls 12 PPA 56 bbls Flush of WF128FIexD 20 bbls FP of LVT (2 bbl under flush) 12/12/2015 RDMO. 10 9 Daily Report of Well Operations BRLS L-124 ***Job continued from 12/11/15 WSR*** Assist Frac (FRACTURING) Heated and circulated LVT transport to 80* F. Pumped a total of 2 bbls diesel down IA and maintained 3000 psi during Frac. Bled IAP down to 0 psi. RDMO. SLB Frac crew in control of well upon LRS departure. IA/OA OTG 12/12/2015 AL closed FWHP=0/0/0 LRS Test Unit 1 IL well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback 12/18/2015 Test***Rig Up. SB for Slickline***Continue to WSR 12/19/15*** LRS Test Unit 1Inlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback 12/19/2015 Test***Continue from WSR 12/18/15***Rig Up. Scheduling SB ***Continue to WSR 12/20/15*** CTU#6 1.75" CT Job Scope: FCO / Pull IBP (Post Frac) MIRU CTU. 12/20/2015 ***In Progress*** LRS Test Unit 1lnlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback 12/20/2015 Test***Continue from WSR 12/19/15***Rig Up/PT Scheduling STBY***Continue to WSR 12/21/15*** LRS Test Unit 1lnlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback 12/21/2015 Test***Continue from WSR 12/20/15 ***Assist CTU***Continue to WSR 12/22/15*** 12/21/2015 LRS T-104 Fluid Support CTU#6 1.75" CT Job Scope: FCO / Pull IBP (Post Frac) MU & RIH w/ 1.75" JSN. Tag at 1057'. Jet thru ice plug. Continue rih circulating out frac fluids. Tag fill at 8470'. Getting 1:1 returns prior to starting clean out. FCO from 8470' to 8607'. Start seeing losses. Reduce pump rate & try to achieve 1:1 returns. Attempt 1.1 bpm, but unable to carry fill out of horizontal section of well efficiently with gel sweeps. Increase rate to 2bpm with —80% returns and first gel pill plugged up ASRC. Swapped to OTT through 2" hardline and started getting 25% returns. POOH to determine new plan forward. Order diesel transports. RBIH w/ 1.75" JSN. Park at 8200'& circulate well to diesel to underbalance. Dry tag at 8434'. FCO with gel sweeps from 8434' to 8750'. Have to pump small sweeps to keep from overbalancing well. 12/21/2015 ***In Progress*** 0 40 Daily Report of Well Operations BRLS L-124 CTU#6 1.75" CT Job Scope: FCO / Pull IBP (Post Frac) Continue FCO from 8750' to 9191' and tagged IBP. Chase up inside 3-1/2" tubing & circ btms up. From 8000', dry drift down to IBP clean at 9190'. Pooh while pumping pipe disp. MU BKR hyd centralizer w/ hyd overshot (1.375" grapple). RIH and tag down on IBP at 9202'. Make multiple attempts to latch IBP with no success (see log for details). POOH pumping pipe displacement. Inspect fishing BHA and found a small amount of proppant, gel and silt -like material behind the grapples. Clean debris out and MU same overshot. RIH and pump min rate at 8050' down to tag at 9206'. PUH 33k and wt broke over, wait for elements to relax. Attempt to pooh, pull heavy at 8770' (93 degrees). Unable to pull IBP out. Pump 5 bbl gel pill and circulate to surface. Re-engage IBP at 8882' ctm. Pull heavy at 8778', unable to pull thru. While in tension pump min -rate to not release from IBP taking 1:1 returns. Able to slowly move up hole. Pull heavy at 8285' (Tbg Tail). Plug starts moving, pull tight & get wedged at 8272' (x -nipple). Able to pull free, see over -pulls pulling thru jewelry. Pooh. 12/22/2015 ***In Progress*** 12/22/2015 LRS T-104 / T-106 Fluid Support LRS Test Unit 1 Inlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback Test***Continue from WSR 12/22/15 ***Assist CTU, SB for slickline***Continue to WSR 12/23/2015 12/24/15*** CTU#6 1.75" CT Job Scope: FCO / Pull IBP (Post Frac) Recover IBP. Lost two 6" Rubber Elements & one 1" Stiffener Ring. Did not perform FCO to PBTD due to no gaslift valves set in well yet. Will turn over to Slickline and ASRC. RDMO. 12/23/2015 ***Job Complete*** ***JOB IN PROGRESS, CONTINUED FROM 12/23/15 WSR***(post-frac). DRIFT WITH 2.80" CENT & 1.75" SAMPLE BAILER TO 8,500' SLM SET 3-1/2" X -SELECTIVE TOOLAT 8,191' MD PULL DUMMY GLV FROM STA.#1 @ 8,132' MD AND STA#2 @ 7054' MD 12/24/2015 ***CONT WSR ON 12/25/15*** LRS Test Unit 1 Inlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback 12/24/2015 Test***Continue from WSR 12/23/15 ***SB for slickline***Continue to WSR 12/25/15*** ***CONT WSR FROM 12/24/15*** (fracturing) PULL RK-DGLV FROM STA44 AT 5,368' MD PULL RK-DGLV FROM STA46 AT 3,222' MD SET RK-LGLV (12/64", 1,536 psi) IN STA46 AT 3,222' MD SET RK-LGLV (16/64", 1,566 psi) IN STA.#4 AT 5,368' MD 12/25/2015 ***CONT WSR ON 12/26/15*** LRS Test Unit 1 Inlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback 12/25/2015 Test***Continue from WSR 12/24/15 *** Slick line installing GLV***Continue to WSR 12/26/15*** i Daily Report of Well Operations BRLS L-124 ***CONT WSR FROM 12/25/15*** SET RK-LGLV (16/64"/1,550 psi) IN STA42 AT 7,054' MD ATTEMPT TO SET RK-OGLV (20/64") IN STA.#1 AT 8,132' MD SET RK-OGLV (20/64") IN STA.#1 AT 8,132' MD ATTEMPT TO PULL 3-1/2" X-SELECTIVE TOOLAT 8,191' MD (heavy sand in gr) RAN 10'x 2.25" PUMP BAILER TO 8,191' MD (.725 gal cement/sand recovered) RAN 10'x 2.25" PUMP BAILER TO 8,191' MD ( 1 gal cement/sand recovered) 12/26/2015 ***CONT WSR ON 12/27/15*** LRS Test Unit 1 Inlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback 12/26/2015 Test***Continue from WSR 12/25/15 ***Slick line installing GLV***Continue to WSR 12/27/15*** ***CONT WSR FROM 12/26/15*** RAN 10' x 2.25" PUMP BAILER TO 8,191' MD (recover —1 cup sand) PULL 3-1/2" X-SELECTIVE TOOL FROM 8,191' MD 12/27/2015 ***WELL S/I ON DEPARTURE*** LRS Test Unit 1 Inlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback Test***Continue from WSR 12/26/15 ***Slick line installing GLV,Pop/Flow Well***Continue to WSR 12/27/2015 12/28/15*** LRS Test Unit 1 Inlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback Test***Continue from WSR 12/27/15 ***Continue to Flow/ Stabilize Well, Begin 8 Hr Piggyback 12/28/2015 Test. ***Continue on WSR 12/29/15*** LRS Test Unit 1 Inlet well L-124, OL well L-112. Assist CT Post Frac FCO / Flowback / Piggyback Test***Continue from WSR 12/28/15 *** Complete 8 Hr Piggyback Test, Perform 4 Hr Piggyback Test, Perform 12 Hr Piggyback Test. Continue to Flow Well. S/I Well, Begin Blow down, Additional 12/29/2015 Test data on upcoming WSR's. ***Continue on WSR 12/30/15*** LRS Test Unit 1. Assist CT Post Frac/ Flow back/ Piggyback Test. *** Continued from WSR 12/29/15 *** Continue Rig Down, Vessel Flush, Unit Move to Washbay for Vessel Cleanout, L-124 12/30/2015 12 Hr Piggyback Test Data. Inlet Well L-124. Outlet Well L-112. *** Job Complete *** n `J rt of Well Operations BRLS L-1 is Fluids Summary Bbls Type 1434 Diesel 16 Methanol 8 Neat Methanol 13 Crude 325 9.8 Brine Water 349 60/40 Methanol/Water 218 1% KCL 20 Clean HEC Gel 47 20/40 Carbolite in HEC Gel Sand Slurry 275 Fresh Water 150 LVT Heated 799 1 % Slick KCL + SafeLube 142 PowerVis is TREE = aw WELLHEAD= FMC ACTUATOR = BAKER C KB. ELEV = " - _ _ 76.8 BF. ELEV = 48.39 KOP = 309 Max Angle = 94 @ 8810' Datum ND = 8646 Datum TVD= 6600' SS * LA24 44L—TBG, 12.6#, L-80, 67• BT -M, .0152 bpf, D = 3.958" 9-5/8" CSG, 40#, L -81--i3221 BT -M, D = 8.835" Minimum ID = 2.813" @ 2016' 3-1/2" HES X NIPPLE PERFORATION SUMMARY REF LOG: MWD' LWD ON 05/11/05 ANGLE AT TOP PERF: Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLTD 8398 - 9102 SLOT 05/12/05 4-1/2" SLTD 9269 - 10306 SLOT 05/12/05 4-1/2" SLTD 10431 - 10684 SLOT 05/12/05 3-1/2" TBG, 9.2#, L-80, BT -M, 1-1 829W .0087 bpf, D = 2.992" BKR WHIPSTOCK (05/06/05) 1-{ "87- FES 487 HES EZSV (05/06/05) 1--1 8500- 7- CSG, 26#, L-80, BTC -M, 9097- .0383 bpf, D = 6.276 " PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 73° @ 8520' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL I Opn/Sqz I SHOT SOZ 2" 6 8520 - 8550 1 O 11/25/15 SAW NOTES: 67' 4-112" XO 3-1t2", D = 2.992" 201 s, GAS 1 IF f MA KFV:?R S ST MD TVD DEV TYPE I VLV LATCHI FORTJ CiATE 7 2318 1990 48 MMG DMY RIC 0 11/18/15 6 3222 2598 46 MMG DOME RK 12 12/27/15 5 4405 3397 48 MNG DMY RK 0 05/13/05 4 5368 4088 34 MMG DONE RK 16 12/27/15 3 6217 4798 34 MNG DMY RK 0 06/01/05 2 7054 5491 33 NMC DONE RK 16 12/27/15 1 8132 6292 54 MNG SO RK 20 12/27/15 8191' 3-112" HES X NIP, D = 2.813" 8212' -j HES GUAGE CARRIER 11 w / CABLE TO SURFACE IN IA, ID= 2.920" 8231' 7" X 3-112" BKR PREM PKR, D = 2.875" 8258' 1--13-1/2- HES X NP, D = 2.813- 8278' (-( 3-1/2" HES X NP, D = 2.813" 8285' --j 7" X 5" BKR ZXP LTP w / TEBK SLV, D = 4,440" 8290' 3-1/2" WLEG, K)—= 2.950" 8303' 7" X5" BKR HMC LNR HGR D = 4.43" I I MLLOUT WINDOW (L-124) 8487--849T I I I � I � 7107,25' RA TAG FISHTWq 6" RUBBER 9197 PBTD ELEMENT'S & ONE STIFFENER RING (12/23/15) LNR, 12.6#, L-80 BT -M, .0152 bpf, D= 3.958" DATE REV BY COMMENTS DATE I REV BY COMMENTS 05115/05 N9ES INITIAL COMPLETION 01/20/16 TTR1JMD FCO/PULL BP1FISH(12/23/15) 06/01/05 MG'S/PJC GLV GO 01/20/16 RCT/JMD GLV GO (12/27/15) 03/05/07 MWS/PJC DRLG DRAFT CORRECTIONS 12/14/10 CSRIPJC LEGEND+ TREE CORRECTIO 11/24/15 RJKIJA+D GLV :JO (11118/1 12/02/15 TFA/JMD ADPERFlSET BPISAND SEC 34, 10727 PRUDHOE BAY LIMIT WELL: L-124 PERMIT No: 12050430 AR No: 50-029-23255-00 T12K R11 E, 2521' FSL 8 1391' FWL BP Exploration (Alaska) C� Schlumberger FracCAT Treatment Report Well L-124 Field Aurora Formation : Kuparuk C Well Location Greater Prudhoe Bay State :Alaska Country : United States Prepared for Client BP Exploration Alaska Client Rep : Jack Lau Date Prepared :12 -Dec -2015 Prepared by Name : Michael Hyat Division Schlumberger Phone 770 597 6685 0 Initial Wellhead Pressure (psi) Pressures 455 Maximum Treating Pressure (psi) 6,202 Final Surface ISIP (psi) 2,675 DataFRAC ISIP (psi) 1,880 Surface Shut in Pressure(psi) 2,450 Total Slurry Pumped Treatment 1 790 Totals Total Proppant Pumped (lbs.); From Load 201,360 (Water+Adds+Proppant) (bbls) Tickets Total WF128 Past Wellhead (bbls) 241 Total Proppant in Formation (lbs.) 200,372 Total YF128FIexD Past Wellhead (bbls) 1,340 Total Freeze Protect Past Wellhead 17 bbls Total Chemical Additives J957 (mgal) 56,273 56,273 J475 (lb) 578 578 F103 (gal) 67 67 J134 (lb) 14 0 L065 (gal) 75 75 M002 (lb) 58 58 L071 (gal) 131 131 J604 (gal) 145 145 M275 (Ib) 36 27 Freeze Protect 0 17 B882 (gal) 417 399 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. 9 Schlumberger Executive Summary C] Client: BP Exploration Alaska Well: L-124 Formation: Kuparuk C District: Prudhoe Bay Country: United States Loadcase: Acq Load Case The pump schedule for L-124 was changed several times during the days leading up to the treatment. That included an increase in pump rate from 20bpm to 40bpm, as well as reducing the maximum proppant concentration from 12 to 11 PPA as well as going to a gentler proppant ramp. Especially the rate change required the addition of a 61h pump, which was done on the planned day of thejob (11 Dec). The field crew had spotted the equipment in a manner that allows pumping the treatment at 40bpm. At the beginning of the year, this had not been the case on another well, where wellsite limitations required the Sand Chief to be spotted perpendicular to the POD and led to undesired consequences. The lesson learnt from that wel I was implemented on L-124. The fracturing treatment for L-124 was performed over a two day period, December 1111 and 1211, On the first day, the rig -up had to be completed before starting the job. The low ambient temperature made the pressure test difficult, as pressure dropped due to thermal contraction of the LVT in the line. It took several hours to pass our pressure test. Once the pressure test was completed, we were forced to shut down for the day due to cell phone and harmony system failure. On 12 Dec. the crew arrived to location at 7am, and we continued to experience delays due to the harmony system. Once all issues were resolved, a DataFRAC was performed. Pressure decline was slow, indicating high fluid efficiency and Schlumberger and BP engineers agreed to proceed with the designed pump schedule, Depending on the pressure response of the 0.5PPA proppant scour, a possible sweep after the IPPA stage was discussed, and potentially going to 12PPA for the last 50 bbl of the job. As pressure remained unchanged when the 0.5PPA step hit the formation, no sweep was pumped and we did pump 12PPA for about the last 60 bbl of the 11 PPA step. For the job the proppant concentration calculation was set up for 40bpm operations, which considers an average of both sides of the blender. During the 0.5PPA scour this led to higher reading than actual being displayed (2.5PPA). The set up was corrected and the proppant ramp tracked well with the actual amount of proppant pumped. The proppant Concentration during the scour was revised for this report and shows the correct 0.5PPA. During the treatment pump rate had to be reduced from 30bpm in steps to 24bpm as treating pressure rose due to proppant friction. This was anticipated ahead of the treatment and discussed with BP and the field crew, which did a good job staying below the maximum allowable pressure, while pumping the treatment to completion as per design, C� • Schlumberger Welk BP Exploration Alaska Well, L-124 Formation. Kuparuk C District: Prudhoe Bay Country, United States Loadcase,Acq Load Case Section 1: DataFRAC: As Measured Pump Schedule Ste # p Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume Proppant Name (gal) Prop Conic (PPA) (PPA) Prop (PPA) Prop Mass (lb) 1 Pump Check 135.3 24.3 6.7 WF128 5682 0.0 0.0 0 2 Calibration 73.5 24.9 3.6 YF128FIexD 3084 0.0 0.0 0 3 Calibration 150.0 30.1 5.0 YF128FlexD 6300 0.0 0.0 0 4 Displacemen 531 30.0 1.9 WF128 2229 0.0 0.0 0 5 Shut Down 0.0 15 3 00 WF128 -0 00 0.0 0 Step # Step Name Stage Pressures : Rates Average Slurry Maximum Slurry Average Treating Rate Rate Pressure (bbl/min) (bbl/min) (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Pump Check 24.3 29.5 4616 5755 440 2 Calibration 24.9 30.1 3635 4324 607 3 Calibration 30.1 1 30.2 1 4612 14656 1 4327 4 Displacement 30.0 30.2 4608 4713 55 5 Shut Down 15.3 0.0 2985 906 55 Average Treating Pressure: 4443 psi Maximum Treating Pressure: 5755 psi Minimum Treating Pressure: 55 psi Average Injection Rate: 27.3 bbl/min Maximum Injection Rate: 30.2 bbl/min Average Horsepower: 3006.9 hhp Maximum Horsepower: 3923.8 hhp Maximum Prop Concentration: 0 0 PPA • Schlumberger • Client: BP Exploration Alaska Well: L-124 Formation: Kuparuk C District, Prudhoe Bay Country, United States Loadcase Acq Load Caso Section 2: Main Treatment: As Measured Pump Schedule Step # Step Name Stage Average Slurry Rate (bbl/min) Pressures & Rates Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) As Measured Pump Schedule PAD 27.9 30.3 4905 Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (Ib) 1 PAD 150.0 27 9 61 YF128FlexD 6300 29.6 00 0.0 0 2 5 PPA 102.2 298 3.4 YF128FlexD 4107 CarboLite 16/20 0 5 0.2 771 3 PAD 1 150.0 30 2 1 5.0 YF128FlexD 6387 300 00 1 0.0 0 4 1.0 PPA 50.0 296 1.7 YF128FlexD 2055 CarboLite 16/20 10 0.1 1651 5 2.0 PPA 50.0 29 3 1.7 YF128FIexD 1975 CarboLite 16/20 2.0 1 2 3701 6 3.0 PPA 49.8 295 1.7 YF128FIexD 1882 CarboLite 16/20 3.0 0.4 5381 7 4.0 PPA 49.4 294 1.7 YF128FlexD 1792 CarboLite 16/20 4.0 2 6 6967 8 5.0 PPA 50.0 291 1.7 YF128FlexD 1758 CarboLite 16/20 5.1 2 5 8612 9 6.0 PPA 89.6 291 3.1 YF128FIexD 3050 CarboLite 16/20 6.1 3 3 18113 10 7.0 PPA 90.1 290 3.1 YF128FIexD 2903 CarboLite 16/20 7.7 1 1 1 20240 11 8.0 PPA 99.9 27.3 3.7 YF128FIexD 3272 CarboLite 16/20 8.3 4 2 25814 12 9.0 PPA 100.0 27.1 3.7 YF128FIexD 3141 CarboLite 16/20 9.4 1.7 28096 13 10.0 PPA 125.0 25.8 4.8 YF128FIexD 3720 CarboLite 16/20 102 2.6 37027 14 11.0 PPA 149.5 24 5 6.1 YF128FIexD 4547 CarboLite 16/20 124 0.0 44837 15 WF Flush 53.0 22.6 2.4 WE] 28 2192 0.0 0.0 0 16 Freeze Prote 20.0 8 4 2.7 Freezeprotect 840 0.0 00 0 Step # Step Name Stage Average Slurry Rate (bbl/min) Pressures & Rates Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 PAD 27.9 30.3 4905 5614 906 2 5 PPA 29.8 302 4958 5026 4881 3 PAD 30.2 302 5060 5087 5015 4 1.0 PPA 29.6 30.2 4967 5086 4909 5 2.0 PPA 29.3 29.6 4948 5016 4917 6 3.0 PPA 29.5 29.7 5102 5204 5017 7 4.0 PPA 29.4 300 5309 5430 5203 8 5.0 PPA 29.1 30 1 5531 5658 5429 9 6.0 PPA 29.1 302 5825 5981 5661 10 7.0 PPA 290 29.9 5951 6094 4760 11 8.0 PPA 27 3 28.7 5902 6202 4822 12 9.0 PPA 27.1 280 6106 6187 5817 13 10,0 PPA 25.8 26,7 5986 6142 5816 14 11 0 PPA 24 5 257 6006 6194 5728 15 WF Flush 1 22.6 23.7 5198 5846 3670 16 Freeze Protect 1 8 4 15.9 3018 3681 2519 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (al) (Ib) 1378.5 526 49086 201,210 Client: BP Exploration Alaska Schlumberger Well: L-124 Formation: Kuparuk C District: Prudhoe Bay Country: United States Loadcase: Acq Load Case Average Treating Pressure: 5462 psi Maximum Treating Pressure: 6202 psi Minimum Treating Pressure: 906 psi Average Injection Rate: 27.6 bbl/min Maximum Injection Rate: 30.3 bbl/min Average Horsepower: 3702.7 hhp Maximum Horsepower: 4410.0 hhp Maximum Prop Concentration: 12.4 PPA Schlumberger Section 3: Job Messages Day 1; Pressure Test Client, BP Exploration Alaska Well, L-124 Formation, Kuparuk C District, Prudhoe Bay Country: United States Loadcase:Acq Load Case Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl)(bbl/min) Slurry Rate Prop. Conc. (PPA) 1 7:00:00 Arrived on location 0 2 9:50:53 Started Acquisition 0 3 13:54:16 Started Recording 1 4 13:58:02 safety meeting 1 -7 109 0 0 5 13:58:17 gate checks 1 -8 109 0 0 6 14:02:14 prime up pod 1 -8 108 0 0 7 14:04:50 warm lines 1 -7 108 0 0 8 14:08:33 pump trips set to 500 1 16 108 0 0 9 14:16:43 pump 1 primed up and trip test 1 67 108 0 2.6 10 14:23:54 pump 2 primed up and trip tested 1 61 107 0 1.4 11 14:26:38 pump3 primed and trip tested 1 62 108 0 1.8 12 14:28:58 pump 4 primed and trip tested 1 72 108 0 1.1 13 14:31:10 pump 5 primed up and trip tested 1 71 107 0 4.3 14 14:44:54 working on p mp 2 oiler air line 1 66 107 0 2.1 15 14:55:09 pump 2 primed and trip tested 1 64 107 0 0 16 15:05:00 Global trip tested 500 1 424 107 0 0 17 15:07:46 Low pressure stall 1 1533 107 0 0 18 15:49:53 checking valves operations on stinger 1 34 104 0 0 19 16:38:58 Remark 1 1479 102 0 0 20 16:49:46 low pt good 3 psi loss in 5 min 1 402 101 0 0 21 16:52:03 check valve test 4,000 psi good 1 4022 101 0 0 22 16:55:36 qlobal trip test 5k good 1 5263 101 0 0 23 17:05:04 High PT Loss 206 psi in 5 min PASS 1 8065 101 0 0 24 17:13:33 Client delays job pending emergency phone service restored 1 910 101 0 0 25 17:26:56 Remark 1 1031 101 0 0 26 17:30:20 arming surfacing equipment 1 65 101 0 0 27 18:07:43 client delays job until emergency service 1 54 100 0 12.1 28 18:07:54 -repaired fanning surface equipment 1 53 101 0 6.3 29 18:11:10 R cording 0 61 1 101 0 4.3 30 18:11:13 _Stopped Stopped Acquisition 0 61 1 101 0 4.3 Schlumberger Day 2; Main Treatment 11 Client, BP Exploration Alaska Well, L-124 Formation, Kuparuk C District Prudhoe Bay Country, United States Loadcase Acq Load Case Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 7:01:14 Arrived Location 0 0 0 0 0 2 7:45:32 PCM and LAS rigged up 0 0 0 0 0 3 14:32:40 Start PAD Automatically 1112 2827 0 0.1 0 4 14:32:40 Start Propped Frac Automatically 1112 2827 0 0.1 0 5 14:34:49 Stage at Perfs: Calibration 5148 2923 31.2 29 0 6 14:36:34 Stage at Perfs: Shut Down 5296 2997 83.6 30.2 0 7 14:37:25 zero on pad 8.3 4887 3026 109.3 30.2 0 8 14:38:47 Start.5 PPA Automatically 4935 3029 150.1 29.6 0 9 14:38:47 Started Pumping Prop 4935 3029 150.1 29.6 0 10 14:40:22 Stopped Pumping Prop 4985 2977 196.9 29.9 1.8 11 14:41:36 Stage at Perfs: PAD 5002 3029 234.1 30.2 0 12 14:42:13 Start PAD Automatically 5008 2964 252.7 30.2 0 13 14:44:57 at Perfs: .5 PPA 5069 2984 335.1 30.1 0 14 14:47:11 _Stage Start 1.0 PPA Automatically 5061 2999 402.5 30.2 0 15 14:47:28 Started Pumping Prop 5054 3001 411 30.3 0 16 14:48:52 Start 2.0 PPA Automatically 4921 2973 452.2 29.5 1 17 14:49:59 Stage at Perfs: PAD 4960 2992 485 29 2.1 18 14:50:35 Start 3.0 PPA Automatically 5036 3006 502.5 29.3 1.9 19 14:51:41 Sta eat Perfs: 1.0 PPA 5133 3021 534.9 29.5 3 20 14:52:16 Start 4.0 PPA Automatically 5219 2985 552 29 3 21 14:53:15 pH 10 3 ppa 5305 2977 580.9 29.4 4 22 14:53:24 Stage at Perfs: 2.0 PPA 5346 2980 585.3 29.1 4 23 14:53:57 Start 5.0 PPA Automatically 5436 2986 601.6 30.1 4 24 14:55:04 Stage at Perfs: 3.0 PPA 5539 3001 634.3 29 5 25 14:55:40 Start 6.0 PPA Automatically 5681 3007 651.6 29.4 5 26 14:56:47 Sta e at Perfs: 4.0 PPA 5788 3003 684 29.9 6 27 14:58:30 _Stage at Perfs: 5.0 PPA 5969 3010 734 28.7 6 28 14:58:45 Start 7.0 PPA Automatically 6000 3013 741.2 29.7 6 29 15:01:38 Stage at Perfs: 6.0 PPA 5424 2978 825.1 27 7.4 30 15:01:52 Start 8.0 PPA Automatically 5308 2969 831.2 24 7.8 31 15:03:05 packing out on 6 5828 2983 864.4 27.6 7.9 32 15:04:46 Sta a at Perfs: 7.0 PPA 6001 2982 910.5 27.4 8 33 15:05:32 Start 9.0 PPA Automatically 6047 2984 931.2 26.6 8 34 15:06:58 pH 10.5 6107 2981 970 26.9 9.1 35 15:08:31 Stage at Perfs: 8.0 PPA 6184 2971 1012.3 27 8.9 36 15:09:13 Start 10.0 PPA Automatically 5811 2953 1031.1 26.4 9.3 37 15:12:24 IStage at Perfs: 9.0 PPA 6066 2925 1113.3 26 9.9 38 15:14:04 IStart 11.0 PPA Automatically 6061 2917 1156.1 25.1 1 9.8 39 15:14:44[Activated Extend Stage 6034 2898 1173 24.7 1 11.1 • Schlumberger Client BP Exploration Alaska Well: L-124 Formation: Kuparuk C District: Prudhoe Bay Country: United States Loadcase:Ace Load Case Message Log � Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 40 15:16:53 12 a 6151 2879 1226.6 24.8 12 41 15:17:20 Stage at Perfs: 10.0 PPA 6176 2877 1237.8 24.8 12 42 15:20:10 Deactivated Extend Stage 5705 2832 1305.5 23.4 0 43 15:20:10 Start WF Flush Manually 5705 2832 1305.5 23.4 0 44 15:22:25 Stopped Pumping Prop 3681 2834 1356.2 15.9 -0.2 45 15:22:34 Start Freeze Prote Automatically 3593 2831 1358.6 15.9 0 46 15:27:41 Started Pumping 2520 1424 1378.5 0 0 47 15:40:07 15 min 2276 -79 1378.5 0 0 48 15:40:49 wellhead closed 2261 -79 1378.5 0 0 49 15:41:54 Flushing surface lines with LVT 134 -80 1378.5 0 0 50 16:36:36 Finished fanning pumps -3670 -1272 1378.5 0 0 51 14:47:11 Start 1.0 PPA Automatically 5061 2999 402.5 30.2 0 52 14:47:28 Started Pumping Prop 5054 3001 411 30.3 0 53 14:48:52 Start 2.0 PPA Automatically 4921 2973 452.2 29.5 1 54 14:49:59 Sta a at Perfs: PAD 4960 2992 485 29 2.1 55 14:50:35 Start 3.0 PPA Automatically 5036 3006 502.5 29.3 1.9 56 14:51:41 Stage at Perfs: 1.0 PPA 5133 3021 534.9 29.5 3 57 14:52:16 Start 4.0 PPA Automatically 5219 2985 552 29 3 58 14:53:15 pH 10 3 ppa 5305 2977 580.9 29.4 4 59 14:53:24 Stage at Perfs: 2.0 PPA 5346 2980 585.3 29.1 4 60 14:53:57 Start 5.0 PPA Automatically 5436 2986 601.6 30.1 4 61 1 14:55:04 Stage at Perfs: 3.0 PPA 5539 3001 634.3 29 5 62 14:55:40 Start 6.0 PPA Automatically 5681 3007 651.6 29.4 5 63 14:56:47 Sta e at Perfs: 4.0 PPA 5788 3003 684 29.9 6 64 14:58:30 at Perfs: 5.0 PPA 5969 3010 734 28.7 6 65 14:58:45 -Stage Start 7.0 PPA Automatically 6000 3013 741.2 29.7 6 66 15:01:38 Stage at Perfs: 6.0 PPA 5424 2978 825.1 27 7.4 67 1 15:01:52 Start 8.0 PPA Automatically 5308 2969 831.2 24 7.8 68 15:03:05 packinq out on 6 5828 2983 864.4 27.6 7.9 69 15:04:46 at Perfs: 7.0 PPA 6001 2982 910.5 27.4 8 70 15:05:32 -Stage Start 9.0 PPA Automatically 6047 2984 931.2 26.6 8 71 15:06:58 pH 10.5 6107 2981 970 26.9 9.1 72 15:08:31 Stage at Perfs: 8.0 PPA 6184 2971 1012.3 27 8.9 73 15:09:13 Start 10.0 PPA Automatically 5811 2953 1031.1 26.4 9.3 74 15:12:24 Sta a at Perfs: 9.0 PPA 6066 2925 1113.3 26 9.9 75 15:14:04 Start 11.0 PPA Automatically 6061 2917 1156.1 25.1 9.8 76 15:14:44 Activated Extend Stage 6034 2898 1173 24.7 11.1 77 1 15:16:53 12ppa 6151 2879 1226.6 24.8 12 78 15:17:20 Stage at Perfs: 10.0 PPA 6176 2877 1237.8 24.8 12 79 15:20:10 Deactivated Extend Stage 5705 2832 1305.5 23.4 0 80 15:20:10 Start WF Flush Manually 5705 2832 1305.5 23.4 0 81 15:22:25 Stopped Pumping Prop 3681 2834 1356.2 15.9 -0.2 82 15:22:34 Start Freeze Prote Automatically 3593 2831 1358.6 15.9 0 83 15:27:41 Started Pum ing 2520 1 1424 1378.5 0 0 84 15:40:07 15 min 2276 -79 1378.5 0 0 85 15:40:49 wellhead closed 2261 -79 1378.5 0 0 86 15:41:54 Flushing surface lines with LVT 134 -80 1378.5 0 0 87 16:36:36 IFinished fanning pumps -3670 -1272 1378.5 0 1 0 • Schlumberger Section 4: Treatment Plots 1 I* Client: BP Exploration Alaska Well: L-124 Formation: Kuparuk C District: Prudhoe Bay Country: United States Loadcase.Acq Load Case — Treating Pressure BP Exploration Alaska — Annulus Pressure Pressure Test L-124 12-12-2015 — Slurry Rate — Prop Con Time -hh: mm:. 40 10 36 9 32 8 28 7 24 6 � v 20 � 5 v a D 16 4 12 3 8 2 4 1 00 ; © SchIurn berger 1994-2012 Swrfuniberger Schlumberger 1 I.J DataFRAC PRC Plot BP Exploration Alaska L-124 12-12-2015 Client: BP Exploration Alaska Well: L-124 Formation: Kuparuk C District: Prudhoe Bay Country: United States Loadcase:Acq Load Case Treating Pressure Annulus Pressure slurryRate Prop Con PRC Treatment Plot Time - hh:mm:ss BP Exploration Alaska L-124 12-12-2015 — Treating Pressure — Annulus Pressure — Slurry Rate — Prop Con Time - hh:mm:ss 10 9 8 7 6 a n 5 v 4 n 3 2 1 0 24 21 18 15 12 D 9 6 3 0 SchlumbergerClient: BP Exploration Alaska Well: L-124 Formation: Kuparuk C District: Prudhoe Bay Country: United States Loadcase: Acq Load Case F103 Concentration PCM Additives Bp Exploration Alaska — L065 Concentration L-124 — L071 Concentration 12.12.2015 — Clean Fluid Rate Slurry Rate Till FIMAM r PAR M-011 11111111 POD Additives 16 ii a a 8 8 4- 0 13:5534 14.37:14 Time - hh:mm:ss BP Exploration Alaska L-124 12-12.2015 15'.18'.54 — Prop Con SH Prop Con J475 Concentration Slurry Rate — Clean Fluid Rate — Gate Position 40 10 . 0 13:13:54 13:55:34 14:37:14 15:18:54 16:00:34 Time-hh:mm:w 16:00:34 100 90 80 70 60 p io0 i 50 0 O 40 0 30 20 10 0 11,117 Ca ion Test It 10 . 0 13:13:54 13:55:34 14:37:14 15:18:54 16:00:34 Time-hh:mm:w 16:00:34 100 90 80 70 60 p io0 i 50 0 O 40 0 30 20 10 0 Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 12/11/201 Job End Date: 12/12/201 State: Alaska County: Beechey Poin API Number: 50-029-23255-00-0 Operator Name: BP America Production Compan Well Name and Number: L-12 Longitude: -149.3266032 Latitude: 70.3507694 Datum: NAD2 Federal/Tribal Well: N True Vertical Depth: 6,40 Total Base Water Volume (gal): 65,73 Total Base Non Water Volume: Hydraulic Fracturing Fluid Composition: -49W- Frac , 'Frac Focus Chemical Disclosure Registry 01cottC'1Or: Cou�sctt <Oil&GPS • Chemical Maximum Maximum Trade Name Supplier Purpose Ingredients Abstract Service Ingredient oncentration in Ingredient oncentration in Comments Number CAS #), Additive HF Fluid 3uar Polymer Slurry, (% by mass)** (% by mass)** F128FIexD:WF128 Schlumberger Surfactant , Breaker, rosslinker, Scale nhibitor, Clay Control gent, Additive, Bactericide, Propping ent Nater (Including Mix Water NA 72.4962 Supplied by Client eramic materials and wares, 6402-68-4 96.75198 26.61041 hemicals Distillates (petroleum), 4742-47-8 0.87879 0.2417 drotreated light uar gum 000-30-0 0.7922 0.2179 hydroxy-N,N,N 7-48-1 0.4333 0.1191 rimeth lethanaminium chloride oronatrocalcite 1319-33-1 0.2916E 0.08021 Ethylene Glycol 107-21-1 0. 2 4 5'9—C 0.0662 Diammonium peroxodisulphate 727-54-0 0.2264E 0.0622 Propenoic acid, polymer with 129898-01-7 0.0673 0.0185 odium phosphinate inylidene 5038-72-6 0.04910 0.0135 hloride/methylacrylate 0 0l mer • ropan-2-ol 7-63-0 0.0483E 0.0133 butoxyethanol 111-76-2 0.0483E 0.0133 Icohol, C11 linear, ethoxylated 4398-01-1 0.0444 0.0122 odium hydroxide (impurity) 1310-73-2 0.0282 0.0077 odium tetraborate 1330-43-4 0.0245E 0.0067 12-15 alcohol ethyoxylated 8131-39-5 0.02411 0.0066 ihydrogenated tallow dimethyl ammonium bentonite 8953-58-2 0.02289 0.0062 ilicon Dioxide 631-86-9 0.01408 0.0038 odium chloride 647-14-5 0.01361 0.0037 oric acid 10043-35-3 0.00767 0.00211 umaric acid 110-17-8 0.00767 0.00211 onosodium fumarate 704-73-6 0.00767 0.00211 methyl-1,3-dioxolan-2-one 108-32-7 0.00704 0.0019 alcium Chloride 10043-52-4 0.00688 0.0018 Diatomaceous earth, calcined 1053-39-3 0.0064 0.0017 1-undecanol 112-42-5 0.0038 0.0010 agnesium silicate hydrate (talc) 14807-96-6 0.001 5C 0.00041 agnesium nitrate 10377-60-3 0.0013C 0.0003 mine treated smectite clay 8153-30-0 0.000BE 0.0002 2"-oxydiethanol (impurity) 111-46-6 0.0007 0.0002 -chloro-2-methyl-2h- sothiazolol-3-one 6172-55-4 0.0007 0.0001 agnesium chloride 786-30-3 0.0006 0.0001 oly(tetrafluoroethylene) 002-84-0 0.0006z 0.0001 iutan gum 125005-87-0 0.0003E 0.00011 methyl-2h-isothiazol-3-one 682-20-4 0.00021 0.0000 otassium chloride (impurity) 447-40-7 0.0002 0.0000 rystalline silica (impurity) 14808-60-7 0.0001 0.0000 ristobalite 14464-46-1 0.0001 0.0000 %cetic acid, potassium salt 127-08-2 0.0001 0.0000 %c'etic acid(impurity) 4-19-7 0.0000 0.00001 I otal water volume sources may include fresh water, produced water, and/or recycled water Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) 0 0 THE STATE Alaska Oil and Gas "ALASKA GOVERNOR BILL WALKER 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Tyson Shriver av'o aQ % Z05 Well Intervention Engineer �(,�►:'� BP Exploration (Alaska), Inc. P.O. Box 196612 d�~ dq Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, BRLS L-124 Sundry Number: 315-681 Dear Mr. Shriver: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. —it— DATED this day of November, 2015 Encl. Sincerely, Cathy . Foerster Chair Jv RBDMS', 0 12015 WC ) STATE OF ALASKA NOV 0 3 2015 ALASKA OIL AND GAS CONSERVATION COM MON APPLICATION FOR SUNDRY APPROVALS ®nC�C�I 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate RI • Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate [jfOther Stimulate ❑ Alter Casing ❑ Change Approved Program El �L Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: - Exploratory ❑ Development a 5. Permit to Drill Number: 205-043 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-23255-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No R1 • BRLS L-124 - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 0028239 PRUDHOE BAY, BOREALIS OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10774 6485 10725 6482 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" X 34" 215.5# A53 31 -110 31 -110 Surface 3199 9-5/8" 40# L-80 30-3229 30-2603 5750 3090 Intermediate 9070 7" 26# L-80 28-9098 28-6481 7240 5410 Production Liner 2442 4-1/2" 12.6# L-80 8287-10729 6378-6482 8430 17500 Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD (ft) and TVD (ft): See Attachment No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: BOP Sketch ❑ Detailed Operations Program [ Exploratory ❑ Stratigraphic ❑ Development 21 " Service ❑ 14. Estimated Date for Commencing Operations: r i , l r 15. Well Status after proposed work: Oil Q • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Op Shutdown ❑ GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shriver, Tyson Email Tyson.Shriver@bp.com Printed Name Shriver, Tyson Title Well Interventions Engr Signature I ~ c Phone 564-4133 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I _0 I Plug Intl grity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: fosf 1A &" &&, K_ Wf/C� �D r"� FRLC 50 C v.S CAC,,1 .l.'C 1Sd0jUff P,5)bA-143 www. '4 c mac" S. nPlvs odsaXJYJ ,rs U QAC. 2s. 8 3 Spacing Exception Required? Yes ❑ No L✓J Subsequent Form Required: ' Q — 4 Q APPROVED BYTHE _ Approved by: COMMISSIONER COMMISSION Date:/ /--Z5— / 5 RBDR 0 12015 // 106% 1-11 ORIGINAL Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. �J� 6 cUw 11/o/l S /i 1>1 a` /< Submit Form and Attachments in Duplicate AB ABANDONED Perforation Attachment MECHANICAL ISOLATED REMOVED APF ADD PERF MIS BRLS L-124 BRIDGE PLUG SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base L-124 5/12/2005 SL 8398 9102 6430.4 6481.01 L-124 5/12/2005 SL 9269 10306 6478.71 6468.1 L-124 5/12/2005 SL 10431 10684 6470.45 6481.07 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BRIDGE PLUG BPP PULLED MILK MECHANICAL LEAK BRIDGE PLUG BPS SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN 6UUEEZE SQF FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF E • • Casing / Tubing Attachment ADL0028239 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20" X 34" 215.5# A53 31 - 110 31 - 110 SURFACE 3199 9-5/8" 40# L-80 30 - 3229 30 - 2603 5750 3090 INTERMEDIATE 9070 7" 26# L-80 28 - 9098 28 - 6481 7240 5410 LINER 2442 4-1/2" 12.6# L-80 8287 - 10729 6378 - 6482 8430 7500 TUBING 43 4-1/2" 12.6# L-80 26 - 69 26 - 69 8430 7500 TUBING 8223 3-1/2" 9.2# L-80 69 - 8292 69 - 6381 10160 10530 • 0 0 Packers and SSV's Attachment ADL0028239 SW Name Type MD TVD Depscription L-124 TBG PACKER 8232.96 6349.38 3-1/2" Baker Premier Ret. Pkr L-124 PACKER 8298.51 6383.84 5" Baker ZXP Top Packer 1] STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS % Before me, the undersigned authority, on this day personally appeared who being duly sworn states: ` 1. My name is Tyson Shriver. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration (Alaska) Inc. ("BPXA") and I am familiar with the Application for Sundry Approvals to stimulate the L-124 Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On October 7, 2015, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this Ind day of October, 2015. (Signatur STATE OF ALASKA THIRD JUDICIAL DISTRICT (� Subscribed and sworn to or affirmed before me at (Q on the l -� day of , 20 �' Sigirture of Officer (/ lycCrIce— ` Title of Officer '� .� lyra Q,*� 1WKA •AI.1eSS_ • Date: October 26, 2015 Subject: L-124 Fracture Stimulation From: Tyson Shriver - Engineer, Alaska o: 907.564.4133 c: 406.690.6385 To: Chris Wallace 0 Attached is BP's proposal and supporting documents to perform a fracture stimulation on well L-124 in the Kuparuk reservoir of the Prudhoe Bay Unit. L-124 is a long horizontal producer located in the far northwest quadrant of the Borealis reservoir that produces from C3 sands. It was completed in 2005 with a slotted liner throughout most of its production interval. The permeability in this area is relatively low and L-124 has struggled to produce for sustained periods. There is evidence to suspect the difficulty in production is caused by insufficient injection support (nearby injector to the northwest, L-123, is LTSI for low injectivity and nearby injector to the south, L-115, has a favorable sweeping path to the south where permeability trends improve). L- 124 is currently LTSI and has been shut in for most of the time since 2011. The objective of this program is to perforate 30' of C3 sand and perform a fracture stimulation on L-124 to improve well performance. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which require identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to Tyson Shriver Affidavit of Notification (20 AAC 25.283, a, 1): Partners notified 10/7/2015: ConocoPhillips ExxonMobil Chevron Department of Natural Resources Plat Identifying Wells (20 AAC 25.283, a, 2): *See Figure 4 in section "Location of Wells and Faults (20 AAC 25.283, a, 10-11)" Exemption for Freshwater Aquifers (20 AAC 25.283, a, 3-4): Well L-124 is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1-4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/I or more. 4. By letter of July 1, 1986, EPA -Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non -substantial program revision not requiring notice in the Federal Registrar. Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25.440" thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. C Detailed Casing and Cement Information (20 AAC 25.283, a, 5-6A): Well L-124 was spudded on 4/26/2005 A 12-1/4" hole was drilled to 3242' MD where 9-5/8", 40#, L-80, IBT-M casing was run (casing shoe at 3227' MD) and cemented in place with 437 bbls ofArticSet lite 10.7 ppg lead and 60 bbls of 15.8 ppg Class G cement. Cement returns of 100 bbls at surface were seen. A passing pressure test was conducted on the 9-5/8" casing to 3500 psi for 30 min. Cement and formation were drilled out to 3262 and a LOT was performed to 9.0 ppg (700 psi surface pressure, 14.17 ppg EMW, 2601' TVD at shoe). A 8-3/4" intermediate hole was drilled to 9106' MD where 7", 26#, BTC -M casing was run (casing shoe at 9097' MD) and cemented in place with 120 bbls of 12.0 ppg lead Class G cement and 42 bbls of 15.8 ppg tails Class G cement. Casing was successfully pressure tested to 3500 psi for 30 min. A window was milled from 8499'-8513' MD a FIT was performed to 9.3 ppg (575 psi surface pressure, 11.01 ppg EMW, 6473' TVD). A 6-1/8" production hole was drilled to TD at 10,727' MD. Unce�siotted liner, 4-1/2", 12.6#, L- 80, IBT-M was run to 10,725' MD. The liner has three sections of 4-1/2", 12.6#, L-80 IBT-M solid liner from 8315'-9398' MD, 9102'-9268' MD and 10,305'-10,431' MD. The completion assembly consisting of 4-1/2", 12.6#, L-80, IBT-M x 3-1/2", 9.2#, L-80, IBT-M tubing was run to 8290' MD with the packer at 8231' MD. *See Mechanical report and cement evaluation Table 4 in section "Location of Wells and Faults (20AAC25.283, a, 10-11)" for conformance with 20 AAC 25.283, a, 66) Pressure Testing (20 AAC 25.283, a, 7): Table 1—Tubing and Production Casing Pressure Testing Date Tubing Pressure (psi) Production Casing Pressure (psi) Differential Pressure (psi) TBD 4500 0 *4500 TBD 2000 4500 2500 *The tubing will be pressure tested to 4500 psi which is 110% of max differential pressure (4090 psi) during fracture stimulation per 20 AAC 25.283, c, 2._ • Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283, a, 8): Wellbore Schematic TREE = CNV WELLHEAD= FMC Note: Refer to Production DB for historical pert data ACTUATOR = BAKER C INTERVAL KB. ELEV = 76.8 4-112" BF ELEV = 48.30 SLOT KOP = 300 SLTD Max Anne = 94 @ 8810 05/12/05 Datum MD = 8646 10431 - 10684 Datum TVD= 66001SS .0383 bpf. ID = 6.276It 4-1/2" TBG. 12.6#, L-80. r 10725' PBTO IBT-M..0152 bpf, D = 3,958- 1 3227' I 10 = 8.835" Minimum ID = 2.813" @ 2016' 3-1/2" HES X NIPPLE PERFORATION SLVMARY REF LOG MWD LWOON05/11/05 ANGLEAT TOP PERF' Note: Refer to Production DB for historical pert data SIZE SFF INTERVAL OpnSgz DATE 4-112" SLTD 8398-9102 SLOT 05112/05 4-112" SLTD 9269- 10306 SLOT 05/12/05 4-1/2" SLTD 10431 - 10684 SLOT 05/12/05 1 L-1 2 4 SAFETY NOTES $7 4.112" XO 3.112', ID - 2.992" 8290' 8290' 3-112" WLEG, ID=2.950" .0087 bpf. ID = 2.992" MGS/PJC GLV GO 03+05?07 MWS/PJC DRLG DRAFT CORRECTIONS 2016' 3112" HES X NP. ID 2.813, CSRPJC LEGENDI TREE CORRECTION 8310' 5" X 4-112" XO. ID = 3.95" GAS LIFT MANDRELS I I MILLOUT WNDOW (L•124) 8487'- 8499' I I BKR WHIPSTOCK 8487 �8Ni7r {r bt"'S'2-�Sa'M'9 (05/06105) ST MD TVD DEV TYPE VLV ILATCH PORT DA'' .0383 bpf. ID = 6.276It r 10725' PBTO 7 2318 1990 48 NUG DONE RK 16 OVI, 6 3222 2598 46 MviG DMY RK 0 05113105 5 4405 3397 48 NVG DMY RK 0 05113/05 4 5368 4088 34 NUG DONE RK 16 06101/05 3 6217 4798 34 NVG DMY RK 0 06/01/05 2 7054 5491 33 NVG DONE RK 16 06101/05 1 1 8132 1 6292 1 54 1 NMG SO Pot 1 20 06/01/05 $191' 3-1 f2" HES X NIP, ID = 2.813" 8212' HES GUAGE CARRIER w t CA BLE TO SURFACE NIA, [D=2,920- D=2.920 - 8231' 7" X 3-112" BKR PREM PKR 8231' 8258' 3.112" NES X NIP. ID = 2.813" 8278' 3-112" HES X MR ID = 2.813" DATE gy$5' 7"X 5" BKR ZXP LTP w / TIEBK SLV, D = 4,440" 3-112" TBG. 9.2#. L-80. IBT-M. 8290' 8290' 3-112" WLEG, ID=2.950" .0087 bpf. ID = 2.992" MGS/PJC GLV GO 03+05?07 MWS/PJC DRLG DRAFT CORRECTIONS 8303' 7" X 5" BKR HNC LNR HGR ID = 4,43" CSRPJC LEGENDI TREE CORRECTION 8310' 5" X 4-112" XO. ID = 3.95" I I MILLOUT WNDOW (L•124) 8487'- 8499' I I BKR WHIPSTOCK 8487 �8Ni7r {r bt"'S'2-�Sa'M'9 (05/06105) 9102 RA TAG r r HES EZSV (05/06105) 8500' � Lf 10306' RA TAG 7" CSG, 26#, L-80, BTC -M 9097' .0383 bpf. ID = 6.276It r 10725' PBTO \ \ \ 4-112" LNR 12.6#. L-80 IBT-M, 0152 bpf. D = 3.958" 10727' DATE REV BY COMMENTS DATE REV BY CONVENTS 05/15105 N9ES INITIAL COMPLETION 06101105 MGS/PJC GLV GO 03+05?07 MWS/PJC DRLG DRAFT CORRECTIONS 12114110 CSRPJC LEGENDI TREE CORRECTION Figure 1—Wellbore schematic for well L-124. PRUDHOE BAY UNIT WELL: L-124 PERNIFT No: '2050430 API No: 50-029.23255.00 SEC 34. TI 2N. Rt 1 E 2521' FSL & 1391' FWL BP Exploratlon (Alaska) Table 2—Tubular Ratings Size/Name Weight Grade Connection ID Burst, psi Collapse, psi 9-5/8" Surface 40# L-80 BTC 8.835" 5750 3090 7" Liner Production #1 26# L-80 BTC -M 6.276" 7240 5410 4-1/2" Liner Production #2 12.6# L-80 113T -M 3.958" 8430 7500 3-1/2" Tubing 9.2# L-80 113T -M 2.992" 10,160 10,530 Wellhead Wellhead: FMC manufactured wellhead, rated to 5000 psi. Figure 2—Well L-124 FMC wellhead. Tree: 4-1/16" 5,000psi Tubing head adaptor: 11" 5,000psi x 4-1/16" 5,000psi Tubing Spool: 11" 5,000psi w/ 2-1/16" side outlets Casing Spool: 11" 5,000psi w/ 2-1/16" side outlets 0 • Tree -saver Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the frac treating iron. Bottom connection is 7-1/16" The tree -saver is rated to 10,000 psi. Figure 3—Diagram of tree -saver to be used during fracture stimulation. a r L_ Geological Frac Information (20 AAC 25.283, a, 9): Table 3—Geological Information Formation MD Top MD Bot TVDss top TVDss bot TVD Thickness Frac Grad Lithological Desc. HRZ 7847 8138 6038 6219 181 .7 Shale Kalubik 8138 8473 6219 6382 163 .69 Shale TKUP 8473 8477 6382 6384 2 0.6 SS TKC4 8477 8508 6384 6394 10 0.61 SS TKO E 8508 8540 6394 6403 9 0.61 SS TKO 8540 8693 6403 6423 20 0.61 SS **TKC3C N/A N/A 6423 6444 11 0.61 SS **TKC3B N/A N/A 6444 6458 14 0.62 SS **TKC3A N/A N/A 6458 6466 8 0.62 SS **TKC2E N/A N/A 6466 6473 7 0.62 SS **TKC2D N/A N/A 6473 6478 5 0.63 SS **TKC2C N/A N/A 6478 6484 6 0.63 SS **TKC2B N/A N/A 6484 6490 6 0.64 SS **TKC2A N/A N/A 6490 6502 12 0.64 SS **TKC1B N/A N/A 6502 6514 12 0.64 SS **TKC1A N/A N/A 6514 6526 12 0.64 SS *Invert Section **Estimated from L-124 P61 (L-124 well trajectory never crossed) i Ll Location of Wells, Mechanical Information and Faults (20 AAC 25.283, a, 10-11): Location of wells and faults 581500 58200 $62500 SSNOO 583 .. ..� L957651 I � Figure 4—Plat of wells within one-half mile of L-124 wellbore trajectory and location of faults. The blue line indicates the approximate fracture length and orientation in the heel of L-124. The plat above shows faults and wells within a % mile radius of the subject well. There are three faults that are of concern while performing fracturing operations: 1, 2, and 3. Faults 1 and 2 are perpendicular to the primary fracture plane and should avoid any contamination of fracturing fluids due to expected fracture half-length unpropped. Fault 3 is parallel to the primary fracture plane but sufficient stand-off . and fracture orientation should keep Fault 3 from being contaminated with any fracturing fluids. All wells within % mile radius of the subject well and there mechanical designs can be seen in Table 4. No wells are of concern being contaminated with or seeing treating pressure during pumping operations. Mechanical report and cement evaluation Table 4—Mechanical Report and Cement Evaluation Well Name Casing Type Casing Size Casing Depth Hole Size Vol cmt TOC est. via TOC TOC Top of pay interval Zonal Isolation? Comments in Ibs/ft Feet Inches Cu Ft MDFeet TVDssFeet TVDssFeet L-124 Production 7 26# 9097 8.75 558 Volumetric 6239 4739 6383 Yes Production Liner 4.5 12.6# 10727 6.125 0 No Cement N/A N/A 6383 N/A L-124PB1 Production 7 26# 9097 8.75 558 Volumetric 6239 4739. 6383 Yes L-123 Production 7 26# 11393 8.75 822 Volumetric 7183 4414 - 6384 Yes Production Liner 4.5 12.6# 12405 6.125 245 Volumetric 10402 6246 - 6384 Yes L-123PB1 Production 7 26# 11393 8.75 822 Volumetric 7183 4414 6384 Yes L-115 Production 7 26# 8417 8.75 638 Volumetric 5149 4352. 6376 Yes L-117 Production 7 264 9169 8.75 1 483 Volumetric 6695 4701. 6470 Yes NWEILEEN-1 Intermediate 9.625 404 5602 12.25 747.5 Volumetric 3764 3764. 6366 Yes Production 7 26# 9789 8.5 1450 Volumetric 6945 6945 6366 No Cemented in two stages. First stage around shoe does not isolate. Production DV Collar 7 26# 5786 9.625 897 Volumetric 2884 2720 6366 Yes Second stage of cementjob done through DV collar isolates Kuparuk interval. L-122 Production 5.5 15.5# 8796 6.75 262 Volumetric 6380 4305 6380 Yes Production Liner 3.5 9.2# 9410 6.75 145 Volumetric 8795 6166 6380 Yes • 0 Hydraulic Fracture Program (20 AAC 25.283, a, 12): Fracture Stimulation Pump Schedule ATTACHMENT 1: PUMP SCHEDULE MAWP Slurry Rate 40 Highest Pump Trip Proppant Density 2.71 Well Name L•124 AFE Nitrogen PRV Annulus Pressure 3000 Fluid Type YF128FIexD Proppant Used 16120 CarboLite STEP STAGE COMMENTS FLUID PUMP GF DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps. Fiber PUMP TIME # # TYPE RATE Ra r:: STAGE CUM ( STAGE CUM STAGE CUM SIZE GROSS CUM Breaker Conc. STAGE CUM (BPM) iu?rJ°, (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) (#IMgal) (#/Mgal) (hh:mm:ss) (hh:mm:sy 1 Injection test WF128 40 0 0 0 0 0 8.012:00:00 AM 12 00 00 AM 12:00:00 A2.00.00 AM Hard shutdown; monitor pressure. 8400 8400 200 200 8.0 12:05:OOAM 12.05 00 AM 2 Calibration Test YF128FlexD 40 400 200 3321 11721 - 79 279 - - 8.0 --- 12:01:58 AM 12:06 58 AM 3 Displacement WIN 28 40 40 0 279 Hard shutdown; monitor pressure. FLUID PUMP CF DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps. Fiber PUMP TIME STEP STAGE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM Breaker Conc. STAGE CUM # # PPA (BPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) (#/Mgal) (#IMgal) (BBL) (BBL) 4 1 PAD YF128FIexD 40 20.0 150 429 6300 18021 0 0 0 8.0 12:0345 AM' 121043 AM 5 1 FLAT YF128FlexD 40 39.1 50 479 2100 20121 1027 1,027 16)20Carbol-ite49 _150 ___ _42_9 478 8.0 12 :0 1 15AM' 1211:58 AM 6 1 PAD YF128FlexD 40 40.0 300 779 12600 32721 0 1,027 300 778 8.0 12:0730AM11219:28 AM 7 1 1 FLAT YF128FlexD 40 38.3 50 829 2100 34821 2011 3,038 16120 Carbol-ite 48 826 8.0 12:01 15 AM' 12 20 43 AM 8 1 2 FLAT YF128FlexD 40 36.7 50 879 2100 36921 3859 6,897 16120 Carbol-ite 46 872 _ 8.0 f2701:15 AM 12 21 58 AM 9 1 3 FLAT YF128FIexD 40 35.3 60 939 2520 39441 6674 13,571 16120 CarboLite 53 925 10.0 12:01.30 AM 12:2328 AM 10 1 4 FLAT YF128FIexD 40 34.0 50 989 2100 41541 71 37 20,708 16120 Carb.Ute 42 967 10.0 12:01:15 AM 12:24 43 AM 11 1 5 FLAT YF128FIexD 40 32.8 50 1039 2100 1 8598 29.306 16120 CarboLite 41 1008 10.0 12.01 15 AM 12:25'58 AM 12 1 6 FLAT YF128FIexD 40 31.6 25 1064 -436 1050 44691 4978 34,284 16120 CarboLite 20 1028 10.0 12 00,37 AM 12:26'35 AM 13 1 7 FLAT YF128FIexD 40 30.5 25 1089 1050 45741 5612 39,896 16120 Carbol-ite 19 1047 10.0 12:0037 AM 12:2712 AM 14 1 8 FLAT YF128FIexD 40 29.5 50 1139 2100 47841 12408 52,304 16120Carbol-ite37 1084 10.0 12:01:15 AM 1228:27 AM 15 1 9 FLAT YF128FIexD 40 28.6 50 1189 2100 49941 13517 65,821 16120Carbol-ite36 1120 10.0 12:01:15AM 12:29:42 AM 16 1 10 FLAT YF128FIexD 40 277 100 1289 4200 54141 29117 94,939 16120 Carboute 69 1189 10.0 12:02:30 AM 12:32 12 AM 17 1 11 FLAT YF128FIexD 40 26.9 100 1389 4200 58341 31076 126,014 16120 Carboute 67 1256 10.0 12:02:30 AM 12:34 42 AM 18 1 12 FLAT YF128FIexD 40 26.1 100 1489 4200 62541 32921 158,935 w2o carboute 65 1322 10.0 12:02:30 AM 12:37:12 AM 19 1 13 FLAT YF128FIexD 40 25.4 125 1614 5250 67791 43328 202,263 16120 Carboute 79 1401 10.0 12:03:07 AM 12:40:19 AM 58 4 FLUSH WF128 40 40.0 57 1671 2391 70183 202,263 57 1458 10.0 12:01:25 AM 12:41:44 AM 59 4 FLUSH Freeze rotect 15 15.0 19 1690 804 70987 202,263 19 1477 12:01:16 AM 12,43*00 AM TOTALS 1690 1 202263 1477 12:43:00 AM • 0 Chemical Disclosure Fluid Description(s) YF128F[exD:WF128 58,044 Gal Contains: Water, Surfactant, Breaker, Stabilizing Agent, Crosslinker, Guar Slurry, Additive, Bactericide, Propping Agent Scale Inhibitor, Clay Control Ageq+l The totW volume fiswlin the tables above represents the sunimabon of w" at oddfdveL Wow is supoW by dient. Propflefary Ted�mogy CAS Number - Chemical Name Water (Inducing Mix Water Supplied by Client)* Mass Fraction T' 50-70-4 Sorbitol <0.1 % 6419-7 Acetic add(impurity) <0.0001 % 67-48-1 2-hydroxy-NN,N-thmethylethanaminium chloride < I % 67-63-0 Propan-2-d <0.1 % 107-21-1 Ethylene Giycof <0.1 110-17-8 Fumaric acid <0.01% 11146-6 2,2°-oxycliethanol (impuqjA < O.OD1 % 111-76-2 2-butqtanol <-O—.,% 1 112-42-5 1-undecanol - <&O1 % 127-0-2 Acetic acid, potassium salt <0.0001 % 1310-73-2 Sodium hydroxide (impurity) <0.01 % 1319-33-1 Boronatrocalcite <0.1 % 1330-43-4 Sodium tetraborate < 0.01 % 2682-20-4 2-meth*2h-isothiazol-3-one <0.0001 % 7447-40-7 Potassium chloride (impunity) 1 7631-86-9 7647-14-5 Silicon Dioxide Sodium chlonde < O.OD1 % <0.01 % 770473-6Monosodium fumarate <0.01 % 7727-540 Diammonium peroxidisulphate <0.1 % 7786-30-3 Magnesium chloride <0.001 % 9000-30-0 Guar um <1% 9002-84-0 pol&trafluoroethyfene) <0.001 % 9012-548 Hemicellulase enzyme <0.01 % 10043-35-3 Boric acid <0.01 % 10043-524 Calcium Chloride <0.01 % 10377-60.3 Magnesium nitrate <0.001 % 1446446-1 Cristobalite <0.0001 % 14807-966 Magnesium silicate hydrate (tale ) <0.001 % 14808-60-7 Cluartz, Crolline silica <QOOD1 % 25038-72-6 mylidene chlohdelmethylacrylate copolymer <0.1 % 26172-55-4 5-chloro-2-methyl-2h4sothiazolol-3-one <0.001 % 34398-01-1 Alcohol, C11 linear, ethoxylated <0.1 % 6474247-8 Distillates (petroleum), hydrotreated light <1% 66402-68-4 Ceramic materials and wares, chemicals '29 % C12-15 alcohol ethyoxylated < 0.01 % ,.68131-39-5 68153-30-0 Amine treated smectite day < 0.01 % 91053-39-3 Diatomaceous earth, calcined < 0.01 % 125005-87-0 Diutan gum <0.0001 % 129898-01-7 2-Propenoic acid, polymer vAth sodium phosphinate <0.1 % Mix water is supplied by the client Schlumberger has performed no and/w of the wooer and cannot provide a breakdown of components that may how been added to the water by third-parte_ 0 Anticipated Treating Pressures Table 5—Anticipated Pressures Maximum Anticipated Treating Pressure: 6000 psi Maximum Allowable Treating Pressure: 7000 psi Stagger Pump Kickouts Between: 6650 psi and 6300 psi (90% to 95% of MATP) Global Kickout: 6650 psi (95% of MATP) IA Pop-off Set Pressure: 3375 psi (75% of MIT -IA) IA Minimum Hold Pressure: 3000 psi Treating Line Test Pressure: 8000 psi Sand Requirement: 200,000 lbs 16/20 Carbolite Minimum Water Requirements: 1250 bbls (pump schedule: 975 bbls) OA Pressure: Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and wellbore from overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into - neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are staggered between 90% and 95% of the maximum allowable treating pressure. 2) A primary pressure transducer in the treating line will trigger a global kickout that will shift all the pumps into neutral. 3) There is a manual kickout that is controlled from the frac van that can shift all pumps into neutral. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. 0 250 5W 750 Iwo 1250 US. suruem steel Zsc:ge 5001 3282.45 ,3QU e5 r: �..�__L4.. 6400 C3 6500 .100 b00 800 1000 1200 1-100 1500 Figure 5—L-124 cross-section with approximate perforation location labeled by the blue line. 0 Based on a regional stress map, the maximum horizontal stress in the Kuparuk sands is determined to run N/S (5-150 W of N). The heel and lateral of the well are drilled perpendicular to the maximum - horizontal stress meaning the induced fracture will also be perpendicular to the wellbore. Frac Dimensions: TVDss, feet MD, feet Frac Half -Length, ft Top 6425 8400 —250 ft Bottom 6575 8850 The above values were calculated using modeling software. Maximum Anticipated Treating Pressure: 6000 psi Surface pressure is calculated based on a closure pressure of —0.6 psi/ft or 4000 psi. Closure pressure plus anticipated net pressure to be built (500 psi) and friction pressure minus hydrostatic results in a surface pressure of 5500 psi at the time of flush. 4000 psi (closure) + 500 psi (net) + 3900 psi (friction) - 2900 psi (hydrostatic) = 5500 psi (max surface press) The difference in closure pressures of the confining shale layers determines height of the fracture. Average confining layer stress is anticipated to be —0.7 psi/ft limiting fracture height to 150 ft TVD. Fracture half-length is determined from confining layer stress as well as leak -off and formation modulus. The modeled frac is anticipated to reach a half-length of —250 ft. L-124 Wellwork Procedure From: Tyson Shriver — Intervention Engineer David Wages — Intervention Engineer Subject: L-124 Pre -Frac Stimulation Work Est. Cost: $1,000M Please perform the following work: Date: 10/8/2015 To: Wireline Ops Superintendent Well Services Ops Superintendent Coil and Well Testing SR WSL AFE: APBFRACS IOR: 200 1. W PPPOT-T and PPPOT-IC 2. S/F Drift to deviation. Set TTP. Install DGLVs and circ valve. Circ/Load tubing and IA. MIT -T and MIT -IA. Pull TTP post MITs. Drift w/ dmy pert guns. 3. C Perforate. Set IBP. Lay sand plug. 4. F/S Injection test w/ memory gauges on slickline 5. O Install Tree -saver. Perform fracture stimulation. 6. S D&T proppant top. Install LGLVs. 7. C Clean out proppant to PBTD 8. T Assist CT cleanout. Post frac flowback. Current status of well and previous operations: Current Well Status Shut-in Operable Gas Lift Producer Max Deviation 94 degrees @ 8810' MD BHP & BHT 10/13/2014 2647 psi and 148 degrees F @ 6600' TVD Minimum ID 2.813" X -nipple @ 2016' MD Last Downhole Ops 04/07/2012 B&F down to 8300' SLM Last TD Tag 09/16/2005 10,726' CTM CT dry tag Latest HZS Value 04/08/2012 20 ppm Procedure contacts: Contact Work Alternate Intervention Engineer Tyson Shriver (907) 564-4133 (406) 690-6385 Intervention Engineer David Wages (907) 564-5669 (713) 380-9836 Production Engineer James Shrider (907) 564-4755 (907) 699-2669 Discussion and Objective: L-124 was drilled in 2005 into the Kuparuk reservoir. It produces from the C3 and C4 sands but has struggled to sustain production for an extended period of time due to low permeability and poor injector support (L -123i). This well has been a LTSI since October 2011. The thought is to perform fracture stimulation treatments on - both L-124 and L-1 23i to increase permeability to improve the production/injection pair. The objective of this program is to perform a successful fracture stimulation treatment of new perforations shot in the heel to improve well performance and produce the estimated 1.4mmbbls of remaining recoverable , reserves. Note: All integrity testing must be done within 3 months of performing the fracture stimulation to satisfy state requirements. > 06/12/2011: PPPOT-T PASSED > 06/25/2011: SL caliper (max wall penetration of 17%) > 06/27/2011: MIT -T & CMIT-TxIA PASSED to 3000 psi > 04/07/2012: SL B&F, tight spots from 1200'-3600' MD > 09/20/2013: FB hot oil tubing wash Procedure: Wellhead PPPOT-T and PPPOT-IC 1. PPPOT-T to 5000 psi and PPPOT-IC to 3500 psi Slickline Drift to deviation. Set TTP. Install DGLVs and circ valve Load tubing. Pull TTP and drift w/ dmy perf guns. 2. MIRU SL 3. Drift to deviation w/ 3.5" BLB and 2.80" gauge ring • This well was on a routine B&F schedule while producing, so work with LRS as necessary to clean up tubing. Need the tubing as clean as possible for frac operations. 4. Set high pressure X -lock in lower most X -nipple @ 8278' MD • A high pressure X -lock must be used due to the pressures being applied during the MIT -T. The 3- 1/2" high pressure X -lock is rated to 5740 psi from above. 5. Install DGLVs in ST#'s 2, 4, & 7 and circ valve in ST# 1. Have FB load/circ tubing and IA - ---r � 13 Z 'm- t, 6. After tubing and IA are loaded and equalized, pull circ valve and set DGLV in ST# 1. After DGLV is set have FB MIT -T and MIT -IA 7. Pull TTP plug if MITs pass. Troubleshoot if either MIT fails 8. Drift to deviation w/ 30' of 2-1/2" dummy perf guns 9. RDMO SL Fullbore Load/Circ tubing and IA. MIT -T and MIT -IA. 10. MIRU FB 11. Load/Circulate tubing and IA w/ inhibited 9.8 ppg NaCl and a crude freeze protect. Circulate down tubing and up IA. Rig up to U-tube crude freeze protect between tubing and IA. • Volume of tubing and IA down to ST# 1 is 285 bbls. Pump 300 bbls inhibited 9.8 ppg NaCl and 70 bbls crude for a 2000' freeze protect. 12. MIT -T and MIT -IA to 4500 psi (need to be tested individually) • Do not hold any pr sure on IA while tubing is being pressure tested (AOGCC requirement). Hold 2500 psi on tubing while pressure testing IA. ✓�a-=- 13. If MITs pass RDMO FB Coiled Tubing Perforate. Set IBP and lay sand plug. 14. MIRU CT 15. MU and RIH w/ GR/CCL/Nozzle to PBTD @ 10,725' MD. Log up as necessary to correlate depths for IBP set (9200'MD) and perforating (8520'-8550' MD). Paint coil flags for depth control. 16. POOH, MU and RIH w/ Baker IBP. Tie-in to Measured Depth Log (dates 05/11/2005) and set plug between 9186'-9227' MD. Ensure set depth is not over a collar. 17. POOH, MU and RIH w/ large center hole (>1/2") ball drop nozzle w/o checks for lying in sand plug. Lay in sand plug. 18. MU and RIH w/ 30' of SLB 2-1/2" HSD, big hole charges. Tie-in to CT GR/CCL log from Step 16 and perforate the interval 8520'-8550' MD. Capture injectivity test @ 1, 3, and 5 BPM. • If there is a need to log again prior to perforating, do so at WSL discretion 19. Once sand plug is at desired depth POOH, RDMO CT Fullbore w/ Injection test w/ memory gauges Slickline Assist 20. MIRU SL and FB 21. SL MU and RIH to 8530'w/ memory temp and pres logging string 22. Pump the following fluids down the tubing at max rate not to exceed 4500 psi. • Spear in w/ 5 bbls neat meth. Pump 150 bbls diesel down tubing (fluid subject to change based on injection pressure) and record surface pressure and rate at 1 sec — 2 sec intervals • Once pressure is caught, work up to max rate as quick as possible • Perform a hard shut down of pumps and monitor pressure decline for 1 hour (continue to record pressure) • Send recorded data to Tyson Shriver 23. RDMO ASRC Other Install Tree -saver. Perform fracture stimulation. 24. Install Tree -saver 25. Perform fracture stimulating treatment per pump schedule w/ the following pressure limits. Maximum Allowable Treating Pressure: 7000 psi Stagger Pump Kickouts Between: 6650 psi and 6300 psi (90% to 95% of MATP) Global Kickout: 6650 psi (95% of MATP) IA Pop-off Set Pressure: 3375 psi (75% of MIT -IA) IA Minimum Hold Pressure: 3000 psi Treating Line Test Pressure: 8000 psi Sand Requirement: 200,000 lbs 16/20 Carbolite Minimum Water Requirements: 1250 bbls (pump schedule: 1000 bbls) OA Pressure: Monitor and maintain open to atmosphere Max Pump Rate: 40 bpm Max Proppant Concentration 13 ppa 26. RDMO Slickline I D&T proppant top 27. MIRU SL 28. D&T proppant top 29. If possible pull DGLVs and install deep GL design • If a screen -out occurs while fracing it will be likely that the sand top is left somewhere in the tubing and a GLV C/O will not be performed until CT has cleaned out the well. 30. RDMO SL Coiled Tubing Clean out proppant to IBP. Assist coil w/ cleanout. Post frac flowback.' w/ ASRC Assist 31. MIRU CT and ASRC 32. MU cleanout BHA and RIH down to estimated sand top and begin cleaning out w/ 1 % KCI 33. Cleanout down to top of IBP @ 9200' MD. Jet top of IBP sufficiently to be able to pull the IBP. 34. POOH, MU BHA to pull IBP and RIH to IBP. Pull IBP, POOH. 35. MU cleanout BHA and RIH to PBTD if possible. If able to drift to TD, jet the liner and tubing back to surface performing sweeps as necessary to chase out any solids picked up. Otherwise perform a cleanout down to PBTD and chase all solids back to surface. 36. FP to 2500' if SL was not able to C/O GLVs 37. POOH. RDMO CT 38. Perform post frac flowback 39. RDMO ASRC Davies, Stephen F (DOA) From: Shriver, Tyson <Tyson.Shriver@bp.com> Sent: Wednesday, November 18, 2015 11:01 AM To: Davies, Stephen F (DOA) Subject: RE: PBU L-124 (P(TD #205-043) Sundry Application to Fracture Stimulate - Additional Questions Steve, Some answers to your questions: Has PBU L -03A been drilled: No, on the schedule to be drilled in 3Q2016. How was top of cement determined for L-124: Volumetrically Cement tops for NW Eileen State 1: Refer to e-mail from David Wages Does PBU L-51 intersect the Kuparuk formation within one-half mile radius of fracture interval in PBU L-124: Yes (good catch) see discussion below Well PBU L-51 is a SAG producer that intersects the Kuparuk interval between 7236' MD (6385 TVDss) and 7772' MD (6810 TVDss). 'OOJ 7 7 _780'1 1 P ,, 7t, vi - Cc cC?JCI SIC.lfl SCG ve.'C'C'Q 811,CC `_k 300 j 58J`u0 :jL '+ k 41CeC i Vrl. :.11 vYu sxfj - r17X1 - _ r L-51 exits Kuparuk interval @ 7772' MD L-51 penetrates Kuparuk interval @ 7236' MD The cement job for PBU L -51's intermediate casing was done in two stages. First stage was cemented around the shoe with 117 bbls of cement and second stage was circulated through a cement port with 126 bbls. A bond log was completed on the 7" intermediate casing showing good quality cement from 10349' MD (casing shoe) to 7748' MD and from 7234' MD to 5272' MD. Note that the Kuparuk interval (7772' — 7236' MD) is not isolated with cement. That being said, the distance between the Kuparuk interval within PBU L-51 not isolated by cement is sufficient distance away from the planned fracture interval in PBU L-124 (^'2400 ft). Along with fracture orientation (N/S) and predicted half-length (250 ft), the capability of PBU L-51 being a conduit for migration of frac fluids is minimal. Q s/ I , Let me know if you have any other questions. Thanks, Tyson Shriver BP Alaska Wells 0 o: (907) 564-4133 c: (406) 690-6385 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, November 16, 2015 10:15 AM To: Shriver, Tyson Subject: FW: PBU L-124 (P{TD #205-043) Sundry Application to Fracture Stimulate - Additional Questions Tyson, Additional questions: How was the top of cement determined for L-124? In the nearby NW Eileen State 1 well, the top of the Kuparuk C sand lies at 6385' TVDSS and the base of the lowest Kuparuk Sand lies at 6715' TVDSS. In that well, BP's estimated top of cement for the 7" production casing (set at 9789' MD) lies at 6945' TVDSS, which is about 230 true vertical feet below the Kuparuk sands. The DV collar used for the second stage of cement was placed at 5717' TVDSS (5786' MD), which is about 670' true vertical feet above the Kuparuk sands. So, if I'm reading BP's application correctly it appears as though the Kuparuk sands within NW Eileen State 1 are not covered by cement. Is this correct? How were BP's cement tops determined for this well? Are there bond logs in NW Eileen State 1? If not, what other evidence clearly shows the location and quality of cement within the well? Thank you again for your help. Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Davies, Stephen F (DOA) Sent: Monday, November 16, 2015 10:05 AM To: 'Tyson.shriver@bp.com' Subject: PBU L-124 (P{TD #205-043) Sundry Application to Fracture Stimulate Tyson, The AOGCC issued a Permit to Drill for the BP's planned PBU L -03A redrill on October 23, 2105. Has PBU L -03A been drilled? If so, does PBU L -03A intersect the Kuparuk formation within one-half mile of the planned fracture interval in PBU L-124? If so, Is the Kuparuk formation isolated by good quality cement in PBU L -03A so that it is not capable of acting as a conduit for migration of hydraulic fracturing fluids? E • Is this isolation analysis based on a cement bond log? If not, what other direct evidence does BP have to support this analysis? If not, will PBU L -03A intersect the Kuparuk formation within one-half mile of the planned fracture interval in PBU L-124? If so, Will the Kuparuk formation isolated by good quality cement in PBU L -03A so that it is not capable of acting as a conduit for migration of hydraulic fracturing fluids? What logs will be run or what other evidence will be utilized to support BP's conclusions concerning quality of isolation for the Kuparuk interval within PBU L -03A? Does well PBU L-51 intersect the Kuparuk formation within one-half mile of the planned fracture interval in PBU L- 124? If so, Is the Kuparuk formation isolated by good quality cement in PBU L-51 so that it is not capable of acting as a conduit for migration of hydraulic fracturing fluids? Is this isolation analysis based on a cement bond log? If not, what other direct evidence does BP have to support a conclusion that the Kuparuk interval is adequately isolated in PBU L-51? Thank you for your help. Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7 t Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.sov. Sent from my desktop PC Jl�\IED Sr4,,kp ?� TJ _C W 37 � o= qC PROSEG�\ REPLY TO ATTN OF: M/S 409 U.S, ARONIVIENTAL PROTECTION AC 1�,Y REGION 10 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 J U L 10 1986 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Standard Alaska Production Company Aquifer Exemption Request May 16, 1986. Dear Mr. Chatterton: Based on a July 7, 1986, telephone conversation between Lonnie Smith and Harold Scott, I understand there were no comments during the public comment period regarding the proposed exemption. Therefore, we concur with your decision to exempt the aquifers beneath the Western Operating Area of the Prudhoe Bay Unit for Class II injection activities only. This is a "non -substantial program revision" in accordance with Section 13 of our Memorandum of Agreement. Sincerely, 6,,,i - Robert S. Burd Director, Water Division R �cE1V �D Alaska Oil Cas cons. Commissiv Anchora9a • ENVIRONMENTAL PROTECTION &NCY aJEo srgr� REGION 10 0 s 1200 SIXTH AVENUE > 'Z SEATTLE, WASHINGTON 98101 �P PRO��G,O JUL 01 1939 REPLY TO M/S 409 ATTN OF: C. V. Chatterton, Chairman ALaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Standard Alaska Production Company Aquifer Exemption Request May 16, 1986 Dear Mr. Chatterton: As you know, the UIC permit application submitted by the Standard Alaska Production Company (formerly Sohio Alaska Petroleum Company) to EPA on June 6, 1984, indicated there were no underground sources of drinking water (USDW's) at the Prudhoe Bay Oil Field (Western Operating Area). However, in their May 16, 1986, aquifer exemption request to AOGCC, it appears there are USDW's in the area. We will be contacting the operator for clarification as to when they became aware of the existence of USDW's. We will keep you informed of our findings and any subsequent actions. In accordance with our Memorandum of Agreement, EPA has conducted a preliminary review of the aquifer exemption request. We believe that the subject aquifers qualify for an exemption. Our final concurrence/ non -concurrence with your decision will be based on the results of your detailed evaluation of the exemption request and any additional information developed through your public comment process. This action is considered to be a minor exemption and a "nonsubstantial program revision" and will not require notice in the Federal Register. Sincerely, Al Robert S. Burd Director, Water Division- RECEIV[-p Jut. 0 7 1986 Alaska Oil & Ga C,ns. Gchlnli;sion Aoc!r�raye STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF STANDARD ) Aquifer Exemption Order No. 1 ALASKA PRODUCTION COMPANY ) for an Aquifer Exemption ) Western Operating Area Order for that portion of ) including the K Pad Area the Prudhoe Bay Unit , ) commonly Known as the ) Western Operating Area ) including the contiguous K ) Prudhoe Bay Unit Pad Area ) Prudhoe Bay Field July 11, 1986 IT APPEARING THAT: 1. Standard Alaska Production Company, by letter of May 16, 1986, requested that the Alaska Oil and Gas Conservation Commission issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II injection activities. 2. Notice of an opportunity for a public hearing on July 21, 1986, was published in the Anchorage Times on June 13, 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. 4. A copy of Standard Alaska Production Company's request was forwarded to the U.S. Environmental Protection Agency (EPA) - Region 10, on May 21, 1986, in conformance with Section 13 of the Memorandum of Agreement, between the Alaska Oil and Gas Conservation Commission and EPA, effective June 19, 1986. FINDINGS: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K Pad Areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K Pad Areas of the Prudhoe Bay Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable. 1 0 9) Aquifer Exemption order No. 1 Page 2 July 11, 1986 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K Pad Areas of the Prudhoe Bay Unit are reported to have a total dissolved solids content of 7000 mg/1 or more. 4. By letter of July 1, 1986, EPA -Region 10 advises that the aquifers occurring beneath the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a nonsub- stantial program revision not requiring notice in the Federal Register. 5. The Western Operating Area and the contiguous K Pad Area constitute a compact land parcel which can readily be described by governmental subdivisions. CONCLUSION: Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AAC 25.440. NOW, THEREFORE, IT IS ORDERED THAT the portions of aquifers on the North Slope described by the 1/4 mile area beyond and lying directly below the following tracts of land are exempted for Class II injection activities only. UMIAT MERIDIAN T12N R10E Sections 13 and 24. T12N R11E Sections 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23, 24, 25, 26, 27, 28, 29, 30, 32, 33, 34, 35 and 36. T12N R12E Sections 7, 17, 18, 19, 20, 21, 22, 23, 24, 25, 26, 27, 28, 29, 30, 31, 32, 33, 34, 35 and 36. T12N R13E Sections 19, 20, 21, 22, 23, 26, 27, 28, 29, 30, 31, 32, 33, 34, 35 and 36. T12N R14E Sections 27, 28, 29, 31, 32, 33 and 34. T11N R11E Sections 1, 2, 3, 4, 9, 10, 11, 12, 13, 14, 15, 24 and 25. T11N R12E Entire Township. DONE at Anchorage, Alaska and dated July 11, 1986. '*-� I i - IF.vnivvr&I-E C. V. Chatterto C�. /kman Alaska Oil and Gas Conservation Commission Lonnie C. 9mith, Commissioner Alaska Oil and Gas Conservation Commission AX Wi VITTiam W. BarnweIr, Commissioner Alaska Oil and Gas Conservation Commission 9 i ' Aquifer Exemption order No. 1 Page 3 July 11, 1986 T11N R13E Entire Township. T11N R14E Sections 3, 4, 5, 6, 7, 8, 17, 18, 19, 20, 29, 30, 31 and 32. T10N R12E Sections 1, 2, 3, 4, 10, 11 and 12. T10N R13E Sections 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, and 24. T10N R14E Sections 5, 6, 7, 8, 17, 18, 19 and 20. DONE at Anchorage, Alaska and dated July 11, 1986. '*-� I i - IF.vnivvr&I-E C. V. Chatterto C�. /kman Alaska Oil and Gas Conservation Commission Lonnie C. 9mith, Commissioner Alaska Oil and Gas Conservation Commission AX Wi VITTiam W. BarnweIr, Commissioner Alaska Oil and Gas Conservation Commission 9 i 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU L-124 (PT® No. 205-043; Sundry No. 315-681) Paragraph Sub -Paragraph �— Section Complete? l Provided with application. Affidavit states that Notice of (a) Application for (a)(1) Affidavit Operations was sent on October 7, 2015 to all owners, SFD Sundry Approval landowners and operators within a one-half mile radius of 11/13/2015 the well (CPAI. ExxonMobil. Chevron and AK DNR). (a)(2) Plat Provided with application (p. 8 of supporting documents) 11/1SFD 3/2015 Displayed on Figure 4 of the application. Legal description not included with packet (Sections 27, 28, and 34, T12N, a 2 A Well location ( )( )O R11E, UM), but only PBU partners and DNR are potentially SFD affected. The well lies more than 1-1/2 miles from the 11/13/2015 nearest external boundary of the PBU and within the Affected Areas of CO 341F, AIO 36, and AEO 1. None. Per the Water Estate Map within AK DNR's Alaska Mapper web application, there are no subsurface water (a)(2)(e) Each water well within % mile rights within 4-1/4 miles. The nearest surface water rights SFD 11/13/2015 are 2 miles to the NW. The nearest temporary use permit for surface water is about 1-3/4 miles to the NW. PBU L-115, PBU L-117, PBU L-51, PBU L-123, PBU L-123 (a)(2)(C) Identify all well types within 'a Plugback 1, PBU L-122, PBU L-124, NW Eileen St 1, and NW SFD mile Eileen St 2. PBU L -03A was permitted in Oct 2015, but will 11/20/2015 not be drilled until Q3 2016. (a)(3) Freshwater aquifers: geological None: AEO 1 exempts aquifers in this area for Class II SFD name injection activities. 11/16/2015 (a)(3) Freshwater aquifers: measured and Not applicable per AEO 1 SFD true vertical depth 11/16/2015 (a)(4) Baseline water sampling plan Not required; no freshwater aquifers present per AEO 1. SFD 11/16/2015 Well L-124 cementing data summaried as well as offset (a)(5) Casing and cementing information wells. GLS 11/20/15 AOGCC Page 1 November 20, 2015 • L� 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU L-124 (PTD No. 205-043; Sundry No. 315-681) Paragraph Sub -Paragraph Section No cementing details provided other than total volumes. Assume TOC is as predicted. Fracking non-cemented (a)(6) Casing and cementing operation slotted liner so 7" casing window will see full pumping assessment I pressure . IBP is set to concentrate frac at heel of well in 0 sand. Complete? GLS 11/20/15 Not applicable: per AEO 1, no freshwater aquifers present. (a)(6)(A) Casing cemented below Surface casing set at 3227' MD (-2525' TVDSS) and SFD i lowermost freshwater aquifer and cemented; cement returns of 100 barrels were reported at 11/16/2015 conforms to 20 AAC 25.030 'the surface. The Kuparuk interval appears to be isolated by cement in PBU L-115, PBU L-117, PBU L-115, PBU L-122, PBU L-123 Plugback 1, PBU L-122, and PBU L-124. NW Eileen St 2 reached TD about 3,400 true vertical feet above the planned fracturing interval. In NW Eileen St 1, the Kuparuk interval does not appear SFD (a)(6)(B) Each hydrocarbon zone is isolated to isolated by cement behind the 7" casing string. This 11/20/2015 interval lies about 3200' west of the planned frac interval I in L-124 (see (a)(11) below). The Kuparuk interval in PBU L-51 is not isolated by cement, but is located 2400' away from L-124, so it is highly unlikely that PBU L-51 will act as a conduit for frac fluids. (a)(7) Pressure test: information and CDW pressure -test plans for casing and tubing Tubing to 4500 psi, IA to 4500 psi with tubing at 2000 psi. 11/17/2015 installed in well (a)(8) Pressure ratings and schematics: CDW wellbore, wellhead, ROPE, treating head 11/17/2015 ------------ (a)(9)(A) Fracturing and confining zones: 1 The planned 30' fracture interval lies in the Kuparuk C3 SFD lithologic description for each zone sands near the "heel" of L-124. Upper confinement will be i 1.11/16/2015 AOGCC Page 2 November 20, 2015 E 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU L-124 (PTD No. 205-043; Sundry No. 315-681) Paragraph Sub -Paragraph Section Complete?I Provided with application. Affidavit states that Notice of (a) Application for (0)(1) Affidavit Operations was sent on October 7, 2015 to all owners, SFD Sundry Approval landowners and operators within a one-half mile radius of 11/13/2015 the well (CPA[, ExxonMobil, Chevron and AK DNR). ( a)(2) Plat Provided with application (p' 8 of supporting documents) SFD 11/13/2015 (a)(2)(A) Well location (o)(2)(B) Each water well within % mile (a)(2)(C) Identify all well types within mile (a)(3) Freshwater aquifers: geological name (a)(3) Freshwater aquifers: measured and true vertical depth (a)(4) Baseline water sampling plan (a)(5) Casing and cementing information (a)(6) Casing and cementing operation assessment Displayed on Figure 4 of the application. Legal description not included with packet (Sections 27, 28, and 34, T12N, R11E, UM), but only PBU partners and DNR are potentially affected. The well lies more than 1-1/2 miles from the nearest external boundary of the PBU and within the Affected Areas of CO 341F, AlO 313, and AEO 1. None. Per the Water Estate Map within AK DNR's Alaska Mapper web application, there are no subsurface water rights within 4-1/4 miles. The nearest surface water rights are 2 miles to the NW. The nearest temporary use permit for surface water is about 1-3/4 miles to the NW. PBU L-115, PBU L-117, PBU L-51, PBU L-123, PBU L-123 Plugback 1, PBU L-122, PBU L-124, NW Eileen St 1, and NW Eileen St 2. PBU L -03A was permitted in Oct 2015, but will not be drilled until Q3 2016. None: AEO 1 exempts aquifers in this area for Class II iniection activities. Not applicable per AEO 1 Not required; no freshwater aquifers present per AEO 1. SFD 11/13/2015 SFD 11/13/2015 SFD 11/20/2015 SFD 11/16/2015 SFD 11/16/2015 SFD 11/16/2015 AOGCC Page 1 November 20, 2015 • 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU L-124 (PTD No. 205-043; Sundry No. 315-681) Paragraph Sub -Paragraph (a)(6)(A) Casing cemented b� lowermost freshwater aquiff conforms to 20 AAC 25.030 (a)(6)(B) Each hydrocarbon. isolated (a)(7) Pressure test: informa pressure -test plans for casin, installed in well (a)(8) Pressure ratings and s( wellbore, wellhead, BOPE, tr (a)(9)(A) Fracturing and con, lithologic description for eac. (a)(9)(B) Geological name of (a)(9)(C) and (a)(9)(D) Meas vertical depths Section Complete? AOGCC Page 2 November 20, 2015 • 0 Not applicable: per AEO 1, no freshwater aquifers present. ,low Surface casing set at 3227' MD (-2525' TVDSS) and SFD �r and cemented; cement returns of 100 barrels were reported at 11/16/2015 the surface. In NW Eileen St 1, the Kuparuk interval does not appear to isolated by cement behind the 7" casing string. This interval lies about 3200' west of the planned frac interval in L-124 (see (a)(11) below). is The Kuparuk interval appears to be isolated by cement in SFD one PBU L-115, PBU L-117, PBU L-115, PBU L-122, PBU L-123 11/20/2015 Plugback 1, PBU L-122, and PBU L-124. NW Eileen St 2 reached TD about 3,400 true vertical feet above the planned fracturing interval. The Kuparuk interval in PBU L- 51 is not isolated by cement, but is located 2400' away from L-124, so it is highly unlikely that PBU L-51 will act as a conduit for frac fluids. tion and CDW I and tubing Tubing to 4500 psi, IA to 4500 psi with tubing at 2000 psi. 11/17/2015 �hematics: CDW ?ating head 11/17/2015 The planned 30' fracture interval lies in the Kuparuk C3 Ming zones: sands near the "heel" of L-124. Upper confinement will be i zone provided by the Kuparuk D, Kalubik, Pebble, and HRZ shale SFD intervals (about 335' true vertical thickness). Lower 11/16/2015 each zone confinement will be provided by the Miluveach and Kingak shales (about 1,850' true vertical thickness). _ fired and true Provided in Table 3 of BP's application SFD 11/16/2015 AOGCC Page 2 November 20, 2015 • 0 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU L-124 (PTD No. 205-043; Sundry No. 315-681) Paragraph Sub -Paragraph Section Complete? (a)(9)(E) Fracture pressure for each zone CDW 11/17/2015 (a)(10) Location, orientation, report on mechanical condition of each well - -- The designed half-length of the frac wings in L-124 is 250', so if operations go as planned, it appears highly unlikely (a)(11) Sufficient information to determine that the induced fracture(s) will extend to any other well. "If wells will not interfere with containment According to BP's application: a sudden drop in treating SFD pressure is seen, indicating frac fluids have found a fault or 11/16/2015 � within %mile wellbore, pumping operations will immediately stop.„ The very thick overlying and underlying shale intervals will provide adequate isolation. The planned half-length of the induced fractures is 250'. A NW -trending, naturally occurring fault having 20' of vertical (a)(11) Faults and fractures, Location, displacement lies about 650' southwest of the planned frac interval. A second, NW -trending, naturally occurring fault orientation with 75' of vertical displacement lies about 750' to the frac interval. Orientation of the principal axis of the stress field at Kuparuk level is NNW, which means the induced fracture(s) will also likely be NNW -trending. It is highly SFD unlikely that the induced fractures will extend toward or 11/16/2015 reach the existing, naturally occurring faults. (a)(11) Faults and fractures, Sufficient It is highly unlikely that the 20' or 75' naturally occurring information to determine no interference faults will provide a conduit through the very thick overlying and underlying shale intervals. According to BP's with containment within % mile application: "If a sudden drop in treating pressure is seen, indicating frac fluids have found a fault or wellbore, pumping operations will immediately stop.” (a)(12) Proposed program for fracturing CDW operation 11/17/2015 AOGCC Page 3 November 20, 2015 • CJ 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU L-124 (PTD No. 205-043; Sundry No. 315-681) Paragraph Sub -Paragraph Section (b)Testing of casing or intermediate casing (a)(12)(A) Estimated volume (a)(12)(e) Additives: names, purposes, concentrations (a)(12)(C) Chemical name and CAS number of each_ (0)(12)(D) Inert substances, weight or volume of each (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program (a)(12)(F) Fractures — height, length, MD and TVD to top, description of fracturing model (a)(13) Proposed program for post - fracturing well cleanup and fluid recovery Est 6000 anticipated to 7000 psi max Not explicitly defined. Complete? CDW 11/17/2015 CDW 11/17/2015 CDW 11/17/2015 CDW 11/17/2015 CDW 11/17/2015 CDW 11/17/2015 CDW 11/17/2015 Tested >110% of max anticipated pressure IA proposed pressure to be 3000 minimum in program. IA CDW testing to 4500 psi with est 2000 psi held on tubing. 11/17/2015 (c) Fracturing string (c)(1) Packer >100'below TOC of production or intermediate casing (c)(2) Tested >110% of max anticipated pressure differential (d) Pressure relief Line pressure <= test pressure, remotely valve controlled shut-in device (e) Confinement Frac fluids confined to approved formations (f) Surface casing Monitored with gauge and pressure relief pressures device (g) Annulus 500 psi criteria AOGCC Page 4 November 20, 2015 • CDW 11/17/2015 Est diff equals 7000 -3000 psi = 4000 psi. testing proposed CDW at 4500 psi > 110% 11/17/2015 Test pressure of 8000 psi, line pressure est max 7000 psi. CDW shut down devices set at 6650 psi and 6300 psi. 11/17/2015 CDW 11/17/2015 OA open, IA monitored and pop-off set at 3375 psi. CDW 11/17/2015 AOGCC Page 4 November 20, 2015 • Paragraph 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU L-124 (PTD No. 205-043; Sundry No. 315-681) Sub -Paragraph pressure monitoring & notification (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (h) Sundry Report (i) Reporting (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (j) Post frac water sampling plan (k) Confidential Clearly marked and specific facts information supporting nondisclosure (1) Variances Modifications of deadlines, requests for requested variances or waivers Section Complete? N/A CDW 11/17/2015 N/A CDW 11/17/2015 Water plan, variable staggered pump shutdown same as CDW remote shutdown requirement. 11/17/2015 AOGCC Page 5 November 20, 2015 • • 9 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. QC)5 - of Well History File Identifier Organizing (done) RESCAN color Items: VGreyscale Items: ❑ Poor Quality Originals: ❑ Other: NOTES: wo-sided 111111111111111111 DIGITAL DATA V/Diskettes, No.15 ❑ Other, No/Type: ae,canNeeaea OVERSIZED (Scannable) ❑ Maps: ❑ Other Items Scannable by a Large Scanner OVERSIZED (Non -Scannable) ❑ Logs of various kinds: ❑ Other:: BY: C, Maria Date: r7y / U f7 /s/ V j Project Proofing III 1111111111111 III BY: Maria Date: f71q10r7 /s/ (of Scanning Preparation _ x 30 = + {) = TOTAL PAGES q1/0 f (Count does not include cover sheet) Imp BY: ., Maria z -y%� Date: • / ! 01 A rJ /s/ Im Production Scanning Stage 1 Page Count from Scanned File: (Count does include co r sheet) Page Count Matches Number in Scanning Preparation: _Z -YES NO BY: Maria Datel/q'O 7 /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: oualit,ChecKea 111111111111111111 10/6/2005 Well History File Cover Page.doc BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 d W:. Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L -Pad Dear Mr. Maunder, 0 C T 0 5 2009 Alaska Oil & Gas Cons. Cotntnission Anchorage a05—W3 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L - Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) L pad Date 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na gal L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L -02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need Top Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-1 14A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L -121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 150029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 150029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 150029233080000 NA 2 NA 17 6/25/2009 L -214A 2060270 150029232580100 NA 0.25 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 plate blocking conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 1 205152050029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 IHJt,k.4 DATA SUBMITTAL COMPLIANCE REPORT _ 5/31/2007 Sn4 2 AV AA) -A Permit to Drill 2050430 Well Name/No. PRUDHOE BAY UN BORE L-124 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23255-00-00 MD 10774 TVD 6485 Completion Date 5/14/2005 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR / RES / DEN / NEU / PWD, MWD / GR / RES / (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments EQ D Asc Directional Survey 0 10774 Open 5/27/2005 Rpt Directional Survey 0 10774 Open 5/27/2005 C-$ D Asc Directional Survey 0 9106 Open 5/27/2005 PB 1 Rpt Directional Survey 0 9106 Open 5/27/2005 PB 1 D Asc Directional Survey 0 10615 Open 5/27/2005 PB2 Rpt Directional Survey 0 10615 Open 5/27/2005 PB2 ED C Lis 14560 Induction/Resistivity 100 10773 Open 3/22/2007 LIS Veri, FET, ROP, GR, NPHIDRHO og 14560 Induction/Resistivity 25 Blu 100 10774 Open 3/22/2007 MD Vision Service 11 -May - 2005 Log 14560 Induction/Resistivity 25 Blu 100 10774 Open 3/22/2007 TVD Vision Service 11 - May -2005 ED C Lis 14561 Induction/Resistivity 100 9105 Open 3/22/2007 PB1 LIS Veri, FET, ROP, GR, DRHO, NPHI og 14561 Induction/Resistivity 25 Blu 108 9108 Open 3/22/2007 PB1 MD Vision Service 4 - May -2005 og 14561 Induction/Resistivity 25 Blu 108 9108 Open 3/22/2007 PB1 TVD Vision Service 4- i May -2005 !ED C Lis 14562 Induction/Resistivity 100 10615 Open 3/22/2007 PB2 LIS Veri, FET, ROP, GR, NPHI, DRHO i og 14562 Induction/Resistivity 25 Blu 10235 10615 Open 3/22/2007 PB2 MD Vision Service 10 - May -2005 Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 Permit to Drill 2050430 Well Name/No. PRUDHOE BAY UN BORE L-124 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23255-00-00 MD 10774 ND 6485 Completion Date 5/14/2005 ADDITIONAL INFORMATION Well Cored? Y / Chips Received? Y Analysis Received? Comments Compliance Reviewed By: Completion Status 1 -OIL Current Status 1 -OIL UIC N Daily History Received? L:Y N Formation Tops N Date: Schlumberger Schlumberger -DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. e ' Petrotechnical Data Center 1132-1 f' 900 E Benson Blvd Anchorage AK 99508-4254 MAR 4 Date Delivered. M A j i �9k i/i C°a€ K >#191P.@. pit Plg`ia9�alfP Andiff,R9 )d5 -6�3 0 .# r 415(,0,6 # tq&Z2 NO, 4189 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date SL Color CD Schlumberger -DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 i ATTN: Beth t J Received by: ; 03/20/07 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM&N REPORT OF SUNDRY WELL OPERATIONS RECEIVE OCT 12 005 1. Operations Abandon Repair Well L1 Plug Perforations Stimulate 2] AfaSk"PRIGaS Cons. Uommissiol Performed: Alter Casing Pull Tubing Perforate New Pool Waivero Time Extension [:jAnchgfage Change Approved Program E] Operat. Shutdown Perforate El Re-enter Suspended Well E] 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development W Exploratory r Stratigraphic r Service r 205-0430 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 6. API Number: 50-029-23255-00-00 7. KB Elevation (ft): 9. Well Name and Number: 76.8 KB L-124 8. Property Designation: 10. Field/Pool(s): ADL -028239 PRUDHOE BAY Field/ BOREALIS OIL Pool 11. Present Well Condition Summary: Total Depth measured 10774 feet Plugs (measured) None true vertical 6484.56 feet Junk (measured) None Effective Depth measured 10725 feet true vertical 6482.23 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" X 34" 215.5# A53 28 - 108 28 - 108 Surface 3199 9-5/8" 40# L-80 28 3227 28 - 2601.62 5750 3090 Production 8461 7 26# L-80 26 8487 26-6464.7 7240 5410 Liner 2442 4-1/2" 12.6# L-80 8285 10727 6376.95 - 6482.33 8430 7500 Perforation depth: Measured depth: True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 24-67 3-1/2" 9.2# L-80 67-8290 Packers and SSSV (type and measured depth) 3-1/2" Baker Premier Ret. Pkr 8231 12. Stimulation or cement squeeze summary: Intervals treated (measured): RMS BFB, Q? 13 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 627 304 0 260 350 Subsequent to operation: 526 254 0 220 370 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r' Development1 Service F Daily Report of Well Operations X16. Well Status after proposed work: Oil W' Gas r WAG GINJ r WIND r WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal Title Data Mgmt Engr C_ Phone 564-4424 Date 10/12/2005 Signa&* = �y Y�j i' Form 10-404 Revised 04/2004 f Submit Original Only L-124 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY IAv �9►CIVTYDATE ISU 9/17/2005 CTU #5 w/1.75" CT. Acid/PPROF.r**** Continued from 9/16/05 WSR **** Jet 75' bbls 7.5% DAD acid across interval 8400 to 10700 and 10700 to 8400 - over displace acid to form - POH - POP well. Flow back well through test separator (see separate test AWGRS) for 5 hours and recovered —250 bbls. RIH w/PDS STP to 10700'. Made 40 ft/min up/dn passes and jewlery log to 8000'. Make 80 ft/min up/dn passes and POOH. Recover good data - no spinner results - 158 BHT - .3mm gas - **** RDMO Turn well over to ASRC T Sep. Job Complete ***** NOTE: Well was severely choked back by 1-3/4" while logging. Little or no liquid was seen at surface during the majority of the up/dn passes. Well will be loaded with hot diesel and 50 bbls pumped into formation to free water/solids? in the near bore and then brought back on line using ASRC T Sep. FLUIDS PUMPED BBLS 53 Diesel 58 50/50 Meth 77 7.5% DAD acid 188 TOTAL STATE OF ALASKA ALASKA AND GAS CONSERVATION COMNOION WELL COMPLETION OR RECOMPLETION REPORT AND LOG � A'' I 3 : S ,N. v ✓.. 1a. Well Status: ® Oil ❑ Gas ❑ Plugged ❑ Abandoned 20AAC 25.105 ❑ GINJ ❑ WINJ ❑ WDSPL No. of Completions ❑ Suspended ❑ WAG 20AAC 25.110 One Other 1b. Well Class: ® Development [3 Exploratory ❑ Stratigraphic ❑ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 5/14/2005 12. Permit to Drill Number 205-043 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/26/2005 13. API Number 50-029-23255-00-00 4a. Location of Well (Governmental Section): Surface: 2521' NSL, 3889' WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2094' NSL, 4818' WEL, SEC. 27, T12N, R11E, UM Total Depth: 2022' NSL, 1731' WEL, SEC. 28, T12N, R1 1E, UM 7. 8. 9. Date T.D. Reached 5/11/2005 14. Well Name and Number: PBU L-124 KB Elevation (ft): 76.8' 15. Field / Pool(s): Prudhoe Bay Field /Borealis Pool Plug Back Depth (MD+TVD) 10725 + 6482 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583026 y- 5978241 Zone- ASP4 TPI: x- 582033 y- 5983082 Zone- ASP4 Total Depth: x- 579842 Y- 5982987 Zone- ASP4 10. 11. Total Depth (MD+TVD) 10774 + 6485 Ft 16. Property Designation: ADL 028239 Depth where SSSV set (Nipple) 2016' MD 17. Land Use Permit: Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 19. 18. Directional Survey ® Yes ❑ No 21. Logs Run: MWD / GR, MWD / GR / RES / DEN / NEU / PWD, MWD / GR / RES / DEN / NEU 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE WT. PER FT. GRADE Top IBoTTom Top SIZE AMOUNT CEMENTING RECORD' PULLED 20" 215.5# A-53 Surface 108' Surface 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 28' 3227' 28' 12-1/4" R6465' 573 sx AS Lite, 288 sx Class 'G' 7" 26# L-80 26' 8487' 26' 8-3/4" 283 sx Class 'G', 202 sx Class 'G' 4-1/2" 12.6# L-80 8285' 10727' 6377' 1 6-1/8" jUncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 8398'- 9102' 6430'- 6481' 9269'-10306' 64791-6468' 10431'- 10682' 6470'- 6481' 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.2#, L-80 8290' 8231' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 8500' Set EZSV 8487' Set Whipstock to Kick Off from PB1 Freeze Protect w/ 155 Bbls of Diesel 26. PRODUCTION TEST Date First Production: June 10, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 6/10/2005 Hours Tested 2 PRODUCTION FOR TEST PERIOD OIL -BBL 10 GAS -MCF 25 WATER -BBL 10 CHOKE SIZE 176 GAS -OIL RATIO 2,605 Flow Tubing Press. 220 Casing Pressure 1,379 CALCULATED 24-HOUR RATE OIL -BBL 117 GAS -MCF 305 WATER -BBL 120 OIL GRAVITY -API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". E None R8DMS BFL jUN 2 0 2005 Form 10-407 Revised 12/2003 CONTINUED ON'REVERSE SIDE /Ank 28. GEOLOGIC MARKERS 29' WIRMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3510' 2797' None Ugnu M Sands 5054' 3839' Schrader Bluff N Sands 5322' 4050' Schrader Bluff O Sands 5493' 4192' Base Schrader / Top Colville 5921' 4550' HRZ 7847' 6115' Kalubik 8138' 6296' Kuparuk C 8477' 6461' Kuparuk C 10717' 6482' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed / Title Assistant Date v��t! 3/(� Terrie Hubble J Technical PBU L-124 205-043 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Shane Gagliardi, 564-5251 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 BP Page 1 of 1 Leak -Off Test Summary v Legal Name: L-124 Common Name: L-124 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 4/30/2005 LOT 3,242.0 (ft) 2,601.0 (ft) 9.00 (ppg) 700 (psi) 1,916 (psi) 14.18 (ppg) 5/7/2005 FIT 8,513.0 (ft) 6,473.0 (ft) 9.30 (ppg) 575 (psi) 3,702 (psi) 11.01 (ppg) Printed: 5/16/2005 11:58:30 AM Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 4/24/2005 119:30 - 00:00 L-124 L-124 DRILL+COMPLETE NABORS ALASKA DRILLING I NABOBS 9ES 4.501 MOB I P I I PRE 4/25/2005 00:00 - 08:00 8.00 MOB P PRE PRE 1.00 08:00 - 14:00 6.00 RIGU P 05:00 - 05:30 PRE RIGU 14:00 - 14:30 0.50 RIGU P 1.00 PRE P 14:30 - 19:00 4.50 RIGU P RIGU PRE 19:00 - 00:00 1 5.001 RIGU I P I I PRE Spud Date: 4/26/2005 Start: 4/24/2005 End: 5/14/2005 Rig Release: 5/14/2005 Rig Number: 00:00 - 04:00 4.00 RIGU P PRE 04:00 - 05:00 1.00 RIGU P PRE 05:00 - 05:30 0.50 RIGU P PRE 05:30 - 06:30 1.00 RIGU P PRE 06:30 - 10:30 4.00 RIGU P PRE 10:30 - 13:00 2.50 RIGU P PRE 13:00 - 15:00 2.00 RIGU P PRE 15:00 - 16:30 1.50 BOPSUP P PRE 16:30 - 17:00 0.50 BOPSUF P PRE 17:00 - 17:30 0.50 BOPSUF P PRE 17:30 - 18:00 0.50 DRILL P SURF 18:00 - 20:30 2.50 DRILL P SURF 20:30 - 23:00 2.50 DRILL P SURF 23:00 - 00:00 1.00 DRILL P SURF 4/27/2005 00:00 - 12:00 1 12.001 DRILL I P SURF 12:00 - 12:30 0.50 DRILL P SURF 12:30 14:00 1.50 DRILL P SURF 14:00 - 19:00 1 5.001 DRILL I P I SURF Unpin the blocks and bridle up. Move the camp and the pits to L -pad from W -pad. Lower chute and ready the rig floor. Lay over the derrick. Open sub doors and move sub to the center of the pad. Move sub from W -pad to L -pad. Position sub near L-124. Install surface Hydril. Position divereter system. Spot wellhead equipment in cellar area. Add 1 more joint of 16" to the diverter line. Raise the derrick and pin the legs. Move the sub into position. Lay mats and herculite. Close the cellar doors and center over the well. Move the pits into position. Lay mats and herculite. RU circulating lines. Raise the chute, bridle the blocks and pin the top drive. Backing out 6 hours for Diverter and wellhead work, Rig accepted @ 1300 hours 4/25/2005. Fill the pits with spud mud. Nipple up the bell nipple, riser and dresser sleeve. Install ball valves on conductor. Load the pipe shed with 4" DP. Install new Kelly hose.Load and strap 4" DP. Clean rig floor and prep to pick up 4" DP. Pickup and stand back 4" DP Adjust kelly hose. Continue picking up 4" DP. Pickup and set back 24 joitns 4" HWDP, jars and stand of NM DC's. Make up BHA #1 with used Hughes MX -CI, motor (1.50), NM lead collar, NM stab, MWD, NM stab, NM XO, orienting sub, orient BHA, tag ice @ 80' Function test 20" diverter and Knife valve. Jeff Jones with AOGCC waived witness of the diverter test. Conduct D-4 Accumulator drill, Pre -Spud meeting with all rig personnel, Discussed drilling hazards and diverting shallow gas. Fill hole and check surface equipment for leaks. Clean out conductor pipe, Drill from 108' to 181', 5-15k wob, 60 rpm, torque 2k, 605 gpm, 1020 psi. Rig up Sperry -Sun and Gyrodata tools for gyro, RIH with gyro, orient BHA to desired gyro toolface for kickoff. POH with gyro. Drill 12.25" hole from 181' to 360' 10-15k wob, 605 gpm, 1160 psi, 80 rpm, torque 2k, up wt = 60k, do wt = 60k, rt wt = 60k. AST = 1.04 ART = 1.80 POH, pickup remaining BHA, (Jars) RIH. Drill 12.25" hole from 360' to 1,191', 35k wob, 600 gpm 1800 psi on bottom, 1530 off bottom, 80 rpm, torque on bottom 4.8k,torque off bottom 2k, up wt = 78k, do wt = 71 k, rt wt = 74k. AST = 7.78 hrs. ART =.2 hrs. Drill 12.25" hole from 1,191'to 1,281'. Ran gyro @ 1,281' POH with gyro taking surveys every 50' from bottom to 850', every 100' from 800' to surface, total of 16 surveys. Drill 12,25" hole from 1,281' to 1,750', 35k wob, 600 gpm 1960 psi on bottom, 1840 off bottom, 80 rpm, torque on bottom 4.8k,torque off bottom 4k, up wt = 75k, do wt = 65k, rt wt = 70k. Printed: 5/16/2005 11:58:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-124 L-124 DRILL+COMPLETE NABORS ALASKA DRILLING I NABOBS 9ES Start: 4/24/2005 Rig Release: 5/14/2005 Rig Number: I 4/27/2005 14:00 - 19:00 J 5.001 DRILL P SURF 19:00 - 20:00 1.00 DRILL P SURF 20:00 - 21:30 1.50 DRILL P SURF 21:30 - 22:30 1.00 DRILL P SURF 22:30 - 23:30 1.00 DRILL P SURF 23:30 - 00:00 0.50 DRILL P SURF 00:00 - 01:00 1.00 DRILL P SURF 01:00 - 10:30 9.50 DRILL P SURF 10:30 - 12:00 1.50 DRILL P SURF 12:00 - 13:00 1 1.001 DRILL IP I I SURF 13:00 - 13:30 0.50 DRILL P SURF 13:30 - 15:00 1.50 DRILL P SURF 15:00 - 17:00 2.00 DRILL P SURF 17:00 - 19:00 2.00 DRILL P SURF 19:00 - 20:00 1.00 DRILL P SURF 20:00 - 22:00 2.00 CASE P SURF 22:00 - 00:00 1 2.001 CASE I P I I SURF 14/29/2005 100:00 - 04:00 1 4.001 CASE � P I I SURF 04:00 - 07:00 1 3.001 CEMT IP I ( SURF 07:00 - 09:30 1 2.501 CEMT I P I I SURF 09:30 - 10:00 0.501 DIVRTR P SURF 10:00 - 12:00 2.001 DIVRTR I P SURF 12:00 - 17:00 1 5.001 DIVRTR I P I I SURF Spud Date: 4/26/2005 End: 5/14/2005 AST = 2.33 hrs. ART = 2.30 hrs. Circulate hole clean, rotating 80 rpm, torque 4k, 600 gpm, 1840 psi reciprocating full stand, montior well. POH to BHA, no hole problems on trip out. Lay down UBHO sub and change bit. Clean floor, service topdrive and draw works. RIH with BHA #2. RIH from 820' to 1,654', make up topdrive and wash last stand to bottom. Drill 12.25" hole from 1,750 to 3,242', 35k wob, 650 gpm, 3150 psi on bottom, 3080 psi off bottom, 80 rpm torque 6.5k on bottom, 4.5k off bottom, up wt = 103k, do wt = 69k, rt wt = 84k, encountered first hydrates at 2,110' to TD. AST = 1.43 hrs. ART = 3.82 hrs. Circulate bottoms up 2.5X @ 700 gpm, 3350 psi, 100 rpm Torque 4.5k Wiper trip from 3,242' to 1,646', worked thru tight spot from 2,043' to 1959', no pump. RIH from 1,646to 3,242' no problems hole 'in good shape. Circulate hole clean, 700 gpm, 3350 psi, 100 rpm, torque 4.5k POH to BHA no hole problems. Stand back NM DC's, lay down BHA, per DD. Clear floor of directional tools, clean floor. Rig up casing tools, make up Franks tool, make dummy run with casing hanger. Held PJSM with all rig personel. Make up shoe track and check floats, run 9 5/8" 40# L-80 surface casing, per running order. Run 9 5/8" 40# L-80 casing per running order, ran a total of 77 joints, make up torque 8100 ft/lbs, filling pipe every joint, getting back proper displacement. From 1,100' to 3,227' taking 45k down drag work thru tight areas. Make up casing hanger and landing joint, break circulation 2 bpm, 350 psi, no losses, wash last joint to bottom with Franks tool. Stage pumps up to 10 bpm, 825 psi, reciprocating pipe 5', (landing ring hanging up in stack), circulate one bottoms up, Lay down franks tool and pickup cement head, continue to condition mud, to 70-80 vis, 15-20 YP, prior to cementing. up wt = 150k do wt = 75k, Held PJSM with Cementers and rig crew. Pump 5 bbls water and test lines to 3,500 psi, pump 75 bbls mudpush weighted to 10 ppg, drop bottom plug and pump 437 bbls ASL weighted to 10.7 ppg @ 6 bpm, 610 psi, pump 60 bbls 15.8 ppg class G @ 4.5 bpm 930 psi, release top plug and pump 10 bbls water, switch over to rig and displace cement @ 8 bpm, 550 psi, reciprocate pipe, during job, set casing on ring 50 bbls from picking up plug, slowed pumps to 3 bpm, 430 psi 20 bbls away, bumped plug with calculated strokes, pressured up to 2,000 psi, bled off pressure floats held, 100 bbls good cement to surface. CIP @ 09:30. Flush 20" riser and flow line, Blow down lines. Lay down cement head, back out and lay down landing joint, clear floor of all casing and cementing equipment. Flush out 20" Hydril, diverter spool, nipple down 20" Hydril and Printed: 5/16/2005 11:58:38 AM Legal Well Name: L-124 Common Well Name: L-124 Spud Date: 4/26/2005 Event Name: DRILL+COMPLETE Start: 4/24/2005 End: 5/14/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/14/2005 Rig Name: `NABOBS 9ES Rig Number: M-4-- l C.-4 T.. I CL....- I -r__1' '. l rl-.4- I NICT'.f C4...... I 7r`% --- A_+G_» _; Fi.cr.vnk:»»e+ 4/29/2005 12:00 - 17:00 5.00 DIVRTR P SURF diverter line. 17:00 - 20:30 3.50 BOPSU P SURF Nipple up casing and tubing head, test M/M seal to 5,000 psi ok, Nipple up BOP and drilling nipple. 20:30 - 21:00 0.50 BOPSUF P SURF Insatll test plug and rig up BOP test equipment. 21:00 - 00:00 3.00 BOPSUF P SURF Test BOPE to 250 psi low, 3,500 psi high per Nabors testing procedures, Chuck Scheve with AOGCC waived witness of BOP test. Test was witnessed by WSL Brian Buzby, Nabors Toolpusher Kelly Cosby. 4/30/2005 00:00 - 01:00 1.00 BOPSU P SURF Continue testing BOPE to 250 psi low, 3,500 psi high, per Nabors testing procedure. No failures during testing operation 01:00 - 02:00 1.00 BOPSUP P SURF Rig down BOP test equipment, blow down lines and choke manifold, pull test plug and install wear ring. 02:00 - 07:00 5.00 DRILL P INTI RIH picking up 93 joints 4" DP, POH stand back 31 stands 4" DP. 07:00 - 12:30 5.50 DRILL P INT1 RIH picking up 96 joints 4" DP, POH stand back 32 stands 4" DP. 12:30 - 15:30 3.00 DRILL P INTI Held PJSM, Make up bit, motor, float sub, NM stab, LWD/CDR, MWD, ADN, orient motor and MWD. load sources, pickup { remaing BHA and RIH with 4" HWDP to 997'. Shallow test MWD, 520 gpm, 1170 psi. 15:30 - 17:30 2.00 DRILL P INT1 RIH with BHA # 3 picking up 63 joints 4" DP to 2,960' 17:30 - 18:30 1.00 DRILL P INT1 Cut and slip drilling line, service rig and topdrive. 18:30 - 19:30 1.00 CASE P INTI Rig up and test casing to 3,500 psi for 30 min. record on chart. 19:30 - 21:30 2.00 DRILL P INTI Tag cement @ 3,120', drill cement and float equipment, 475 gpm, 1850 psi, 60 rpm, torque 5.8k, 5-10k wob, clean out rat hole and drill from 3,242' to 3,262'. 21:30 - 22:00 0.50 DRILL P INTI Displace well over to 9.0 ppg LSND mud @ 585 gpm, 1,550 psi. 22:00 - 22:30 0.50 DRILL P INT1 Rig up and perform LOT, TVD @ 9 5/8' shoe 2,601'9.0 ppg mud wt. pressure attained 700 psi, EMW = 14.17 ppg 22:30 - 23:00 0.50 DRILL P INTI Establish base line ECD and SPR with new mud in the hole, ECD parameters 100 rpm, 590 gpm, clean hole ECD = 9.53 ppg- 23:00 - 00:00 1.00 DRILL P INT1 Drill 8.75" hole from 3,262' to 3,337', 5-10k wob, 585 gpm, 1750 psi on bottom, 1,560 psi off bottom, 100 rpm, torque 5.8k on bottom, 4.5k off bottom. Hydrates directly out from under shoe, ECD = 9.7 5/1/2005 00:00 - 12:00 12.00 DRILL P INT1 Drill 8.75" hole from 3,337' to 4,463', 5-10k wob, 585 gpm, 2,100 psi on bottom, 2,020 psi off bottom, 100 rpm, torque 7k on bottom, 6k off bottom. up wt = 128k, do wt = 77k, rt Wt = 96k, Pumped sweeps @ 3,618', 4,084', substantial amount of cuttings with sweeps. Control drill at 350-400 fph to keep ecd within set parameters, back ream full stand on connections. Cal ECD = 9.64 Actual = 9.87 AST = 1.08 ART = 3.12 12:00 - 00:00 12.00 DRILL P INTI Drill 8.75" hole from 4,463" to 5,767', 5-10k wob, 583 gpm, 2,460 psi on bottom, 2,400 psi off bottom, 110 rpm, torque 8k on bottom, 7k off bottom. up wt = 132k, do wt = 98k, rt wt = 114k, Pumped sweep @ 4,649', 5,767', Cal ECD = 9.54 Actual = 10.0 AST = 2.17 ART= 4.68 5/2/2005 00:00 - 12:00 12.00 DRILL P INTI Drill 8.75" hole from 5,767' to 6,795', 5-10k wob, 583 gpm, 3,140 psi on bottom, 3,045 psi off bottom, 100 rpm, torque 6k on bottom, 4k off bottom. up wt = 149k, do wt = 108k, rt wt = 124k, pumped sweep at 6,702' no increase in cuttings. Cal Printed: 5/16/2005 11:58:38 AM low BP Page 4 of 10 Operations Summary Report Legal Well Name: L-124 Common Well Name: L-124 Spud Date: 4/26/2005 Event Name: DRILL+COMPLETE Start: 4/24/2005 End: 5/14/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/14/2005 Rig Name: NABOBS 9ES Rig Number: Date From'- To Hours Task ` Code NPT Phase Description of Operations 5/2/2005 00:00 - 12:00 12.00 DRILL P INT1 ECD = 9.72 Actual = 10.21 AST = 1.2 ART = 6.41. 12:00 - 00:00 12.00 DRILL P INT1 Drill 8.75" hole from 6,795', to 7,542' 10k wob, 585 gpm, 3,690 psi on bottom, 3,550 psi off bottom, 100 rpm, torque 7.5k on bottom, 6.8k off bottom. up wt = 165k, do wt = 112k, rt wt = 130k. Started 4 deg/100 build and turn @ 7,168', began weighting up mud system to 10.2 ppg with 12.3 ppg spike fluid @ 7,449', Cal ECD = 10.7 Actual = 11.2 AST = 3.17 hrs. ART = 5.06 hrs. 5/3/2005 00:00 - 12:00 12.00 DRILL P INTI Drill 8.75" hole from 7,542', to 8,330' 10k wob, 550 gpm, 3,750 psi on bottom, 3,700 psi off bottom, 100 rpm, torque 8.4k on bottom, 7k off bottom. up wt = 168k, do wt = 115k, rt wt = 138k, Cal ECD = 10.7 Actual = 11.1 AST = 5.76 hrs ART = 2.58 hrs. 12:00 - 21:30 9.50 DRILL P INT1 Drill 8.75" hole from 8,330' to 9,106', 10k wob, 550 gpm, 3,940 psi on bottom, 3,860, psi off bottom, 100 rpm, torque 12.1k on bottom, 10.2k off bottom. up wt = 171k, do wt = 107k, rt wt = 134k, Cal ECD = 10.7 Actual = 11.1 AST = 2.38 hrs ART= 4.97 hrs. 21:30 -00:00 2.50 DRILL P INT1 Pump 25 bbl high vis sweep, circulate bottoms up x 2.5, 550 gpm, 3,740 psi, 120 rpm, torque 10k, no increase in cuttings when sweep came back, ECD .20 over calculated prior to trip. 5/4/2005 00:00 - 01:00 1.00 DRILL P INTI Monitor well, POH from 9,106', pulled 25k over @ 8,624', & 8,489' wiped back down saw nothing, continue POH to 7,989', hole taking correct fill. Hydrates breaking out while pulling the first 6 stands then quit. 01:00 - 01:30 0.50 DRILL P INT1 Monitor well, pump dry job, blow down topdrive. 01:30 - 04:30 3.00 DRILL P INTI Continue POH with BHA #3, started pulling 20k over and swabbing at 3,580' make up topdrive, unable to circulate, packed off. 04:30 - 05:00 0.50 DRILL P INT1 RI from 3,580 to 3,897', no excess dag, make up to drive, break circulation, stage up pumps slowly to 400 gpm, 1,645 psi 100 rpm, work pipe up slowly, regained full returns. 05:00 - 07:30 2.50 DRILL P INTI Back ream out from 3,3897' to 3,227' 100 rpm, torque 4k, 460 gpm @ 1,715 psi. 07:30 - 08:00 0.50 DRILL P INT1 Pump high vis sweep at shoe, 575 gpm, 2,310 psi, 100 rpm, torque 3.5k, Amount of cuttings doubled when sweep came back 90% wall cake. 08:00 - 08:30 0.50 DRILL P INT1 Service rig and topdrive. 08:30 - 09:00 0.50 DRILL P INT1 Monitor well, pump dry job. 09:00 - 10:30 1.50 DRILL P INT1 POH from 3,227' to 1,004', monitor well at BHA, PJSM, remove sources. 10:30 - 12:30 2.00 DRILL P INT1 Lay down BHA #3 12:30 - 13:00 0.50 DRILL P INTI Clear floor of all directional equipment, clean floor 13:00 - 14:30 1.50 BOPSUF P INT1 Pull wear ring and install test plug, change top rams to 7" test door seals to 3,500 psi. 14:30 - 15:00 0.50 CASE P INTI Make dummy run with 7" casing hanger and landing joint. 15:00 - 16:30 1.50 CASE P INT1 Rig up casing equipment and Franks tool. 16:30 - 21:30 5.00 CASE P INT1 PJSM with all rig personnel. Make up shoe track, check floats. Run 78 joints 7" 26# L-80 BTC -M casing per running order to 3,201', filling every joint, make up torque 8,400 ft/lbs. 21:30 - 22:00 0.50 CASE P INTI Circulate bottoms up at 9 5/8" shoe, stage up pumps to 6 bpm, 475 psi, no losses. up wt = 110k, do wt 85k 22:00 - 00:00 2.00 CASE P INT1 Continue running 7" 26# L-80 BTC -M casing, @ 1 min/per joint Printed: 5/16/2005 11:58:38 AM low BP Page 5 of 10 Operations Summary Report Legal Well Name: L-124 Common Well Name: L-124 Spud Date: 4/26/2005 Event Name: DRILL+COMPLETE Start: 4/24/2005 End: 5/14/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/14/2005 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/4/2005 22:00 - 00:00 2.00 CASE P INT1 in open hole, filling every joint, break circulation every 15 joints, circulate bottoms up by washing down 4 joints from 4,397' to 4,562', pumping @ 6 bpm, 30 bbls each joint while slowly lowering pipe in hole. 5/5/2005 00:00 - 15:00 15.00 CASE P INTI Run 7" 26# L-80 BTC -M casing, @ 1 min/per joint in open hole, filling every joint, break circulation every 15 joints. Started losing pipe displacement at 5,058', (123 its) slowed running speed, Continued running pipe in at reduced rate, losing 1 bbl per/jt, circulate bottoms up by washing down 4 joints from 5,389' to 5,554', stage up pumps to 6 bpm, pump 45 bbls each joint while slowly lowering pipe in hole, lost 5 bbls while washing down first joint. Continue running 7" casing to 6,989, losing pipe displacement. Circulate down each joint from 6,989 to bottom, 3.5 bpm @ 560 - 650 psi, running speed 15' per/min. Lost 75 bbls mud to formation while running casing. Make up hanger and landing joint, land casing, lay down Franks tool and make up cement head. 15:00 - 17`00 2.00 CEMT P INT1 Break circulation, stage up pumps to 4 bpm, 720 psi, reciprocate pipe, losing 40 bph initially, losses dropped to zero after 45 minutes, increased rate to 6 bpm 780 psi, lost 67 bbls while circulating, Up wt = 270k do wt = 125k 17:00 - 19:45 2.75 CEMT P INTI Held PJSM with cementers and rig personnel. Pump 5 bbls water test lines to 4,000 psi, pump 65 bbls Mudpush weighted to 10.3 ppg, initial rate 4.7 bpm @ 570 psi, released bottom plug and pump 120 bbls 12.0 ppg class G lead cement, 4.8 bpm @ 610 psi, followed by 42 bbls 15.8 ppg class G tail cement, 4.7 bpm @ 380 psi, shut down wash up cement lines thru tee, release bottom plug, confirmed plug left head, displace with seawater @ 5 bpm, 200 psi, reciprocating pipe 15', final rate 5 bpm, 1,395 psi, slowed rate to 2 bpm 1,265 psi for last 30 bbls, landed casing 21 bbls from bumping plug, up wt = 230k, do wt = 85k, final rate 2 bpm, 1,340 psi, bumped plug with calculated strokes, pressured up to 2,000 psi, bled of pressure, floats held. CIP @ 19:45. Partial returns the last 55 bbls, flow decreased from 14% to 6%. 19:45 - 20:30 0.75 CEMT P INTI Rig down cement head and casing tools, back out and lay down landing joint, change out bails. 20:30 - 21:30 1.00 BOPSUF P INT1 Install and test 7" packoff to 5,000 psi, good test. 21:30 - 22:00 0.50 EVAL P INTI Lay down casing tools and clean floor. 22:00 - 00:00 2.00 EVAL P INT1 PJSM with Schlumberger E -line, Rig up wire line tools, RIH with 6.125" gauge ring junk basket, GR/CCL 5/6/2005 00:00 - 01:30 1.50 EVAL P INT1 RIH w/ 6.125" gauge ring junk basket to 8,680', POH lay down gauge ring junk basket. 01:30 - 05:30 4.00 EVAL P INT1 Make up Halliburton setting tool and EZSV, RIH, tie in with GR/CCL, set 7" EZSV @ 8,500', POH with setting tool, lay down setting tool, rig down Schlumberger. 05:30 - 07:00 1.50 BOPSUF P WEXIT Pull wear ring and install test plug, Change to rams to 3 1/2" x 6" variables, test to 3,500 psi, pull test plug and install wear ring. Clear 9 5/8" X 7" annulus with 114 bbls 10.2 ppg mud @ 3 bpm, broke over @ 675 psi, EMW 15.19 ppg, Freeze protect 9 5/8" X 7" annulus with 77 bbls dead crude with Little Red, final Printed: 5/16/2005 11:58:38 AM Legal Well Name: L-124 Common Well Name: L-124 Spud Date: 4/26/2005 Event Name: DRILL+COMPLETE Start: 4/24/2005 End: 5/14/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/14/2005 f Rig Name: NABOBS 9ES Rig Number: I r)nta IPrnm I Tn Nni ire II ' Tnete (`nrle' I KIPT=r I Phnom I Iflnerrintinn of llnnrotinne 05:30 - 07:00 1.50 BOPSUF P WEXIT rate & pressure @ 3 bpm, 900 psi. 07:00 - 08:30 1.50 EVAL P WEXIT Pressure test 7" casing to 3,500 psi for 30 min. record on chart. Witnessed by WSL Alan Madsen. 08:30 - 09:30 1.00 EVAL P WEXIT Pickup 9, 4 3/4" steel drill collars and rack in derrick. 09:30 - 12:00 2.50 EVAL P WEXIT Make up whipstock milling assembly and orient whistock, pickup 3 stands of 4 3/4" DC's and shallow test MWD, RIH to 1,116' 12:00 - 16:30 4.50 EVAL P WEXIT RIH with Whipstock milling assembly to 8,480' 16:30 - 17:00 0.50 STWHIP P WEXIT Break circulation, orient Whipstock to 35 left, up wt = 195k, do wt = 105k, wash down, tagged bridge plug at 8,505', set down 15k to set bottom trip anchor, picked up 10k to confirm set, set down to shear off whipstock sheared @ 30k. 17:00 - 19:00 1 2.001 STWHIP I P 19:00 - 21:45 1 2.751 STWHIP I P 21:45 -22:30 1 0.751 STWHIPI P 22:30 - 00:00 1 1.501 STWHIPI P 15/7/2005 100:00 - 00:30 1 0.501 STW HI P I P 00:30 - 01:00 1 0.501 STWHIP P 01:00 - 03:00 1 2.001 STWHIP P 03:00 - 05:00 1 2.001 STWHIP P 05:00 - 06:00 1.00 DRILL P 06:00 08:30 2.50 DRILL P 08:30 - 12:30 1 4.001 DRILL I P 12:30 - 13:30 1 1.001 DRILL IP 13:30 - 00:00 1 10.501 DRILL I P 15/8/2005 100:00 - 12:00 1 12.001 DRILL I P 12:00 - 14:30 1 2.501 DRILL I P Top of Whipstock @ 8,487' Bottom of Whipstock @ 8,499' WEXIT Displace well to 9.4 ppg Flo -Pro, 300 gpm, 1890 psi. W EXIT Mill window from 8,487' to 8,499'300 gpm, 1,760 psi, 100 rpm, torque 8k; 2-8k wob, good metal recovery at shakers. WEXIT Mill formation from 8,499' to 8,513', 10k wob, 300 gpm, 1,740 psi, 100 rpm torque 8k, up wt = 156k, do wt = 110k, WEXIT Pump High vis sweep, 300 gpm, 1,610 psi, worked mills through window several times with no rotary, window clean, sweep brought back considerable amount of metal cuttings. WEXIT Perform FIT, 8,513' md, 6,473' tvd, 9.3 ppg, pressure achieved 575 psi, EMW = 11.01 ppg. WEXIT Monitor well, pump dry job, blow down topdrive. WEXIT POH with milling assembly to BHA. WEXIT Stand back HW DP, lay down 4 3/4" DC's, inspect and lay down mills and MWD, upper string mill in gauge. PROW Make up flushing tool and flush BOP, function rams & HCR valves. PROD1 PJSM, make up BHA #5, Security FM 3641, Motor, bypass sub w/float, NM lead collar, MN stab, MWD/LWD, ADN, 2 NM flex collars, Circ sub, crossover sub, 1 joint 4" DP, Jars. PROD1 RIH to 1,064', shallow test MWD, continue to RIH from 1,064' to 8,426'. Filled pipe @ 4,046', 280 gpm, 1,540 psi. PROD1 Cut and slip drilling line, service blocks, topdrive and draw works. PROD1 Break circulation, orient motor to 35 left, shut down pumps and slide through window, no problems at window. Drill 6.125" hole from 8,513' to 8,891' sliding 100%, 5-10k wob, 280 gpm, 2,200 psi on bottom, 2,080 psi off bottom, up wt = 153k, do wt = 103k. AST = 7 hrs. PROD1 Directional drill 6.125" hole from 8,891' to 9,185', 5-10 k wob, 278 gpm, 2250 psi on bottom, 2,100 psi off bottom, up wt = 156k, do wt = 105k, rt wt = 123k, sliding 100% to achieve required turn rates, back ream each stand, 60 rpm, torque 7k, AST = 6.8 hrs. PROD1 Directional drill 6.125" hole from 9,185', 5-10 k wob, 278 gpm, 2250 psi on bottom, 2,100 psi off bottom, up wt = 156k, do wt = 105k, rt wt = 123k, completed planned turn @ 9,204' drill ahead from 9,204' to 9,291' in rotary mode, Topdrive blower failed. AST = 1.42 hrs Printed: 5/16/2005 11:58:38 AM Legal Well Name: L-124 Common Well Name: L-124 Spud Date: 4/26/2005 Event Name: DRILL+COMPLETE Start: 4/24/2005 End: 5/14/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/14/2005 Rig Name: NABOBS 9ES Rig Number: 5/8/2005 114:30 - 16:00 1 1.501 DRILL IN I RREP I PROD1 16:00 - 17:00 1.00 DRILL N RREP PRODi 17:00 - 21:00 4.00 DRILL N RREP PROD1 21:00 - 21:30 0.50 DRILL P PROD1 21:30 - 23:00 1.50 DRILL N RREP PROD1 23:00 - 00:00 1 1.001 DRILL IP I I PROD1 5/9/2005 100:00 - 12:00 1 12.001 DRILL I P I I PROD1 i 12:00 - 00:00 12.00 DRILL P I I PROW 5/10/2005 100:00 - 07:00 1 7.001 DRILL IP I I PROD1 07:00 - 08:30 1 1.501 DRILL I C I I PROW 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 10:30 1.50 DRILL X WAIT PRODi 10:30 - 12:30 2.00 DRILL C PROD1 12:30 - 15:30 3.00 DRILL C PROD1 15:30 - 00:00 8.50 DRILL C PROW 5/11/2005 100:00 - 06:00 1 6.001 DRILL I P I I PROD1 06:00 - 07:30 1 1.501 DRILL I P I I PROD1 07:30 - 08:30 1 1.001 DRILL IP I I PROD1 08:30 - 09:00 1 0.501 DRILL I P I I PROD1 Topdrive blower fan failed causing the electric motor to lockup, resulting in damage to electric motor, fan and fan housing. Set back one stand, monitor well, flowing back, mud coming back aired up. Circulate bottoms up, 280 gpm, 2,240 psi, no sign of gas or oil at bottoms up. Monitor well for 15 min. no flow, POH 9 stands to 8,426' Replace blower fan and motor, repair blower housing, test run blower ok. Service rig and topdrive. Monitor well, orient motor to 35 left, work through window, RIH to 9,291' Directional drill 6.125" hole from 9,291' to 9,321', 5k wob, 280 gpm, 2,300 psi on bottom, 2,020 psi off bottom, 60 rpm, torque on bottom 8k, torque off bottom 7k, up wt = 150k, do wt = 100k, rt wt = 125k ART= .45 hrs. Directional drill 6.125" hole from 9,321' to 9,919'5-10k wob, 285 gpm, 2,320 psi on bottom, 2,275 psi off bottom, 60 rpm, torque on bottom 6k, torque off bottom 5.5k, up wt = 151k, do wt = 100k, rt wt = 125k. AST = 2.85 hrs. ART = 4.95 hrs. Directional drill 6.125" hole from 9,919' to 10,450', 5-10k wob, 280 gpm, 2,250 psi on bottom, 2,175 psi off bottom, 60 rpm, torque on bottom 7k, torque off bottom 5.5k, up wt = 153k, do wt = 102k, rt wt = 126k. AST = 3.94 hrs. ART = 3.69 hrs. Directional drill 6.125" hole from 10,450' to 10,616'5-10k wob, 287 gpm, 2,377 psi on bottom, 2,260 psi off bottom, 60 rpm, torque on bottom 7k, torque off bottom 6k, up wt = 153k, do wt = 99k, rt wt = 123k. AST = 2.86 hrs. ART = 3.21 hrs. Drilled into the Kalubik. Continue to drill ahead looking for the C-3 zone - unsuccessful. Pump out of the hole from 10,616' to the window @ 8,487', 280 gpm, 2,200 psi, PU - 173K, SO - 106K. Hole appears to be in good shape. Service the top drive and the crown. Wait on orders. Decision made to open hole sidetrack. Orient 35 LHS and slide through the window. RIH to 10,235'. Fill pipe and monitor the well - stable. Open hole sidetrack the well from 10,235' to 10,290'. Directional drill 6.125" hole from 10,290' to 10,604'5-10k wob, 287 gpm, 2,450 psi on bottom, 2,240 psi off bottom, 60 rpm, torque on bottom 7k, torque off bottom 6k, up wt = 152k, do wt = 100k, rt wt = 125k. AST = 4.11 hrs. ART = 2.28 hrs. Directional drill 6.125" hole from 10,604' to 10,774' (TD), 5-10k wob, 287 gpm, 2,430 psi on bottom, 2,275 psi off bottom, 60 rpm, torque on bottom 8k, torque off bottom 7k, up wt = 152k, do wt = 103k, rt wt = 122k, AST - 3.56, ART - 1.34. Drilled -50' into the Kalubik shale. Pump out of the hole to 10,665', -59' above the top of the Kalubik. Pump hi-visc sweep while reciprocating pipe - 280 gpm, 2,132 psi, 60 rpm. Monitor the well - stable. Attempt POH without pumps - swabbing. MU top drive and pump out of the hole to 10,106'- 270 gpm, 1,990 psi. PU - 150K, SO - 100K. Monitor well -stable. RIH from 10,109' to 10,700'. Printed: 5/16/2005 11:58:38 AM BP Page 8 of 10 Operations Summary Report Legal Well Name: L-124 Common Well Name: L-124 Spud Date: 4/26/2005 Event Name: DRILL+COMPLETE Start: 4/24/2005 End: 5/14/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/14/2005 Rig Name: NABORS 9ES Rig Number: Date From`-To Hours TaskCode NPT f Phase Description of Operations 5/11/2005 09:00 - 10:30 1.50 DRILL P PROD1 Circulate hi-visc sweep while reciprocating pipe - 280 gpm, 2,335 psi, 60 rpm. Monitor the well - stable. 10:30 - 14:00 3.50 DRILL P PROD1 Attempt to POH without pumps - swabbing. Pump out of the hole from 10,700' to 8,613'- PU - 150K, SO - 100K, 255 gpm, 1,862 psi. 14:00 - 15:00 1.00 DRILL P PROD1 Drop ball and open up the circ sub. Wash across the window. Pull bit inside window without the pumps on. Pump hi-visc sweep - 300 gpm, 1,350 psi. 15:00 - 17:00 2.00 DRILL P PROD1 Monitor well - stable. Attempt to POH without pumps from 8,480' to 7,679'- swabbing. 17:00 - 17:30 0.50 DRILL P PROD1 RIH from 7,679' to 8,480'. 17:30 - 18:30 1.00 DRILL P PROD1 Monitor well - stable. Circulate from surface to surface @ 8,480'- 300 gpm, 1,250 psi, 80 rpm. Monitor well - stable. 18:30 - 00:00 5.50 DRILL P PROD1 Attempt to POH without pumps - swabbing. Pump out of the hole from 8,480' to 5,997' - 126 gpm, 480 psi. 5/12/2005 00:00 - 02:45 2.75 DRILL P PROD1 Pump out of the hole from 5,997' to 4,506'- 126 gpm, 480 psi. POH without pumps from 4,506' to 224'. 02:45 - 04:30 1.75 DRILL P PRODi LD BHA #5 from 224'- jars, 1 x 4" DP, XO, circ sub, 2 x nm flex dc's, ADN, MWD/LWD, nm stab, nm float sub, nm lead collar, nm bypass sub, motor, 6.125" bit (1/2/CT/G/X/I/WT/TD). PJSM held prior to removing nuclear source. 04:30 - 05:00 0.50 DRILL P PROD1 Clear and clean the rig floor. 05:00 - 06:00 1.00 CASE P PROD1 RU casing handling tools and equipment. 06:00 - 09:00 3.00 CASE P PROD1 PJSM. PU 4.5" 12.6# L-80 IBT-M liner to 2,450' and RIH - float shoe, 1 x solid, xo, 6 x slotted, 3 x soild (RA tag in the upper box end), 25 x slotted, 4 x solid (RA tag in the upper box end), 17 x slotted, 2 x solid, pup joint, xo, HMC hanger, ZXP liner top packer with 11.41' tieback (5.25" ID), C-2 running tool. Use Best-o-life 2000 thread lubricant and torque to the mark - 2,600 ft-lbs. PU - 60K, SO - 50K. RD casing handling equipment. 09:00 - 12:00 3.00 CASE P PROD1 RIH with 4.5" Liner on 4" DP to the top of the window @ 8,487'. 12:00 - 12:30 0.50 CASE P PROD1 Circulate pipe volume at the window - 3 bpm, 480 psi. 12:30 - 14:00 1.50 CASE P PROD1 PU - 158K, SO - 103K. RIH with 4.5" liner on 4" DP from 8,487to 10,653'. 14:00 - 15:00 1.00 CASE P PROD1 Screw in with the top drive and pump down from 10,653' to 10,717'. Break out a single and drop ball. Space out and place the shoe @ 10,727'- PU - 175K, SO - 102K. Pump ball on seat and pressure up to 3,500 psi to set the hanger. SO to 50K. Rotate 16 turns to the right to release. With rotation, set down 80K and set the liner top packer. PU above the top of the liner @ 8,285'. Float Shoe - 10727' RA Tag - 10306' RA Tag - 9102' Top HMC 7" x 5" HMC Liner Hanger - 8303' Top 7" x 5" ZXP Liner Top Packer w/11.41', 5.25" ID tieback - 8285' 15:00 - 17:30 2.50 CASE P PROD1 PJSM. Displace the well over to 9.4 ppg brine - 223 gpm, 850 psi, PU - 155K, SO - 107K. Clean possum bellies, troughs and underneath the shakers. 17:30 - 19:30 2.00 CASE P PROD1 Monitor the well - flowing. Circulate bottoms up - 183 gpm, 470 psi. Monitor the well - flowing. Circulate 9.6 ppg brine around - Printed: 5/16/2005 11:58:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-124 L-124 DRILL+COMPLETE NABORS ALASKA DRILLING I NABOBS 9ES Start: 4/24/2005 Rig Release: 5/14/2005 Rig Number: 5/12/2005 17:30 - 19:30 1 2.001 CASE P PROD1 19:30 - 00:00 1 4.501 CASE P PROD1 5/13/2005 00:00 - 03:45 3.75 CASE P PROD1 03:45 - 05:00 1.25 CASE P PROD1 05:00 - 06:30 1.50 CASE P PROD1 06:30 - 09:00 2.50 CASE P PROD1 09:00 - 12:00 3.00 RUNCOMP RUNCMP 12:00 - 14:00 2.00 BUNCO RUNCMP 14:00 00:00 10.00 BUNCO RUNCMP 5/14/2005 00:00 - 02:15 2.25 RUNCO � RUNCMP 7 02:15 - 04:45 1 2.501 RUNCOM1VP I I RUNCMP 04:45 - 07:30 1 2.751 RUNCOMP I RUNCMP 07:30 - 10:00 I 2.501 RUNCOW I I RUNCMP Spud Date: 4/26/2005 End: 5/14/2005 185 gpm, 465 psi. Monitor the well - static. LDDP from 8,285'. Well taking proper displacement. Continue LDDP from 8,285'. Well taking proper displacement. RIH with 30 stands of 4" DP from the derrick. CBU. Slip and cut drilling line. Service top drive, blocks and crown. LD 4" DP. Monitor well - static. Pull wear ring and make a dummy run with the hanger. Changeout the bails and rig up the tubing handling equipment. RU Halliburton spooling unit. MU 3-1/2 Tailpipe and jewelry. Attach I wire. All connections below paker have been Bakerloc'd. PU 3-1/2" 9.3# L-80 IBT-M tubing placing jewelry per running detail and RIH to 6,500'. Use Best -o -life 2000 thread lubricant. Each connection torqued to the mark with 2,400 Ribs. Place I wire clamp on each connection as well as above and below each GLM. Continue to run 3-1/2" completion. PU 258 joints of 3-1/2" tubing, 7 GLM's, 4 X profiles, Premier Packer and HES Gauge carrier on I wire. RU to circulate while RIH - 2 bpm, 135 psi. Saw no indication of pressure increase as the WLEG entered the tieback sleeve. Tagged the bottom of the tieback sleeve with 10.5' in on joint # 258. LD 3-1/2" joints 258, 257 and 256. Cross-over to 4-1/2" 12.6# L-80 IBT-M. MU joint of 4-1/2" tubing, pup joint and tubing hanger on landing joint. Cut 1 -wire and test. Land tubing on hanger. RILDS. PU - 110K, SO - 75K. Rana total of 263 full clamps, 15 mid clamps and 2 stainless steel bands. WLEG - 8290' X profile (2.813") w/RHCM - 8278' X profile (2.813") - 8527' 7" x 3.5" Premier Packer - 8231' HES Gauge Carrier - 8212' X Profile (2.813") - 8191' GLM#1 - 8132' GLM#2 - 7054' GLM#3 (Shear valve) - 6217' GLM#4 - 5368' GLM#5 - 4405' GLM#6 - 3222' GLM#7 - 2318' X Profile (2.813") - 2016' RU to circulate. Clear and clean the floor. Circulate bottoms up with 9.6 ppg brine. Reverse circulate 9.6 ppg brine with Cl and chase with 9.6 ppg brine to spot between GLM #3 and the Premier packer. Drop 1-5/16" ball and rod (with rollers) and allow to set in RHC -M profile @ 8,278'. Pressure up on the tubing to 4,200 psi, chart and hold for 30 minutes - good test. Bleed pressure down to 2,500 psi. Pressure up on the annulus to 3,500 psi, chart and hold for 30 minutes - good test. Bleed pressure off of the annulus and then the tubing. Pressure up on the annulus Printed: 5/16/2005 11:58:38 AM Legal Well Name: L-124 Common Well Name: L-124 Spud Date: 4/26/2005 Event Name: DRILL+COMPLETE Start: 4/24/2005 End: 5/14/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/14/2005 Rig Name: S uI NABOR 9ES Rig Number: rlata I FrnmI '- Tn Pn rc Tack Ilr.nrta'I RIPT'I Phaco I nacrrintinn of ()narntinnc 5/14/2005 107:30 - 10:00 1 2.50 10:00 - 10:30 0.50 WHSUR P 10:30 - 11:00 0.50 RUNCO 11:00 - 13:00 2.00 BOPSU P 13:00 - 16:00 3.00 WHSUR P 16:00 - 17:00 1.00 WHSUR P 17:00 - 18:30 1.50 RUNCO 18:30 - 21:00 2.50 BUNCOVP 21:00 23:00 2.00 WHSUR P RUNCMP to shear the DCR valve in GLM#3 @ 6,217'- good shear. Circulate @ 3 bpm and 400 psi to verify shear. Blow down surface lines and LD landing joint. RUNCMP Install TWC and test from below with 1,000 psi - good test. RUNCMP RD tubing handling equipment. Changeout bails and elevators. RUNCMP ND BOP's RUNCMP NU adapter flange. Splice and secure I -wire. RUNCMP NU 4-1/8" tree and test to 5,000 psi - good test. RUNCMP PJSM on freeze protecting the well. RU LRHOS and test lines to 3,500 psi. Pump 155 bbls of diesel freeze protection fluid down the annulus @ 3bpm. Initial - 400 psi, Final - 1,000 psi RUNCMP Allow fluids to u -tube. Left 425 psi on the tubing/annulus following u -tube due to well being underbalanced. RUNCMP Install BPV with DSM lubricator and test from below with 1,000 psi. Install VR plugs in the OA and IA with DSM. Secure the well for the rig move. Release the rig @ 2300 hours, 5/14/2005 Printed: 5/16/2005 11:58:38 AM by I Schlumberger Revort Report Date: 11 -May -05 Inclination Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Along Hole Vertical Section Azimuth: 344.720° Field: Prudhoe Bay Unit - WOA Northing Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot:L-PAD / L-124 Depth TVD Reference Datum: Rotary Table Well: L-124 Section TVD Reference Elevation: 76.80 ft relative to MSL Borehole: L-124 Sea Bed 1 Ground Level Elevation: 48.30 ft relative to MSL UWIIAPI#: 500292325500 Magnetic Declination: 24.472° Survey Name I Date: L-124 / May 11, 2005 ft Total Field Strength: 57611.547 nT Tort / AHD / DDI / ERD ratio: 283.924° / 7359.91 ft / 6.540 / 1.132 ft Magnetic Dip: 80.811 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet 0.23 Declination Date: May 10, 2005 Location Lat/Long: N 70.35052701, W 149.32591439 0.50 Magnetic Declination Model: BGGM 2004 Location Grid N/E Y/X: N 5978240.590 ftUS, E 583025.790 ftUS 1.82 North Reference: True North Grid Convergence Angle: +0.63483521' 1.62 Total Corr Mag North •> True North: +24.472° Grid Scale Factor: 0.99990783 1.86 Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub -Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude U.UU Depth First GYD GC MS 100.00 0.20 Section Departure 23.20 100.00 0.05 0.17 0.17 0.00 ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS 0.47 0.23 RIE U.UU U.uu U.UU -/ti.dU u.uU U.Uu U.uU U.Uu u.Uu u.UU U.UU OW044U.M1 First GYD GC MS 100.00 0.20 271.64 23.20 100.00 0.05 0.17 0.17 0.00 -0.17 0.20 5978240.59 200.00 0.33 49.75 123.20 200.00 0.22 0.47 0.23 0.20 -0.13 0.50 5978240.78 300.00 1.82 21.25 223.18 299.98 1.62 2.32 1.98 1.86 0.67 1.54 5978242.46 400.00 2.70 5.81 323.10 399.90 5.09 6.24 5.88 5.69 1.48 1.06 5978246.29 500.00 3.78 359.68 422.94 499.74 10.48 11.89 11.45 11.33 1.70 1.13 5978251.93 600.00 5.59 349.43 522.60 599.40 18.52 20.04 19.43 19.41 0.79 1.99 5978260.01 700.00 7.64 345.53 621.93 698.73 30.02 31.55 30.69 30.64 -1.77 2.10 5978271.20 800.00 10.20 343.51 720.72 797.52 45.52 47.05 45.95 45.56 -5.94 2.58 5978286.08 850.00 10.96 342.90 769.87 846.67 54.70 56.23 55.03 54.35 -8.60 1.54 5978294.84 900.00 13.75 343.59 818.70 895.50 65.39 66.93 65.64 64.60 -11.67 5.59 5978305.05 950.00 14.85 343.00 867.15 943.95 77.74 79.28 77.93 76.43 -15.22 2.22 5978316.84 1000.00 17.34 344.83 915.19 991.99 91.59 93.14 91.75 89.75 -19.05 5.08 5978330.11 1050.00 19.56 344.20 962.62 1039.42 107.42 108.96 107.54 104.99 -23.28 4.46 5978345.31 1100.00 20.97 344.73 1009.52 1086.32 124.73 126.28 124.84 121.68 -27.91 2.84 5978361.94 1150.00 23.54 345.82 1055.79 1132.59 143.67 145.21 143.77 139.99 -32.72 5.21 5978380.20 Last GYD GC MS 1189.00 24.93 345.83 1091.35 1168.15 159.67 161.22 159.77 155.51 -36.64 3.56 5978395.67 First MWD+IFR+MS 1223.53 26.97 347.57 1122.40 1199.20 174.77 176.33 174.88 170.22 -40.10 6.31 5978410.34 1318.56 30.12 350.35 1205.87 1282.67 220.04 221.73 220.24 214.78 -48.74 3.60 5978454.80 1411.57 33.23 353.54 1285.02 1361.82 268.46 270.55 268.92 263.13 -55.52 3.80 5978503.06 1503.89 37.07 353.91 1360.50 1437.30 320.94 323.69 321.85 315.95 -61.32 4.17 5978555.81 1597.02 42.40 353.85 1432.09 1508.89 379.69 383.20 381.18 375.12 -67.67 5.72 5978614.90 1691.41 48.99 356.15 1497.99 1574.79 446.10 450.71 448.43 442.37 -73.48 7.20 5978682.08 D03ULD./ti IV/U.3000L/UI vv-14`J.3ZDUII+3V 583025.62 N 70.35052702 W 149.32591581 583025.66 N 70.35052755 W 149.32591544 583026.44 N 70.35053210 W 149.32590898 583027.21 N 70.35054254 W 149.32590237 583027.36 N 70.35055795 W 149.32590059 583026.36 N 70.35058004 W 149.32590799 583023.68 N 70.35061070 W 149.32592873 583019.34 N 70.35065149 W 149.32596262 583016.59 N 70.35067550 W 149.32598417 583013.40 N 70.35070349 W 14915 583009.72 N 70.35073580 W 149. 99 583005.75 N 70.35077219 W 149.32 06903 583001.35 N 70.35081384 W 149.32610336 582996.53 N 70.35085943 W 149.32614099 582991.53 N 70.35090946 W 149.32617999 582987.44 N 70.35095186 W 149.32621181 582983.81 N 70.35099203 W 149.32623996 582974.68 N 70.35111378 W 149.32631009 582967.36 N 70.35124585 W 149.32636514 582960.98 N 70.35139016 W 149.32641223 582953.98 N 70.35155181 W 149.32646376 582947.42 N 70.35173553 W 149.32651091 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -1241-124\L-124 Generated 5/17/2005 11:27 AM Page 1 of 5 Comments Measured inclination Azimuth Sub -Sea TO TO Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude 354.60 Depth 2063.32 356.63 48.71 I Section I Departure 2156.39 4299.33 47.68 48.21 352.60 358.47 2250.51 940.81 47.61 ft deg de ft ft ft ft ft ft ft de /100 ft ftUS ftUS 353.37 48.52 I /U.bI 5980256.12 bU.ZJ job.:iv 3920.43 1876.53 47.88 48.39 355.58 355.33 N 70.35622947 1971.48 1880.41 48.87 4107.15 354.60 47.04 2063.32 356.63 48.71 582804.63 352.62 N 70.35528499 W 149.32755373 2156.39 4299.33 47.68 48.21 352.60 358.47 2250.51 940.81 47.61 937.91 353.04 4485.81 2344.98 47.23 48.30 359.69 353.62 2132.23 2439.32 1065.84 47.74 4671.46 353.37 48.52 2531.44 358.29 47.60 1960.20 354.75 1948.34 2625.95 4859.58 48.38 46.89 355.43 356.33 2718.09 1215.03 48.26 0.63 354.82 5043.16 2810.94 42.99 48.26 353.84 354.39 5980949.59 2905.05 47.71 5229.31 353.70 36.72 2997.88 351.91 47.32 N 70.35812567 354.34 3092.44 5416.91 46.68 33.93 353.91 351.82 3184.34 2.89 46.34 582728.48 353.95 N 70.35848040 3267.71 45.04 5981209.10 355.35 3361.06 W 149.32812715 46.28 2.70 354.23 582711.92 3454.83 N 70.35880127 47.62 356.46 5981319.34 3546.94 48.34 W 149.32825443 355.61 0.40 3640.51 582695.35 48.21 N 70.35909068 356.83 3733.20 5981422.70 47.78 356.40 W 149.32836967 3827.42 5980256.12 48.44 355.24 3920.43 1818.38 47.88 722.39 355.58 4013.97 N 70.35622947 46.74 1880.41 356.18 4107.15 -201.89 47.04 2.25 356.63 4205.93 582804.63 48.71 N 70.35528499 W 149.32755373 357.37 4299.33 867.77 48.21 1.78 358.47 4393.07 940.81 47.70 937.91 358.91 4485.81 998.64 47.23 1010.94 359.69 4579.05 2132.23 47.97 1065.84 358.02 4671.46 N 70.35718313 48.52 2195.48 358.29 4765.16 1960.20 47.65 1948.34 357.81 4859.58 1.54 46.89 5980186.24 356.33 4951.15 1215.03 45.59 0.63 354.65 5043.16 1287.36 42.99 1284.29 353.84 5136.17 5980949.59 39.23 352.25 5229.31 36.72 5981018.80 351.91 5322.70 N 70.35812567 34.28 351.59 5416.91 582735.62 33.93 N 70.35830578 351.82 5509.82 2.89 33.67 582728.48 353.59 1001 Joe 1618.31 1681.07 1741.58 1803.61 1867.03 1930.29 1993.39 2055.43 2118.68 2179.95 2241.77 1UJJ.`JZ 014.ZU OZU.LZ 311.04 011.13 -/O.UU 1.3/ Oy/O/O 1.00 1695.11 584.02 591.38 588.61 582.71 -83.13 2.14 5978822.29 1757.87 5980256.12 654.14 662.64 659.77 1818.38 5979911.50 722.39 582776.74 731.73 N 70.35622947 728.84 1880.41 1741.64 791.11 -201.89 801.10 2.25 798.22 1943.83 582804.63 859.97 N 70.35528499 W 149.32755373 870.65 1821.66 867.77 2007.09 1.78 929.33 582761.39 940.81 5980047.92 937.91 2070.19 1.03 998.64 582758.07 1010.94 N 70.35699301 1008.03 2132.23 -211.23 1065.84 0.98 1079.04 N 70.35718313 1076.11 2195.48 N 70.35566185 W 149.32762959 1134.91 1960.20 1149.26 1948.34 1146.27 2256.75 1.54 1202.60 5980186.24 1218.08 582788.94 1215.03 2318.57 0.63 1270.85 582748.99 1287.36 N 70.35774608 1284.29 2304.76 2381.56 1339.85 2367.45 2444.25 1407.41 2431.94 2508.74 1475.63 2495.19 2571.99 1541.45 2553.43 2630.23 1600.21 2618.67 2695.47 1665.94 2682.69 2759.49 1733.28 2744.34 2821.14 1800.37 2806.62 2883.42 1868.81 2868.65 2945.45 1936.20 2931.56 3008.36 2005.03 2993.60 3070.40 2073.12 3057.03 3133.83 2140.57 3120.71 3197.51 2207.19 3186.96 3263.76 2278.77 3248.90 3325.70 2346.83 3311.68 3388.48 2414.38 3374.37 3451.17 2480.52 3437.25 3514.05 2547.29 3498.79 3575.59 2614.34 3561.38 3638.18 2682.18 3625.45 3702.25 2749.93 3688.79 3765.59 2814.89 3754.64 3831.44 2878.25 3824.71 3901.51 2938.74 3898.13 3974.93 2995.57 3974.15 4050.95 3049.39 4052.16 4128.96 3101.82 4129.37 4206.17 3153.00 653.69 722.35 791.15 860.15 929.83 999.51 1067.25 1137.21 1205.78 1274.75 1357.28 1354.20 1344.30 1425.74 1422.64 1412.38 1494.90 1491.79 1481.17 1561.57 1558.46 1547.47 1621.22 1618.09 1606.86 1687.98 1756.50 1824.93 1894.77 1963.64 2033.78 2103.07 2171.83 2239.85 2313.11 2383.02 2452.63 2520.97 2589.82 2658.76 2728.48 2797.84 2863.97 2928.21 2989.35 3046.66 3100.89 3153.71 3205.40 -89.38 -97.07 -105.99 -114.68 -122.83 -130.78 -137.82 -143.83 -149.68 -156.19 -163.45 -170.58 -177.66 -184.71 -190.28 0.77 5978893.19 1.63 5978961.75 1.11 5979030.44 0.35 5979099.34 0.86 5979168.92 0.63 5979238.50 1.12 5979306.14 0.98 5979376.03 0.51 5979444.52 0.35 5979513.41 0.80 5979582.87 0.66 5979650.86 0.75 5979719.56 0.37 5979785.78 1.97 5979845.10 OO1`J44. 14 IN IU.JOI UZOUZ VV 14U.JZ004101 582936.22 N 70.35211893 W 149.32658926 582929.18 N 70.35231284 W 149.32664005 582920.73 N 70.35250040 W 149.32670247 582911.05 N 70.35268835 W 149.32677492 582901.59 N 70.35287687 W 149.32684551 582892.68 N 70.35306723 W 149.32691166 582883.96 N 70.35325758 W 149.32697617 582876.16 N 70.35344262 W 149.32703341 582869.38 N 70.35363376 W 149.32708220 582862.78 N 70.35382108 W 149.309 582855.50 N 70.35400951 W 149.3 9 582847.48 N 70.35419950 W 149.32724148 582839.59 N 70.35438550 W 149.32729941 582831.75 N 70.35457343 W 149.32735689 582823.97 N 70.35475455 W 149.32741415 582817.74 N 70.35491681 W 149.32745939 1684.83 5980256.12 1673.35 -196.35 W 149.32770418 1.58 5979911.50 582810.94 582776.74 N 70.35509844 W 149.32750868 N 70.35622947 1753.30 1741.64 5980393.63 -201.89 2.25 5979979.72 582804.63 5980461.47 N 70.35528499 W 149.32755373 1821.66 W 149.32782404 1809.90 1.78 -206.63 582761.39 1.04 5980047.92 W 149.32785514 582799.14 1.03 N 70.35547148 W 149.32759219 582758.07 1891.41 N 70.35699301 1879.58 578 -211.23 5980673.96 0.98 5980117.54 N 70.35718313 582793.77 73 N 70.35566185 W 149.32762959 5980742.27 1960.20 1948.34 W 149. -215.30 1.54 0.58 5980186.24 582788.94 W 149.32790678 N 70.35584968 W 149.32766262 0.63 2030.29 2099.55 2168.26 2236.23 2309.39 2379.14 2448.54 2516.62 2585.27 2654.08 2723.68 2792.98 2859.11 2923.35 2984.46 3041.70 3095.86 3148.61 3200.27 2018.29 2087.36 2155.94 2223.83 2296.99 2366.85 2436.44 2504.77 2573.61 2642.51 2712.19 2781.45 2847.38 2911.30 2971.99 3028.75 3082.42 3134.69 3185.96 -220.41 -225.96 -230.90 -235.17 -238.99 -241.53 -243.13 -243.96 -245.34 -247.56 -249.93 -253.47 -258.66 -265.09 -272.47 -280.36 -288.13 -295.76 -302.32 1.15 5980256.12 582783.05 N 70.35604078 W 149.32770418 0.66 5980325.12 582776.74 N 70.35622947 W 149.32774923 1.31 5980393.63 582771.04 N 70.35641681 W 149.32778939 0.48 5980461.47 582766.02 N 70.35660229 W 149.32782404 1.78 5980534.57 582761.39 N 70.35680215 W 149.32785514 1.03 5980604.39 582758.07 N 70.35699301 W 149.3 578 0.65 5980673.96 582755.71 N 70.35718313 W 149, 73 0.80 5980742.27 582754.12 N 70.35736980 W 149. 554 1.54 5980811.08 582751.97 N 70.35755785 W 149.32790678 0.63 5980879.94 582748.99 N 70.35774608 W 149.32792482 1.00 5980949.59 582745.85 N 70.35793646 W 149.32794409 1.40 5981018.80 582741.54 N 70.35812567 W 149.32797285 1.94 5981084,66 582735.62 N 70.35830578 W 149.32801501 2.89 5981148.50 582728.48 N 70.35848040 W 149.32806726 4.20 5981209.10 582720.44 N 70.35864621 W 149.32812715 2.70 5981265.77 582711.92 N 70.35880127 W 149.32819125 2.62 5981319.34 582703.55 N 70.35894788 W 149.32825443 0.40 5981371.52 582695.35 N 70.35909068 W 149.32831634 1.10 5981422.70 582688.22 N 70.35923073 W 149.32836967 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -124\L -124\L-124 Generated 5/17/2005 11:27 AM Page 2 of 5 U.Lb Sao"14/4.Ub D?J;4bbZ.U3 N /U.3ba3/11L VV'149.3Zb4'1bJb 0.47 5981525.55 582675.86 N 70.35951210 W 149.32846080 0.09 5981576.20 582669.72 N 70.35965065 W 149.32850614 0.28 5981626.54 582663.54 N 70.35978836 W 149.32855186 0.45 5981675.94 582657.13 N 70.35992351 W 149.32859950 1.28 5981726.52 582650.86 N 70.36006190 W 149.32864586 0.54 5981778.06 582645.35 N 70.36020287 W 149.32868596 1.27 5981830.61 582640.01 N 70.36034658 W 149.32872469 0.11 5981884.73 582634.40 N 70.36049462 W 149.32876538 0.41 5981938.44 582628.59 N 70.36064152 W 149.32880772 0.17 5981991.11 582622.79 N 70.36078558 W 149.311 0.30 5982043.28 582617.31 N 70.36092829 W 149.3288�J98 0.75 5982095.57 582611.68 N 70.36107130 W 149.32893104 0.49 5982146.35 582605.87 N 70.36121021 W 149.32897370 0.56 5982197.31 582599.79 N 70.36134963 W 149.32901845 0.42 5982247.35 582593.47 N 70.36148652 W 149.32906537 0.53 5982297.49 582586.72 N 70.36162370 W 149.32911571 2.15 5982346.70 582578.21 N 70.36175839 W 149.32918036 4.46 5982395.90 582565.41 N 70.36189321 W 149.32927999 0.56 5982447.14 582549.14 N 70.36203368 W 149.32940753 3.51 5982497.65 582530.55 N 70.36217223 W 149.32955400 4.26 5982549.97 582506.67 N 70.36231590 W 149.32974333 4.17 5982602.98 582477.42 N 70.36246160 W 149.32997617 4.72 5982656.72 582441.85 N 70.36260948 W 149.33026028 4.59 5982710.46 582400.75 N 70.36275755 W 149.33058934 1.89 5982765.00 582355.86 N 70.36290788 W 149.33094912 3.36 5982820.42 582307.02 N 70.36306075 W 149.33134088 2.11 5982874.50 582255.94 N 70.36321004 W 149.3 103 2.89 5982928.44 582202.04 N 70.36335902 W 149.103 4.25 5982983.69 582143.42 N 70.36351174 W 149. 535 5.42 5983038.32 582082.91 N 70.36366277 W 149.33314200 6.30 5983087.91 582025.04 N 70.36380000 W 149.33360767 16.02 5983095.05 582016.25 N 70.36381977 W 149.33367846 5.38 5983103.39 582005.68 N 70.36384287 W 149.33376359 10.40 5983114.43 581991.40 N 70.36387346 W 149.33387861 10.69 5983132.36 581967.52 N 70.36392316 W 149.33407101 10.06 5983150.21 581942.87 N 70.36397267 W 149.33426969 16.86 5983167.95 581917.47 N 70.36402188 W 149.33447443 4.51 5983185.30 581891.71 N 70.36407006 W 149.33468218 11.19 5983201.79 581866.34 N 70.36411586 W 149.33488678 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -124\L -124\L-124 Generated 5/17/2005 11:27 AM Page 3 of 5 Measured 33.DL 303.U3 Vertical Along Hole 4LO4.UD 3LU9.Ua 3L0/.l3 3L3L.UU 3L3/A0 -3V/.a4 Comments Inclination Azimuth Sub -Sea ND TO 353.69 Closure NS EW US Northing Easting Latitude Longitude Depth 5791.30 33.02 Section I Departure 4364.57 4441.37 3305.71 3360.02 3354.88 3339.67 ft de de ft ft ft ft ft 1t ft(deg/100 it (ftus ftus 3410.74 U.Lb Sao"14/4.Ub D?J;4bbZ.U3 N /U.3ba3/11L VV'149.3Zb4'1bJb 0.47 5981525.55 582675.86 N 70.35951210 W 149.32846080 0.09 5981576.20 582669.72 N 70.35965065 W 149.32850614 0.28 5981626.54 582663.54 N 70.35978836 W 149.32855186 0.45 5981675.94 582657.13 N 70.35992351 W 149.32859950 1.28 5981726.52 582650.86 N 70.36006190 W 149.32864586 0.54 5981778.06 582645.35 N 70.36020287 W 149.32868596 1.27 5981830.61 582640.01 N 70.36034658 W 149.32872469 0.11 5981884.73 582634.40 N 70.36049462 W 149.32876538 0.41 5981938.44 582628.59 N 70.36064152 W 149.32880772 0.17 5981991.11 582622.79 N 70.36078558 W 149.311 0.30 5982043.28 582617.31 N 70.36092829 W 149.3288�J98 0.75 5982095.57 582611.68 N 70.36107130 W 149.32893104 0.49 5982146.35 582605.87 N 70.36121021 W 149.32897370 0.56 5982197.31 582599.79 N 70.36134963 W 149.32901845 0.42 5982247.35 582593.47 N 70.36148652 W 149.32906537 0.53 5982297.49 582586.72 N 70.36162370 W 149.32911571 2.15 5982346.70 582578.21 N 70.36175839 W 149.32918036 4.46 5982395.90 582565.41 N 70.36189321 W 149.32927999 0.56 5982447.14 582549.14 N 70.36203368 W 149.32940753 3.51 5982497.65 582530.55 N 70.36217223 W 149.32955400 4.26 5982549.97 582506.67 N 70.36231590 W 149.32974333 4.17 5982602.98 582477.42 N 70.36246160 W 149.32997617 4.72 5982656.72 582441.85 N 70.36260948 W 149.33026028 4.59 5982710.46 582400.75 N 70.36275755 W 149.33058934 1.89 5982765.00 582355.86 N 70.36290788 W 149.33094912 3.36 5982820.42 582307.02 N 70.36306075 W 149.33134088 2.11 5982874.50 582255.94 N 70.36321004 W 149.3 103 2.89 5982928.44 582202.04 N 70.36335902 W 149.103 4.25 5982983.69 582143.42 N 70.36351174 W 149. 535 5.42 5983038.32 582082.91 N 70.36366277 W 149.33314200 6.30 5983087.91 582025.04 N 70.36380000 W 149.33360767 16.02 5983095.05 582016.25 N 70.36381977 W 149.33367846 5.38 5983103.39 582005.68 N 70.36384287 W 149.33376359 10.40 5983114.43 581991.40 N 70.36387346 W 149.33387861 10.69 5983132.36 581967.52 N 70.36392316 W 149.33407101 10.06 5983150.21 581942.87 N 70.36397267 W 149.33426969 16.86 5983167.95 581917.47 N 70.36402188 W 149.33447443 4.51 5983185.30 581891.71 N 70.36407006 W 149.33468218 11.19 5983201.79 581866.34 N 70.36411586 W 149.33488678 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -124\L -124\L-124 Generated 5/17/2005 11:27 AM Page 3 of 5 ODU3.3G 33.DL 303.U3 4N/.LO 4LO4.UD 3LU9.Ua 3L0/.l3 3L3L.UU 3L3/A0 -3V/.a4 5697.77 33.10 353.69 4286.18 4362.98 3255.31 3309.00 3303.86 3288.95 -313.54 5791.30 33.02 353.75 4364.57 4441.37 3305.71 3360.02 3354.88 3339.67 -319.12 5884.67 32.79 353.51 4442.96 4519.76 3355.82 3410.74 3405.59 3390.08 -324.75 5977.02 32.50 352.97 4520.72 4597.52 3405.08 3460.56 3455.40 3439.55 -330.61 6070.61 33.51 354.16 4599.21 4676.01 3455.45 3511.54 3506.37 3490.20 -336.31 6164.15 33.80 354.91 4677.07 4753.87 3506.53 3563.38 3558.21 3541.80 -341.25 6257.67 34.98 354.74 4754.24 4831.04 3558.53 3616.20 3611.03 3594.41 -346.02 6352.48 35.08 354.70 4831.88 4908.68 3612.13 3670.62 3665.45 3648.60 -351.02 6446.81 34.80 354.23 4909.20 4986.00 3665.37 3724.64 3719.47 3702.37 -356.23 6539.74 34.73 354.47 4985.55 5062.35 3717.62 3777.63 3772.46 3755.11 -361.45 6632.08 34.52 354.80 5061.53 5138.33 3769.30 3830.10 3824.93 3807.34 -366.36 6725.61 33.91 354.17 5138.87 5215.67 3821.13 3882.69 3877.52 3859.69 -371.41 6817.78 33.46 354.04 5215.57 5292.37 3871.56 3933.81 3928.64 3910.54 -376.66 6911.47 32.98 353.64 5293.95 5370.75 3922.24 3985.14 3979.96 3961.57 -382.17 7004.52 32.67 353.21 5372.14 5448.94 3972.10 4035.58 4030.39 4011.68 -387.94 7098.79 32.25 352.72 5451.68 5528.48 4022.17 4086.18 4080.97 4061.90 -394.14 7192.58 32.13 348.94 5531.06 5607.86 4071.83 4136.13 4130.82 4111.20 -402.09 7284.82 34.86 343.35 5608.00 5684.80 4122.67 4187.00 4181.13 4160.55 -414.36 7379.32 34.49 342.69 5685.71 5762.51 4176.41 4240.76 4233.87 4211.97 -430.06 7472.08 36.50 338.28 5761.24 5838.04 4230.08 4294.60 4286.17 4262.69 -448.08 7565.55 39.52 334.06 5834.89 5911.69 4286.96 4352.14 4340.95 4315.28 -471.39 7658.32 42.03 329.55 5905.16 5981.96 4345.96 4412.70 4397.14 4368.61 -500.05 7751.95 45.04 324.85 5973.04 6049.84 4407.40 4477.17 4454.99 4422.74 -535.02 7844.76 48.63 321.70 6036.53 6113.33 4470.36 4544.84 4513.79 4476.95 -575.53 7937.78 50.20 320.66 6097.05 6173.85 4535.12 4615.48 4574.17 4531.98 -619.82 8032.38 52.52 317.88 6156.12 6232.92 4601.81 4689.36 4636.32 4587.94 -668.04 8125.10 54.22 316.67 6211.44 6288.24 4667.83 4763.77 4697.87 4642.59 -718.53 8217.89 56.34 314.67 6264.29 6341.09 4734.49 4840.03 4760.12 4697.13 -771.83 8312.65 60.18 313.24 6314.14 6390.94 4803.71 4920.60 4824.94 4753.04 -829.85 Tie -In Survey 8404.48 65.07 312.20 6356.35 6433.15 4872.83 5002.12 4889.96 4808.33 -889.75 Top Whipstock ( Blind) 8487.00 69.96 310.30 6387.90 6464.70 4936.40 5078.34 4950.01 4858.57 -947.07 Base Whipstock ( Blind 8499.00 71.54 309.14 6391.86 6468.66 4945.68 5089.67 4958.79 4865.81 -955.78 First Inc + Trend (Blind) 8513.17 72.15 308.66 6396.27 6473.07 4956.60 5103.14 4969.11 4874.26 -966.26 8532.04 74.02 308.04 6401.76 6478.56 4971.13 5121.19 4982.87 4885.46 -980.42 8562.88 77.17 307.04 6409.43 6486.23 4994.93 5151.06 5005.41 4903.66 -1004.10 8593.93 80.14 306.05 6415.54 6492.34 5018.86 5181.50 5028.11 4921.78 -1028.56 8625.17 85.32 305.08 6419.49 6496.29 5042.88 5212.47 5050.94 4939.80 -1053.76 Last Inc + Trend (Blind) 8656.32 86.35 304.12 6421.76 6498.56 5066.64 5243.54 5073.58 4957.44 -1079.33 First MWD+IFR+MS 8686.60 89.61 303.20 6422.82 6499.62 5089.45 5273.80 5095.36 4974.21 -1104.51 U.Lb Sao"14/4.Ub D?J;4bbZ.U3 N /U.3ba3/11L VV'149.3Zb4'1bJb 0.47 5981525.55 582675.86 N 70.35951210 W 149.32846080 0.09 5981576.20 582669.72 N 70.35965065 W 149.32850614 0.28 5981626.54 582663.54 N 70.35978836 W 149.32855186 0.45 5981675.94 582657.13 N 70.35992351 W 149.32859950 1.28 5981726.52 582650.86 N 70.36006190 W 149.32864586 0.54 5981778.06 582645.35 N 70.36020287 W 149.32868596 1.27 5981830.61 582640.01 N 70.36034658 W 149.32872469 0.11 5981884.73 582634.40 N 70.36049462 W 149.32876538 0.41 5981938.44 582628.59 N 70.36064152 W 149.32880772 0.17 5981991.11 582622.79 N 70.36078558 W 149.311 0.30 5982043.28 582617.31 N 70.36092829 W 149.3288�J98 0.75 5982095.57 582611.68 N 70.36107130 W 149.32893104 0.49 5982146.35 582605.87 N 70.36121021 W 149.32897370 0.56 5982197.31 582599.79 N 70.36134963 W 149.32901845 0.42 5982247.35 582593.47 N 70.36148652 W 149.32906537 0.53 5982297.49 582586.72 N 70.36162370 W 149.32911571 2.15 5982346.70 582578.21 N 70.36175839 W 149.32918036 4.46 5982395.90 582565.41 N 70.36189321 W 149.32927999 0.56 5982447.14 582549.14 N 70.36203368 W 149.32940753 3.51 5982497.65 582530.55 N 70.36217223 W 149.32955400 4.26 5982549.97 582506.67 N 70.36231590 W 149.32974333 4.17 5982602.98 582477.42 N 70.36246160 W 149.32997617 4.72 5982656.72 582441.85 N 70.36260948 W 149.33026028 4.59 5982710.46 582400.75 N 70.36275755 W 149.33058934 1.89 5982765.00 582355.86 N 70.36290788 W 149.33094912 3.36 5982820.42 582307.02 N 70.36306075 W 149.33134088 2.11 5982874.50 582255.94 N 70.36321004 W 149.3 103 2.89 5982928.44 582202.04 N 70.36335902 W 149.103 4.25 5982983.69 582143.42 N 70.36351174 W 149. 535 5.42 5983038.32 582082.91 N 70.36366277 W 149.33314200 6.30 5983087.91 582025.04 N 70.36380000 W 149.33360767 16.02 5983095.05 582016.25 N 70.36381977 W 149.33367846 5.38 5983103.39 582005.68 N 70.36384287 W 149.33376359 10.40 5983114.43 581991.40 N 70.36387346 W 149.33387861 10.69 5983132.36 581967.52 N 70.36392316 W 149.33407101 10.06 5983150.21 581942.87 N 70.36397267 W 149.33426969 16.86 5983167.95 581917.47 N 70.36402188 W 149.33447443 4.51 5983185.30 581891.71 N 70.36407006 W 149.33468218 11.19 5983201.79 581866.34 N 70.36411586 W 149.33488678 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -124\L -124\L-124 Generated 5/17/2005 11:27 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub -Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude 5138.59 Depth 5006.40 6479.26 -1158.06 5303.76 Section Departure 5156.12 5368.16 5159.22 5020.96 -1186.40 k de de ft ft k ft ft ft ft dealt 00 k ftUS ftUS 6493.08 I.xMc n.n 8749.11 8781.02 8809.51 8841.27 8871.77 8902.63 8934.44 8965.44 8996.74 9026.93 9057.48 9089.10 9121.33 9151.49 9182.65 .`7 I.JV 92.25 93.35 93.59 93.42 93.49 93.15 93.28 92.77 91.63 91.77 92.49 92.39 90.37 90.26 90.50 JV I.VJ 298.69 295.66 294.00 290.25 288.47 284.74 280.62 278.17 274.73 271.69 268.61 265.77 264.38 261.24 257.38 V•fLG.Ue 6421.51 6419.95 6418.22 6416.28 6414.44 6412.66 6410.87 6409.23 6408.03 6407.14 6406.00 6404.65 6403.88 6403.71 6403.51 OV yy.JL JI IL.OU UJVO.UL 011/./U 4yy l.vo -I IJ I.J/ 6498.31 9242.27 5134.61 91.15 5336.29 253.03 5138.59 6402.46 5006.40 6479.26 -1158.06 5303.76 6496.75 5156.12 5368.16 5159.22 5020.96 -1186.40 9304.27 6495.02 91.53 5174.44 253.02 5396.60 6401.06 5176.82 6477.86 5032.90 5301.66 -1212.21 6493.08 5193.70 5428.30 5195.37 5044.83 9366.40 -1241.57 90.88 6491.24 253.70 5211.00 6399.72 5458.74 6476.52 5212.09 5300.04 5054.93 -1270.30 6489.46 5227.27 5489.55 5227.89 9428.26 5063.73 90.47 -1299.81 252.85 6487.67 6399.09 5242.16 6475.89 5521.31 5298.34 5242.42 5070.70 -1330.79 6486.03 5255.08 5552.27 9491.71 5255.14 90.95 5075.75 253.35 -1361.33 6398.22 6484.83 6475.02 5266.66 5296.42 5583.54 5266.66 5079.26 -1392.41 6483.94 5276.23 9553.50 5613.72 91.40 5276.33 254.33 5080.95 6396.86 -1422.53 6473.66 6482.80 5284.35 6481.45 5291.17 6480.68 5296.96 6480.51 5301.21 6480.31 5303.70 9213.59 91.19 254.27 6403.05 6479.85 5304.30 9242.27 91.15 253.03 6402.46 6479.26 5303.76 9274.09 91.26 252.54 6401.79 6478.59 5302.69 9304.27 91.53 253.02 6401.06 6477.86 5301.66 9335.48 91.26 253.08 6400.30 6477.10 5300.75 9366.40 90.88 253.70 6399.72 6476.52 5300.04 9397.46 90.50 253.01 6399.35 6476.15 5299.30 9428.26 90.47 252.85 6399.09 6475.89 5298.34 9459.70 90.85 252.87 6398.73 6475.53 5297.31 9491.71 90.95 253.35 6398.22 6475.02 5296.42 9522.49 91.36 253.51 6397.60 6474.40 5295.72 9553.50 91.40 254.33 6396.86 6473.66 5295.29 9584.79 91.84 254.51 6395.97 6472.77 5295.13 9616.02 91.98 255.06 6394.93 6471.73 5295.16 9647.18 92.12 255.50 6393.82 6470.62 5295.47 9678.27 92.08 255.39 6392.68 6469.48 5295.86 9709.31 92.05 255.45 6391.56 6468.36 5296.24 9740.96 91.50 254.43 6390.58 6467.38 5296.36 9772.58 91.22 253.56 6389.83 6466.63 5295.96 9802.94 88.48 255.77 6389.91 6466.71 5295.93 9834.33 88.17 256.17 6390.82 6467.62 5296.61 9865.67 88.21 256.87 6391.81 6468.61 5297.60 9896.80 88.89 256.90 6392.60 6469.40 5298.77 9928.12 89.06 257.69 6393.16 6469.96 5300.18 9959.64 89.23 257.18 6393.63 6470.43 5301.67 5644.25 5675.84 5708.06 5738.22 5769.38 5800.31 5828.99 5860.80 5890.97 5922.17 5953.09 5984.15 6014.94 6046.38 6078.39 6109.16 6140.16 6171.44 6202.65 6233.79 6264.86 6295.88 6327.52 6359.13 6389.49 6420.86 6452.19 6483.31 6514.62 6546.14 5284.72 5292.00 5298.44 5303.47 5306.96 5308.73 5309.45 5309.94 5310.58 5311.57 5312.92 5314.43 5315.88 5317.51 5319.50 5321.76 5324.48 5327.68 5331.25 5335.26 5339.52 5343.94 5348.37 5352.47 5356.92 5362.41 5368.36 5374.64 5381.35 5388.35 5081.03 -1453.06 5079.49 -1484.61 5076.72 -1516.71 5072.94 -1546.62 5067.17 -1577.24 5059.59 -1607.23 5051.52 -1634.74 5042.10 -1665.13 5033.17 -1693.95 5024.08 -1723.79 5015.24 -1753.42 5006.34 -1783.17 4997.30 -1812.62 4988.04 -1842.66 4978.74 -1873.28 4969.96 -1902.78 4961.38 -1932.57 4952.98 -1962.69 4944.78 -1992.81 4936.87 -2022.93 4929.06 -2053.00 4921.25 -2083.02 4913.03 -2113.57 4904.32 -2143.96 4896.29 -2173.23 4888.68 -2203.67 4881.38 -2234.13 4874.32 -2264.44 4867.43 -2294.99 4860.58 -2325.75 `J.UL OVOJ1610.110 06-1 0,5V.JU N /U.Jb4lbl!JJ VV I4V.JJblU4VU 8.04 5983233.38 581812.45 N 70.36420378 W 149.33532177 10.09 5983247.62 581783.94 N 70.36424353 W 149.33555208 5.88 5983259.27 581758.01 N 70.36427615 W 149.33576175 11.80 5983270.88 581728.52 N 70.36430874 W 149.33600028 5.83 5983280.66 581699.69 N 70.36433630 W 149.33623361 12.12 5983289.13 581670.08 N 70.36436033 W 149.33647342 12.94 5983295.76 581639.03 N 70.36437936 W 149.33672509 8.06 5983300.47 581608.44 N 70.36439315 W 149.33697318 11.57 5983303.64 581577.33 N 70.36440273 W 149.33722561 10.08 5983304.99 581547.19 N 70.36440733 W 149.3 4 10.35 5983304.74 581516.67 N 70.36440753 W 149.337 32 8.98 5983302.84 581485.14 N 70.36440329 W 149.33797461 7.61 5983299.72 581453.08 N 70.36439571 W 149.33823536 10.42 5983295.61 581423.20 N 70.36438538 W 149.33847840 12.41 5983289.49 581392.66 N 70.36436958 W 149.33872708 10.30 5983281.59 581362.76 N 70.36434887 W 149.33897069 4.32 5983273.21 581335.34 N 70.36432680 W 149.33919418 1.58 5983263.46 581305.06 N 70.36430106 W 149.33944102 1.82 5983254.21 581276.34 N 70.36427664 W 149.33967511 0.89 5983244.79 581246.60 N 70.36425177 W 149.33991755 2.35 5983235.62 581217.08 N 70.36422761 W 149.34015819 2.54 5983226.40 581187.43 N 70.36420329 W 149.34039989 0.53 5983217.03 581158.09 N 70.36417857 W 149.34063904 1.21 5983207.44 581128.16 N 70.36415324 W 149.34088307 1.53 5983197.80 581097.64 N 70.36412782 W 149.34113183 1.43 5983188.70 581068.25 N 70.36410382 W 149.34137142 2.65 5983179.78 581038.56 N 70.36408034 W 149.3 38 1.52 5983171.05 581008.53 N 70.36405737 W 14910 1.82 5983162.53 580978.51 N 70.36403497 W 149.3 275 1.48 5983154.28 580948.48 N 70.36401334 W 149.34234739 0.38 5983146.14 580918.50 N 70.36399198 W 149.34259166 0.22 5983138.00 580888.57 N 70.36397063 W 149.34283551 3.66 5983129.45 580858.12 N 70.36394815 W 149.34308364 2.89 5983120.39 580827.83 N 70.36392431 W 149.34333046 11.59 5983112.04 580798.65 N 70.36390236 W 149.34356825 1.61 5983104.10 580768.30 N 70.36388156 W 149.34381550 2.24 5983096.46 580737.92 N 70.36386158 W 149.34406293 2.19 5983089.07 580707.70 N 70.36384227 W 149.34430911 2.58 5983081.84 580677.23 N 70.36382343 W 149.34455725 1.71 5983074.65 580646.55 N 70.36380467 W 149.34480711 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -124\L -124\L-124 Generated 5/17/2005 11:27 AM Page 4 of 5 Comments Measured inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude 1.96 Depth 10021.58 89.24 5375.23 257.85 Section Departure -2849.25 6471.33 5983002.09 5304.83 6608.07 5402.85 87.90 4847.32 6395.37 k de de k k k k k k k de /100 k kUS kUS 5307.13 6639.21 9990.50 89.10 257.77 269.92 6394.08 6470.67 6470.88 7043.40 5303.16 6576.99 5395.40 5.26 4853.89 -2355.87 10488.58 1.96 5983067.62 10021.58 89.24 5375.23 257.85 5576.64 6394.53 -2849.25 6471.33 5983002.09 5304.83 6608.07 5402.85 87.90 4847.32 6395.37 -2386.25 5383.40 0.52 5983060.72 10052.72 88.82 3.87 260.07 6395.06 10549.84 6471.86 270.05 5307.13 6639.21 5411.08 7136.10 4841.36 4794.23 -2416.81 9.46 7.25 5983054.42 10084.19 89.82 84.53 260.61 6400.14 6395.43 5399.84 6472.23 5624.74 5310.22 6670.67 5420.29 5983001.23 4836.08 -2447.83 85.91 3.61 5983048.80 10116.27 91.26 7196.85 260.71 4793.23 6395.13 5.84 6471.93 5313.54 6702.75 5430.03 266.73 4830.88 6480.81 -2479.48 7229.13 4.50 5983043.25 10146.13 91.60 5982998.33 260.68 6394.39 90.13 6471.19 6404.25 5316.64 6732.60 5439.26 5670.06 4826.05 -3034.35 -2508.94 5982996.04 1.14 5983038.09 10177.60 92.49 266.11 261.29 6481.45 6393.26 7291.19 6470.06 4787.70 5320.07 6764.05 5449.29 4821.12 10720.69 -2540.00 263.85 3.43 5983032.82 Tie -In Survey 10209.22 92.53 5692.12 261.52 -3080.76 6391.88 5982992.06 6468.68 TD ( Projected ) 5323.75 6795.64 5459.76 6407.76 4816.40 5437.49 -2571.23 5716.17 0.74 5983027.76 MWD+IFR+MS 10240.11 91.73 261.58 Definitive Survey 6390.73 6467.53 5327.42 6826.51 5470.21 4811.86 -2601.77 NOTES: 2.60 5983022.88 10270.43 89.68 264.01 6390.36 ex -BP "Gyrodata multishot into 6467.16 be run above 5331.68 6856.83 5481.25 4808.06 MWD + IFR + -2631.84 with mult-station analysis 10.48 5983018.75 10301.81 87.52 263.18 Assumes a BHA 6391.12 inclination accuracy. 6467.92 5336.52 6888.19 5493.22 4804.56 -2663.01 7.37 5983014.90 10332.86 87.52 263.25 6392.47 6469.27 5341.10 6919.22 5505.02 4800.90 -2693.82 0.23 5983010.90 10364.16 89.06 265.25 6393.40 6470.20 5346.28 6950.50 5517.60 4797.76 -2724.94 8.06 5983007.42 10395.82 90.19 266.90 6393.61 6470.41 5352.52 6982.16 5531.38 4795.60 -2756.53 6.32 5983004.90 10426.38 89.75 268.36 6393.62 6470.42 5359.34 7012.72 5545.57 4794.33 -2787.06 4.99 5983003.30 Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface: 2520 FSL 3889 FEL S34 T12N R11 E UM 5978240.59 583025.79 BHL : 2020 FSL 1734 FEL S28 T12N R11 E UM 5982985.77 579839.61 580616.51 N 70.36378636 W 149.34505179 580586.21 N 70.36376841 W 149.34529853 580555.72 N 70.36375210 W 149.34554674 580524.77 N 70.36373764 W 149.34579872 580493.18 N 70.36372339 W 149.34605582 580463.78 N 70.36371018 W 149.34629510 580432.77 N 70.36369669 W 149.34654740 580401.60 N 70.36368376 W 149.34680112 580371.12 N 70.36367134 W 149.34704914 580341.09 N 70.36366093 W 149.34729343 580309.96 N 70.36365134 W 149.34 580279.20 N 70.36364130 W 149.34 6 580248.12 N 70.36363270 W 149.34804969 580216.56 N 70.36362675 W 149.34830625 580186.05 N 70.36362327 W 149.34855427 580155.38 N 70.36362198 W 149.34880344 580123.87 N 70.36362178 W 149.34905944 580093.52 N 70.36362224 W 149.34930602 580062.70 N 70.36362285 W 149.34955644 580031.11 N 70.36362213 W 149.34981312 580001.97 N 70.36362006 W 149.35004989 579969.75 N 70.36361600 W 149.35031178 579938.85 N 70.36361066 W 149.35056300 579907.88 N 70.36360485 W 149.35081485 579892.48 N 70.36360114 W 149.35094001 579839.61 N 70.36358549 W 149.35137006 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -124\L -124\L-124 Generated 5/17/2005 11:27 AM Page 5 of 5 10457.06 89.34 269.92 6393.87 6470.67 5366.98 7043.40 5560.65 4793.87 -2817.74 5.26 5983002.50 10488.58 88.58 269.86 6394.44 6471.24 5375.23 7074.91 5576.64 4793.81 -2849.25 2.42 5983002.09 10518.95 87.90 270.82 6395.37 6472.17 5383.40 7105.27 5592.36 4793.99 -2879.60 3.87 5983001.94 10549.84 85.08 270.05 6397.26 6474.06 5391.75 7136.10 5608.50 4794.23 -2910.43 9.46 5983001.83 10581.57 84.53 269.04 6400.14 6476.94 5399.84 7167.70 5624.74 4793.98 -2942.03 3.61 5983001.23 10610.83 85.91 268.03 6402.58 6479.38 5406.80 7196.85 5639.41 4793.23 -2971.18 5.84 5983000.16 10643.14 88.99 266.73 6404.01 6480.81 5413.87 7229.13 5655.21 4791.76 -3003.42 10.35 5982998.33 10674.13 90.13 266.09 6404.25 6481.05 5420.15 7260.12 5670.06 4789.81 -3034.35 4.22 5982996.04 10705.21 88.41 266.11 6404.65 6481.45 5426.28 7291.19 5684.93 4787.70 -3065.35 5.53 5982993.59 Last MWD+IFR+MS 10720.69 87.28 263.85 6405.23 6482.03 5429.04 7306.66 5692.12 4786.35 -3080.76 16.31 5982992.06 TD ( Projected ) 10774.00 87.28 263.85 6407.76 6484.56 5437.49 7359.91 5716.17 4780.64 -3133.70 0.00 5982985.77 Survey Type: Definitive Survey NOTES: GYD-GC-MS - ( Gyrodata - gyro compassing m/s -- Older Gyrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex -BP "Gyrodata multishot into open hole" model. Not to be run above 70 degrees inclination.. ) MWD + IFR + MS - ( In -field referenced MWD with mult-station analysis and correction applied in post -processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface: 2520 FSL 3889 FEL S34 T12N R11 E UM 5978240.59 583025.79 BHL : 2020 FSL 1734 FEL S28 T12N R11 E UM 5982985.77 579839.61 580616.51 N 70.36378636 W 149.34505179 580586.21 N 70.36376841 W 149.34529853 580555.72 N 70.36375210 W 149.34554674 580524.77 N 70.36373764 W 149.34579872 580493.18 N 70.36372339 W 149.34605582 580463.78 N 70.36371018 W 149.34629510 580432.77 N 70.36369669 W 149.34654740 580401.60 N 70.36368376 W 149.34680112 580371.12 N 70.36367134 W 149.34704914 580341.09 N 70.36366093 W 149.34729343 580309.96 N 70.36365134 W 149.34 580279.20 N 70.36364130 W 149.34 6 580248.12 N 70.36363270 W 149.34804969 580216.56 N 70.36362675 W 149.34830625 580186.05 N 70.36362327 W 149.34855427 580155.38 N 70.36362198 W 149.34880344 580123.87 N 70.36362178 W 149.34905944 580093.52 N 70.36362224 W 149.34930602 580062.70 N 70.36362285 W 149.34955644 580031.11 N 70.36362213 W 149.34981312 580001.97 N 70.36362006 W 149.35004989 579969.75 N 70.36361600 W 149.35031178 579938.85 N 70.36361066 W 149.35056300 579907.88 N 70.36360485 W 149.35081485 579892.48 N 70.36360114 W 149.35094001 579839.61 N 70.36358549 W 149.35137006 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -124\L -124\L-124 Generated 5/17/2005 11:27 AM Page 5 of 5 ■ �w wwA w w . Schludepoep �- i cora purvey Mepurt Report Date: 3 -May -05 O.UU Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Along Hole Vertical Section Azimuth: 344.720° Field: Prudhoe Bay Unit - WOA 271.64 Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: L -PAD / L-124 0.17 TO Reference Datum: Rotary Table Well: L-124 123.20 TO Reference Elevation: 76.80 ft relative to MSL Borehole: L-124PB1 DLS Sea Bed I Ground Level Elevation: 48.30 ft relative to MSL UWI/API#: 500292325870 299.98 Magnetic Declination: 24.480° Survey Name I Date: L-124PB1 / May 3, 2005 400.00 Total Field Strength: 57610.954 nT Tort / AHD / DDI 1 ERD ratio: 161.886° 15668.89 ft / 6.099 / 0.852 5.09 Magnetic Dip: 80.811 ° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet 3.78 Declination Date: May 04, 2005 Location Lat/Long: N 70.35052701, W 149.32591439 ft Magnetic Declination Model: BGGM 2004 Location Grid N/E Y/X: N 5978240.590 fIUS, E 583025.790 ftUS ft North Reference: True North Grid Convergence Angle: +0.63483521 ° 19.43 Total Corr Mag North -> True North: +24.480° Grid Scale Factor: 0.99990783 621.93 Local Coordinates Referenced To: Well Head 0 K I E Measured O.UU U.UU -tb.BU U.UU Vertical Along Hole U.UO First GYD GC MS 100.00 0.20 271.64 23.20 100.00 0.05 Comments 0.17 Inclination Azimuth Sub -Sea TVD TO 123.20 200.00 Closure NS EW DLS Northing Easting Latitude Longitude 299.98 Depth 2.32 1.98 400.00 Section Departure 323.10 399.90 5.09 6.24 5.88 W 149.32590898 500.00 3.78 359.68 ft de de ft ft ft ft ft ft ft de /100 ft ftUS ftUS 19.43 1.13 K I E O.UU O.UU U.UU -tb.BU U.UU U.DU O.UU U.UO First GYD GC MS 100.00 0.20 271.64 23.20 100.00 0.05 0.17 0.17 583025.62 200.00 0.33 49.75 123.20 200.00 0.22 0.47 0.23 0.50 300.00 1.82 21.25 223.18 299.98 1.62 2.32 1.98 400.00 2.70 5.81 323.10 399.90 5.09 6.24 5.88 W 149.32590898 500.00 3.78 359.68 422.94 499.74 10.48 11.89 11.45 583027.21 600.00 5.59 349.43 522.60 599.40 18.52 20.04 19.43 1.13 700.00 7.64 345.53 621.93 698.73 30.02 31.55 30.69 800.00 10.20 343.51 720.72 797.52 45.52 47.05 45.95 W 149.32590799 850.00 10.96 342.90 769.87 846.67 54.70 56.23 55.03 583023.68 900.00 13.75 343.59 818.70 895.50 65.39 66.93 65.64 2.58 950.00 14.85 343.00 867.15 943.95 77.74 79.28 77.93 1000.00 17.34 344.83 915.19 991.99 91.59 93.14 91.75 W 149.32598417 1050.00 19.56 344.20 962.62 1039.42 107.42 108.96 107.54 583013.40 1100.00 20.97 344.73 1009.52 1086.32 124.73 126.28 124.84 2.22 1150.00 23.54 345.82 1055.79 1132.59 143.67 145.21 143.77 Last GYD GC MS 1189.00 24.93 345.83 1091.35 1168.15 159.67 161.22 159.77 First MWD+IFR+MS 1223.53 26.97 347.57 1122.40 1199.20 174.77 176.33 174.88 583001.35 1318.56 30.12 350.35 1205.87 1282.67 220.04 221.73 220.24 2.84 1411.57 33.23 353.54 1285.02 1361.82 268.46 270.55 268.92 1503.89 37.07 353.91 1360.50 1437.30 320.94 323.69 321.85 W 149.32617999 1597.02 42.40 353.85 1432.09 1508.89 379.69 383.20 381.18 582987.44 1691.41 48.99 356.15 1497.99 1574.79 446.10 450.71 448.43 6.31 1782.67 50.23 356.39 1557.12 1633.92 514.20 520.22 517.64 1876.53 48.39 355.33 1618.31 1695.11 584.02 591.38 588.61 U.UU U.UU U.UU bU/6Z4U.bU 063LILb.t9 N /U.3bUb1/U1 VV 149.3Zb91439 0.00 -0.17 0.20 5978240.59 583025.62 N 70.35052702 W 149.32591581 0.20 -0.13 0.50 5978240.78 583025.66 N 70.35052755 W 149.32591544 1.86 0.67 1.54 5978242.46 583026.44 N 70.35053210 W 149.32590898 5.69 1.48 1.06 5978246.29 583027.21 N 70.35054254 W 149.32590237 11.33 1.70 1.13 5978251.93 583027.36 N 70.35055795 W 149.32590059 19.41 0.79 1.99 5978260.01 583026.36 N 70.35058004 W 149.32590799 30.64 -1.77 2.10 5978271.20 583023.68 N 70.35061070 W 149.32592873 45.56 -5.94 2.58 5978286.08 583019.34 N 70.35065149 W 149.32596262 54.35 -8.60 1.54 5978294.84 583016.59 N 70.35067550 W 149.32598417 64.60 -11.67 5.59 5978305.05 583013.40 N 70.35070349 W 149.315 76.43 -15.22 2.22 5978316.84 583009.72 N 70.35073580 W 149. 99 89.75 -19.05 5.08 5978330.11 583005.75 N 70.35077219 W 149.3 03 104.99 -23.28 4.46 5978345.31 583001.35 N 70.35081384 W 149.32610336 121.68 -27.91 2.84 5978361.94 582996.53 N 70.35085943 W 149.32614099 139.99 -32.72 5.21 5978380.20 582991.53 N 70.35090946 W 149.32617999 155.51 -36.64 3.56 5978395.67 582987.44 N 70.35095186 W 149.32621181 170.22 -40.10 6.31 5978410.34 582983.81 N 70.35099203 W 149.32623996 214.78 -48.74 3.60 5978454.80 582974.68 N 70.35111378 W 149.32631009 263.13 -55.52 3.80 5978503.06 582967.36 N 70.35124585 W 149.32636514 315.95 -61.32 4.17 5978555.81 582960.98 N 70.35139016 W 149.32641223 375.12 -67.67 5.72 5978614.90 582953.98 N 70.35155181 W 149.32646376 442.37 -73.48 7.20 5978682.08 582947.42 N 70.35173553 W 149.32651091 511.73 -78.00 1.37 5978751.38 582942.14 N 70.35192502 W 149.32654762 582.71 -83.13 2.14 5978822.29 582936.22 N 70.35211893 W 149.32658926 SurveyEditor Ver Bid( doc4Ox_37 ) L-124\L-124\L-124PB1\L-124PB1 Generated 5/17/2005 11:30 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub -Sea TO TO Vertical Along Hole Closure NS EW US Northing Easting Latitude Longitude Depth U.if OvfO VJ.Iv I Section I Departure IV [U.,10/15 1/014 VV 14`J.3LUb4000 2063.32 48.71 352.62 ft de de ft ft ft ft ft ft ft de /100 ft ftUS (ftUS 1.63 1971.48 48.87 354.tiU 1ti81.U/ 1(b/.8/ bO4.14 btjZ.b4 b59.// b53.b9 t5y.3t5 U.if OvfO VJ.Iv DozUZU. 10 IV [U.,10/15 1/014 VV 14`J.3LUb4000 2063.32 48.71 352.62 1741.58 1818.38 722.39 731.73 728.84 722.35 -97.07 1.63 5978961.75 582920.73 N 70.35250040 W 149.32670247 2156.39 47.68 352.60 1803.61 1880.41 791.11 801.10 798.22 791.15 -105.99 1.11 5979030.44 582911.05 N 70.35268835 W 149.32677492 2250.51 47.61 353.04 1867.03 1943.83 859.97 870.65 867.77 860.15 -114.68 0.35 5979099.34 582901.59 N 70.35287687 W 149.32684551 2344.98 48.30 353.62 1930.29 2007.09 929.33 940.81 937.91 929.83 -122.83 0.86 5979168.92 582892.68 N 70.35306723 W 149.32691166 2439.32 47.74 353.37 1993.39 2070.19 998.64 1010.94 1008.03 999.51 -130.78 0.63 5979238.50 582883.96 N 70.35325758 W 149.32697617 2531.44 47.60 354.75 2055.43 2132.23 1065.84 1079.04 1076.11 1067.25 -137.82 1.12 5979306.14 582876.16 N 70.35344262 W 149.32703341 2625.95 48.38 355.43 2118.68 2195.48 1134.91 1149.26 1146.27 1137.21 -143.83 0.98 5979376.03 582869.38 N 70.35363376 W 149.32708220 2718.09 48.26 354.82 2179.95 2256.75 1202.60 1218.08 1215.03 1205.78 -149.68 0.51 5979444.52 582862.78 N 70.35382108 W 149.32712969 2810.94 48.26 354.39 2241.77 2318.57 1270.85 1287.36 1284.29 1274.75 -156.19 0.35 5979513.41 582855.50 N 70.35400951 W 149.32718259 2905.05 47.71 353.70 2304.76 2381.56 1339.85 1357.28 1354.20 1344.30 -163.45 0.80 5979582.87 582847.48 N 70.35419950 W 149.327 148 2997.88 47.32 354.34 2367.45 2444.25 1407.41 1425.74 1422.64 1412.38 -170.58 0.66 5979650.86 582839.59 N 70.35438550 W 149.321 3092.44 46.68 353.91 2431.94 2508.74 1475.63 1494.90 1491.79 1481.17 -177.66 0.75 5979719.56 582831.75 N 70.35457343 W 149.32 3184.34 46.34 353.95 2495.19 2571.99 1541.45 1561.57 1558.46 1547.47 -184.71 0.37 5979785.78 582823.97 N 70.35475455 W 149.32741415 3267.71 45.04 355.35 2553.43 2630.23 1600.21 1621.22 1618.09 1606.86 -190.28 1.97 5979845.10 582817.74 N 70.35491681 W 149.32745939 3361.06 46.28 354.23 2618.67 2695.47 1665.94 1687.98 1684.83 1673.35 -196.35 1.58 5979911.50 582810.94 N 70.35509844 W 149.32750868 3454.83 47.62 356.46 2682.69 2759.49 1733.28 1756.50 1753.30 1741.64 -201.89 2.25 5979979.72 582804.63 N 70.35528499 W 149.32755373 3546.94 48.34 355.61 2744.34 2821.14 1800.37 1824.93 1821.66 1809.90 -206.63 1.04 5980047.92 582799.14 N 70.35547148 W 149.32759219 3640.51 48.21 356.83 2806.62 2883.42 1868.81 1894.77 1891.41 1879.58 -211.23 0.98 5980117.54 582793.77 N 70.35566185 W 149.32762959 3733.20 47.78 356.40 2868.65 2945.45 1936.20 1963.64 1960.20 1948.34 -215.30 0.58 5980186.24 582788.94 N 70.35584968 W 149.32766262 3827.42 48.44 355.24 2931.56 3008.36 2005.03 2033.78 2030.29 2018.29 -220.41 1.15 5980256.12 582783.05 N 70.35604078 W 149.32770418 3920.43 47.88 355.58 2993.60 3070.40 2073.12 2103.07 2099.55 2087.36 -225.96 0.66 5980325.12 582776.74 N 70.35622947 W 149.32774923 4013.97 46.74 356.18 3057.03 3133.83 2140.57 2171.83 2168.26 2155.94 -230.90 1.31 5980393.63 582771.04 N 70.35641681 W 149.32778939 4107.15 47.04 356.63 3120.71 3197.51 2207.19 2239.85 2236.23 2223.83 -235.17 0.48 5980461.47 582766.02 N 70.35660229 W 149.32782404 4205.93 48.71 357.37 3186.96 3263.76 2278.77 2313.11 2309.39 2296.99 -238.99 1.78 5980534.57 582761.39 N 70.35680215 W 149.32785514 4299.33 48.21 358.47 3248.90 3325.70 2346.83 2383.02 2379.14 2366.85 -241.53 1.03 5980604.39 582758.07 N 70.35699301 W 149.32787578 4393.07 47.70 358.91 3311.68 3388.48 2414.38 2452.63 2448.54 2436.44 -243.13 0.65 5980673.96 582755.71 N 70.35718313 W 149.32788873 4485.81 47.23 359.69 3374.37 3451.17 2480.52 2520.97 2516.62 2504.77 -243.96 0.80 5980742.27 582754.12 N 70.35736980 W 149.32789554 4579.05 47.97 358.02 3437.25 3514.05 2547.29 2589.82 2585.27 2573.61 -245.34 1.54 5980811.08 582751.97 N 70.35755785 W 149.32790678 4671.46 48.52 358.29 3498.79 3575.59 2614.34 2658.76 2654.08 2642.51 -247.56 0.63 5980879.94 582748.99 N 70.35774608 W 149.382 4765.16 47.65 357.81 3561.38 3638.18 2682.18 2728.48 2723.68 2712.19 -249.93 1.00 5980949.59 582745.85 N 70.35793646 W 149.3 409 4859.58 46.89 356.33 3625.45 3702.25 2749.93 2797.84 2792.98 2781.45 -253.47 1.40 5981018.80 582741.54 N 70.35812567 W 149.32797285 4951.15 45.59 354.65 3688.79 3765.59 2814.89 2863.97 2859.11 2847.38 -258.66 1.94 5981084.66 582735.62 N 70.35830578 W 149.32801501 5043.16 42.99 353.84 3754.64 3831.44 2878.25 2928.21 2923.35 2911.30 -265.09 2.89 5981148.50 582728.48 N 70.35848040 W 149.32806726 5136.17 39.23 352.25 3824.71 3901.51 2938.74 2989.35 2984.46 2971.99 -272.47 4.20 5981209.10 582720.44 N 70.35864621 W 149.32812715 5229.31 36.72 351.91 3898.13 3974.93 2995.57 3046.66 3041.70 3028.75 -280.36 2.70 5981265.77 582711.92 N 70.35880127 W 149.32819125 5322.70 34.28 351.59 3974.15 4050.95 3049.39 3100.89 3095.86 3082.42 -288.13 2.62 5981319.34 582703.55 N 70.35894788 W 149.32825443 5416.91 33.93 351.82 4052.16 4128.96 3101.82 3153.71 3148.61 3134.69 -295.76 0.40 5981371.52 582695.35 N 70.35909068 W 149.32831634 5509.82 33.67 353.59 4129.37 4206.17 3153.00 3205.40 3200.27 3185.96 -302.32 1.10 5981422.70 582688.22 N 70.35923073 W 149.32836967 5603.32 33.52 353.93 4207.25 4284.05 3204.09 3257.13 3252.00 3237.38 -307.94 0.26 5981474.06 582682.03 N 70.35937122 W 149.32841536 5697.77 33.10 353.69 4286.18 4362.98 3255.31 3309.00 3303.86 3288.95 -313.54 0.47 5981525.55 582675.86 N 70.35951210 W 149.32846080 5791.30 33.02 353.75 4364.57 4441.37 3305.71 3360.02 3354.88 3339.67 -319.12 0.09 5981576.20 582669.72 N 70.35965065 W 149.32850614 5884.67 32.79 353.51 4442.96 4519.76 3355.82 3410.74 3405.59 3390.08 -324.75 0.28 5981626.54 582663.54 N 70.35978836 W 149.32855186 5977.02 32.50 352.97 4520.72 4597.52 3405.08 3460.56 3455.40 3439.55 -330.61 0.45 5981675.94 582657.13 N 70.35992351 W 149.32859950 SurveyEditor Ver Bld( doc40x_37 ) L-124\L-124\L-124PB1\L-124PB1 Generated 5/17/2005 11:30 AM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth 313.24 6314.14 Section I Departure 312.20 6356.35 70.69 310.03 ft de de ft ft ft ft ft ft ft de /100 ft) (ftUS ftUS 72.86 bU/U.bi JJ.01 6164.15 6257.67 6352.48 6446.81 6539.74 6632.08 6725.61 6817.78 6911.47 7004.52 7098.79 7192.58 7284.82 7379.32 7472.08 7565.55 7658.32 7751.95 7844.76 7937.78 8032.38 8125.10 8217.89 8312.65 8404.48 8499.19 8592.14 8685.01 8779.47 8870.97 33.80 34.98 35.08 34.80 34.73 34.52 33.91 33.46 32.98 32.67 32.25 32.13 34.86 34.49 36.50 39.52 42.03 45.04 48.63 50.20 J04.1 b 354.91 354.74 354.70 354.23 354.47 354.80 354.17 354.04 353.64 353.21 352.72 348.94 343.35 342.69 338.28 334.06 329.55 324.85 321.70 320.66 40WV.L"1 40rb.V 1 15430.45 4677.07 4753.87 3506.53 4754.24 4831.04 3558.53 4831.88 4908.68 3612.13 4909.20 4986.00 3665.37 4985.55 5062.35 3717.62 5061.53 5138.33 3769.30 5138.87 5215.67 3821.13 5215.57 5292.37 3871.56 5293.95 5370.75 3922.24 5372.14 5448.94 3972.10 5451.68 5528.48 5531.06 5607.86 5608.00 5684.80 5685.71 5762.51 5761.24 5838.04 5834.89 5905.16 5973.04 6036.53 6097.05 52.52 317.88 6156.12 54.22 316.67 6211.44 56.34 314.67 6264.29 60.18 313.24 6314.14 65.07 312.20 6356.35 70.69 310.03 6392.00 73.18 309.03 6420.82 73.22 309.28 6447.66 72.86 309.11 6475.22 72.33 308.84 6502.59 5911.69 5981.96 6049.84 6113.33 6173.85 6232.92 6288.24 6341.09 6390.94 6433.15 6468.80 6497.62 6524.46 6552.02 6579.39 4022.17 4071.83 4122.67 4176.41 4230.08 4286.96 4345.96 4407.40 4470.36 4535.12 4601.81 4667.83 4734.49 4803.71 4872.83 4945.86 5018.06 5090.39 5163.92 5234.78 1501"1.014 1J000.3/ J4Z1V.1U -JJO.JI 3563.38 3616.20 3670.62 3724.64 3777.63 3830.10 3882.69 3933.81 3985.14 4035.58 4086.18 4136.13 4187.00 4240.76 4294.60 4352.14 4412.70 4477.17 4544.84 4615.48 4689.36 4763.77 4840.03 4920.60 5002.12 5089.82 5178.18 5267.09 5357.44 5444.75 3558.21 3611.03 3665.45 3719.47 3772.46 3824.93 3877.52 3928.64 3979.96 4030.39 4080.97 4130.82 4181.13 4233.87 4286.17 4340.95 4397.14 4454.99 4513.79 4574.17 4636.32 4697.87 4760.12 4824.94 4889.96 3541.80 3594.41 3648.60 3702.37 3755.11 3807.34 3859.69 3910.54 3961.57 4011.68 4061.90 4111.20 4160.55 4211.97 4262.69 4315.28 4368.61 4422.74 4476.95 4531.98 4587.94 4642.59 4697.13 4753.04 4808.33 -341.25 -346.02 -351.02 -356.23 -361.45 -366.36 -371.41 -376.66 -382.17 -387.94 -394.14 -402.09 -414.36 -430.06 -448.08 -471.39 -500.05 -535.02 -575.53 -619.82 -668.04 -718.53 -771.83 -829.85 -889.75 4958.96 4865.97 -955.84 5027.59 4922.21 -1023.99 5096.90 4978.34 -1092.94 5167.99 5035.44 -1162.96 5237.05 5090.36 -1230.83 I.Go VVV 1 /LUNG 0.54 5981778.06 1.27. 5981830.61 0.11 5981884.73 0.41 5981938.44 0.17 5981991.11 0.30 5982043.28 0.75 5982095.57 0.49 5982146.35 0.56 5982197.31 0.42 5982247.35 0.53 5982297.49 2.15 5982346.70 4.46 5982395.90 0.56 5982447.14 3.51 5982497.65 4.26 5982549.97 4.17 5982602.98 4.72 5982656.72 4.59 5982710.46 1.89 5982765.00 3.36 5982820.42 2,11 5982874.50 2,89 5982928.44 4.25 5982983.69 5.42 5983038.32 6.30 5983095.22 2.87 5983150.69 0.26 5983206.05 0.42 5983262.37 0.64 5983316.52 8964.75 72.39 308.44 6531.01 6607.81 5307.01 5534.12 5307.98 5146.17 -1300.64 0.41 5983371.55 Last MWD+IFR+MS 9036.70 72.63 308.50 6552.63 6629.43 5362.35 5602.75 5362.70 5188.86 -1354.37 0.34 5983413.63 TD ( Projected ) 9106.00 72.63 308.50 6573.32 6650.12 5415.71 5668.89 5415.76 5230.03 -1406.13 0.00 5983454.23 Survey Type: Definitive Survey NOTES: GYD-GC-MS - ( Gyrodata - gyro compassing m/s -- Older Gyrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex -BP "Gyrodata multishot into open hole" model. Not to be run above 70 degrees inclination.. ) MWD + IFR + MS - ( In -field referenced MWD with mutt -station analysis and correction applied in post -processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Surface: 2520 FSL 3889 FEL S34 T12N R11 E UM BHL : 2471 FSL 5 FEL S28 T12N R11 E UM Northing (Y) [ftUS] Easting (X) [ftUS] 5978240.59 583025.79 5983454.23 581561.94 VVLVVV.OV IV IV.JV VVVI.7V VV IYD.0G VY VV 582645.35 N 70.36020287 W 149.32868596 582640.01 N 70.36034658 W 149.32872469 582634.40 N 70.36049462 W 149.32876538 582628.59 N 70.36064152 W 149.32880772 582622.79 N 70.36078558 W 149.32885011 582617.31 N 70.36092829 W 149.32888998 582611.68 N 70.36107130 W 149.32893104 582605.87 N 70.36121021 W 149.32897370 582599.79 N 70.36134963 W 149.32901845 582593.47 N 70.36148652 W 149.327 582586.72 N 70.36162370 W 149.32 582578.21 N 70.36175839 W 149.32918036 582565.41 N 70.36189321 W 149.32927999 582549.14 N 70.36203368 W 149.32940753 582530.55 N 70.36217223 W 149.32955400 582506.67 N 70.36231590 W 149.32974333 582477.42 N 70.36246160 W 149.32997617 582441.85 N 70.36260948 W 149.33026028 582400.75 N 70.36275755 W 149.33058934 582355.86 N 70.36290788 W 149.33094912 582307.02 N 70.36306075 W 149.33134088 582255.94 N 70.36321004 W 149.33175103 582202.04 N 70.36335902 W 149.33218403 582143.42 N 70.36351174 W 149.33265535 582082.91 N 70.36366277 W 149.33314200 582016.19 N 70.36382022 W 149.33367894 581947.42 N 70.36397383 W 149.33423264 581877.87 N 70.36412716 W 149.374 581807.23 N 70.36428312 W 149. 63 581738.75 N 70.36443312 W 149.3 310 581668.34 N 70.36458554 W 149.33648025 581614.15 N 70.36470215 W 149.33691678 581561.94 N 70.36481460 W 149.33733733 SurveyEditor Ver Bid( doc40x_37 ) L-124\L-124\L-124PB1\L-124PB1 Generated 5/17/2005 11:30 AM Page 3 of 3 by L-"1 Z4MIZ ourvev Revort 011111 Schlumheraer Report Date: 10 -May -05 Inclination Survey/ DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Along Hole Vertical Section Azimuth: 344.720° Field: Prudhoe Bay Unit- WOA Northing Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: L -PAD / L-124 Depth TO Reference Datum: Rotary Table Well: L-124 Section TO Reference Elevation: 76.80 ft relative to MSL Borehole: L-124PB2 Sea Bed / Ground Level Elevation: 48.30 ft relative to MSL UWI/API#: 500292325871 Magnetic Declination: 24.472° Survey Name 1 Date: L-1 24P82 / May 10, 2005 ft Total Field Strength: 57611.547 nT Tort I AHD I DDI I ERD ratio: 268.993° / 7201.07 ft / 6.500 11.108 ft Magnetic Dip: 80.811 ° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet 0.33 Declination Date: May 10, 2005 Location Lot/Long: N 70.35052701, W 149.32591439 200.00 Magnetic Declination Model: BGGM 2004 Location Grid NIE Y/x: N 5978240.590 ftUS, E 583025.790 ftUS 0.23 North Reference: True North Grid Convergence Angle: +0.63483521' Total Corr Mag North •> True North: +24.472° Grid Scale Factor: 0.99990783 300.00 Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub -Sea TO TO Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude U.UV Depth U00V4J./U IN /U.JVVVL/UI VV IY7.JLJ11VJ0 Section Departure 0.20 271.64 23.20 100.00 0.05 ft de de ft ft ft ft ft ft ft de 11o0ft ftUS ftUS 0.33 KIt: 0.00 0.00 0.00 -76.80 0.00 U.UV U.UU V.UU U.UU V.VU U.UV Vy/OL•}U.UV U00V4J./U IN /U.JVVVL/UI VV IY7.JLJ11VJ0 First GYD GC MS 100.00 0.20 271.64 23.20 100.00 0.05 0.17 0.17 0.00 -0.17 0.20 5978240.59 583025.62 N 70.35052702 W 149.32591581 200.00 0.33 49.75 123.20 200.00 0.22 0.47 0.23 0.20 -0.13 0.50 5978240.78 583025.66 N 70.35052755 W 149.32591544 300.00 1.82 21.25 223.18 299.98 1.62 2.32 1.98 1.86 0.67 1.54 5978242.46 583026.44 N 70.35053210 W 149.32590898 400.00 2.70 5.81 323.10 399.90 5.09 6.24 5.88 5.69 1.48 1.06 5978246.29 583027.21 N 70.35054254 W 149.32590237 500.00 3.78 359.68 422.94 499.74 10.48 11.89 11.45 11.33 1.70 1.13 5978251.93 583027.36 N 70.35055795 W 149.32590059 600.00 5.59 349.43 522.60 599.40 18.52 20.04 19.43 19.41 0.79 1.99 5978260.01 583026.36 N 70.35058004 W 149.32590799 700.00 7.64 345.53 621.93 698.73 30.02 31.55 30.69 30.64 -1.77 2.10 5978271.20 583023.68 N 70.35061070 W 149.32592873 800.00 10.20 343.51 720.72 797.52 45.52 47.05 45.95 45.56 -5.94 2.58 5978286.08 583019.34 N 70.35065149 W 149.32596262 850.00 10.96 342.90 769.87 846.67 54.70 56.23 55.03 54.35 -8.60 1.54 5978294.84 583016.59 N 70.35067550 W 149.32598417 900.00 13.75 343.59 818.70 895.50 ' 65.39 66.93 65.64 64.60 -11.67 5.59 5978305.05 583013.40 N 70.35070349 W 149.915 950.00 14.85 343.00 867.15 943.95 77.74 79.28 77.93 76.43 -15.22 2.22 5978316.84 583009.72 N 70.35073580 W 149. 799 1000.00 17.34 344.83 915.19 991.99 91.59 93.14 91.75 89.75 -19.05 5.08 5978330.11 583005.75 N 70.35077219 W 149.32606903 1050.00 19.56 344.20 962.62 1039.42 107.42 108.96 107.54 104.99 -23.28 4.46 5978345.31 583001.35 N 70.35081384 W 149.32610336 1100.00 20.97 344.73 1009.52 1086.32 124.73 126.28 124.84 121.68 -27.91 2.84 5978361.94 582996.53 N 70.35085943 W 149.32614099 1150.00 23.54 345.82 1055.79 1132.59 143.67 145.21 143.77 139.99 -32.72 5.21 5978380.20 582991.53 N 70.35090946 W 149.32617999 Last GYD GC MS 1189.00 24.93 345.83 1091.35 1168.15 159.67 161.22 159.77 155.51 -36.64 3.56 5978395.67 582987.44 N 70.35095186 W 149.32621181 First MWD+IFR+MS 1223.53 26.97 347.57 1122.40 1199.20 174.77 176.33 174.88 170.22 -40.10 6.31 5978410.34 582983.81 N 70.35099203 W 149.32623996 1318.56 30.12 350.35 1205.87 1282.67 220.04 221.73 220.24 214.78 -48.74 3.60 5978454.80 582974.68 N 70.35111378 W 149.32631009 1411.57 33.23 353.54 1285.02 1361.82 268.46 270.55 268.92 263.13 -55.52 3.80 5978503.06 582967.36 N 70.35124585 W 149.32636514 1503.89 37.07 353.91 1360.50 1437.30 320.94 323.69 321.85 315.95 -61.32 4.17 5978555.81 582960.98 N 70.35139016 W 149.32641223 1597.02 42.40 353.85 1432.09 1508.89 379.69 383.20 381.18 375.12 -67.67 5.72 5978614.90 582953.98 N 70.35155181 W 149.32646376 1691.41 48.99 356.15 1497.99 1574.79 446.10 450.71 448.43 442.37 -73.48 7.20 5978682.08 582947.42 N 70.35173553 W 149.32651091 SurveyEditor Ver Bld(doc4Ox_37) L-124\L-124\L-124PB2\L-124PB2 Generated 5/17/2005 11:29 AM Page 1 of 5 Comments Measured Inclination Azimuth Sub-Sea ND TO Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude -/S.UU Depth 59/8/51.38 581941.14 N /U.351y15UL VV 14V.311i54/5L Section Departure 48.39 355.33 1618.31 1695.11 584.02 ft de de ft ft ft ft ft ft ft de 1700 ft (ftUS ftUS 1971.48 1781.57 5U.13 355.39 155/.1'1 1533.91 514.LU 51U.11 51/.54 5"11./3 -/S.UU 1.3/ 59/8/51.38 581941.14 N /U.351y15UL VV 14V.311i54/5L 1876.53 48.39 355.33 1618.31 1695.11 584.02 591.38 588.61 582.71 -83.13 2.14 5978822.29 582936.22 N 70.35211893 W 149.32658926 1971.48 48.87 354.60 1681.07 1757.87 654.14 662.64 659.77 653.69 -89.38 0.77 5978893.19 582929.18 N 70.35231284 W 149.32664005 2063.32 48.71 352.62 1741.58 1818.38 722.39 731.73 728.84 722.35 -97.07 1.63 5978961.75 582920.73 N 70.35250040 W 149.32670247 2156.39 47.68 352.60 1803.61 1880.41 791.11 801.10 798.22 791.15 -105.99 1.11 5979030.44 582911.05 N 70.35268835 W 149.32677492 2250.51 47.61 353.04 1867.03 1943.83 859.97 870.65 867.77 860.15 -114.68 0.35 5979099.34 582901.59 N 70.35287687 W 149.32684551 2344.98 48.30 353.62 1930.29 2007.09 929.33 940.81 937.91 929.83 -122.83 0.86 5979168.92 582892.68 N 70.35306723 W 149.32691166 2439.32 47.74 353.37 1993.39 2070.19 998.64 1010.94 1008.03 999.51 -130.78 0.63 5979238.50 582883.96 N 70.35325758 W 149.32697617 2531.44 47.60 354.75 2055.43 2132.23 1065.84 1079.04 1076.11 1067.25 -137.82 1.12 5979306.14 582876.16 N 70.35344262 W 149.32703341 2625.95 48.38 355.43 2118.68 2195.48 1134.91 1149.26 1146.27 1137.21 -143.83 0.98 5979376.03 582869.38 N 70.35363376 W 149.32708220 2718.09 48.26 354.82 2179.95 2256.75 1202.60 1218.08 1215.03 1205.78 -149.68 0.51 5979444.52 582862.78 N 70.35382108 W 149.3 2810.94 48.26 354.39 2241.77 2318.57 1270.85 1287.36 1284.29 1274.75 -156.19 0.35 5979513.41 582855.50 N 70.35400951 W 149.3 2905.05 47.71 353.70 2304.76 2381.56 1339.85 1357.28 1354.20 1344.30 -163.45 0.80 5979582.87 582847.48 N 70.35419950 W 149.32724148 2997.88 47.32 354.34 2367.45 2444.25 1407.41 1425.74 1422.64 1412.38 -170.58 0.66 5979650.86 582839.59 N 70.35438550 W 149.32729941 3092.44 46.68 353.91 2431.94 2508.74 1475.63 1494.90 1491.79 1481.17 -177.66 0.75 5979719.56 582831.75 N 70.35457343 W 149.32735689 3184.34 46.34 353.95 2495.19 2571.99 1541.45 1561.57 1558.46 1547.47 -184.71 0.37 5979785.78 582823.97 N 70.35475455 W 149.32741415 3267.71 45.04 355.35 2553.43 2630.23 1600.21 1621.22 1618.09 1606.86 -190.28 1.97 5979845.10 582817.74 N 70.35491681 W 149.32745939 3361.06 46.28 354.23 2618.67 2695.47 1665.94 1687.98 1684.83 1673.35 -196.35 1.58 5979911.50 582810.94 N 70.35509844 W 149.32750868 3454.83 47.62 356.46 2682.69 2759.49 1733.28 1756.50 1753.30 1741.64 -201.89 2.25 5979979.72 582804.63 N 70.35528499 W 149.32755373 3546.94 48.34 355.61 2744.34 2821.14 1800.37 1824.93 1821.66 1809.90 -206.63 1.04 5980047.92 582799.14 N 70.35547148 W 149.32759219 3640.51 48.21 356.83 2806.62 2883.42 1868.81 1894.77 1891.41 1879.58 -211.23 0.98 5980117.54 582793.77 N 70.35566185 W 149.32762959 3733.20 47.78 356.40 2868.65 2945.45 1936.20 1963.64 1960.20 1948.34 -215.30 0.58 5980186.24 582788.94 N 70.35584968 W 149.32766262 3827.42 48.44 355.24 2931.56 3008.36 2005.03 2033.78 2030.29 2018.29 -220.41 1.15 5980256.12 582783.05 N 70.35604078 W 149.32770418 3920.43 47.88 355.58 2993.60 3070.40 2073.12 2103.07 2099.55 2087.36 -225.96 0.66 5980325.12 582776.74 N 70.35622947 W 149.32774923 4013.97 46.74 356.18 3057.03 3133.83 2140.57 2171.83 2168.26 2155.94 -230.90 1.31 5980393.63 582771.04 N 70.35641681 W 149.32778939 4107.15 47.04 356.63 3120.71 3197.51 2207.19 2239.85 2236.23 2223.83 -235.17 0.48 5980461.47 582766.02 N 70.35660229 W 149.32782404 4205.93 48.71 357.37 3186.96 3263.76 2278.77 2313.11 2309.39 2296.99 -238.99 1.78 5980534.57 582761.39 N 70.35680215 W 149.32785514 4299.33 48.21 358.47 3248.90 3325.70 2346.83 2383.02 2379.14 2366.85 -241.53 1.03 5980604.39 582758.07 N 70.35699301 W 149.3578 4393.07 47.70 358.91 3311.68 3388.48 2414.38 2452.63 2448.54 2436.44 -243.13 0.65 5980673.96 582755.71 N 70.35718313 W 149. 73 4485.81 47.23 359.69 3374.37 3451.17 2480.52 2520.97 2516.62 2504.77 -243.96 0.80 5980742.27 582754.12 N 70.35736980 W 149.3 54 4579.05 47.97 358.02 3437.25 3514.05 2547.29 2589.82 2585.27 2573.61 -245.34 1.54 5980811.08 582751.97 N 70.35755785 W 149.32790678 4671.46 48.52 358.29 3498.79 3575.59 2614.34 2658.76 2654.08 2642.51 -247.56 0.63 5980879.94 582748.99 N 70.35774608 W 149.32792482 4765.16 47.65 357.81 3561.38 3638.18 2682.18 2728.48 2723.68 2712.19 -249.93 1.00 5980949.59 582745.85 N 70.35793646 W 149.32794409 4859.58 46.89 356.33 3625.45 3702.25 2749.93 2797.84 2792.98 2781.45 -253.47 1.40 5981018.80 582741.54 N 70.35812567 W 149.32797285 4951.15 45.59 354.65 3688.79 3765.59 2814.89 2863.97 2859.11 2847.38 -258.66 1.94 5981084.66 582735.62 N 70.35830578 W 149.32801501 5043.16 42.99 353.84 3754.64 3831.44 2878.25 2928.21 2923.35 2911.30 -265.09 2.89 5981148.50 582728.48 N 70.35848040 W 149.32806726 5136.17 39.23 352.25 3824.71 3901.51 2938.74 2989.35 2984.46 2971.99 -272.47 4.20 5981209.10 582720.44 N 70.35864621 W 149.32812715 5229.31 36.72 351.91 3898.13 3974.93 2995.57 3046.66 3041.70 3028.75 -280.36 2.70 5981265.77 582711.92 N 70.35880127 W 149.32819125 5322.70 34.28 351.59 3974.15 4050.95 3049.39 3100.89 3095.86 3082.42 -288.13 2.62 5981319.34 582703.55 N 70.35894788 W 149.32825443 5416.91 33.93 351.82 4052.16 4128.96 3101.82 3153.71 3148.61 3134.69 -295.76 0.40 5981371.52 582695.35 N 70.35909068 W 149.32831634 5509.82 33.67 353.59 4129.37 4206.17 3153.00 3205.40 3200.27 3185.96 -302.32 1.10 5981422.70 582688.22 N 70.35923073 W 149.32836967 SurveyEditor Ver Bid( doc40x_37 ) L -124\L -124\L-1 24PB2\L-1 24PB2 Generated 5/17/2005 11:29 AM Page 2 of 5 Comments Measured Inclination Azimuth Sub -Sea TO TO Vertical Along HOIe Closure NS EW DLS Northing Easting Latitude Longitude Depth U.20 DUO I4/'F.VO 002002.03 Section Departure DOD 5697.77 33.10 353.69 4286.18 ft de de ft ft ft it ft ft ft deg/1 00 ft (ftus) (ftus 582675.86 SurveyEditor Ver Bid( doc40x_37 ) L-124\L-124\L-124PB2\L-124PB2 Generated 5/17/2005 11:29 AM Page 3 of 5 5603.32 33.52 353.93 420/.25 4204.05 3204.09 325/.13 3202.00 JL3/A0 -30/.54 U.20 DUO I4/'F.VO 002002.03 IN /U.3DV3/ ILL " 140.02041 DOD 5697.77 33.10 353.69 4286.18 4362.98 3255.31 3309.00 3303.86 3288.95 -313.54 0.47 5981525.55 582675.86 N 70.35951210 W 149.32846080 5791.30 33.02 353.75 4364.57 4441.37 3305.71 3360.02 3354.88 3339.67 -319.12 0.09 5981576.20 582669.72 N 70.35965065 W 149.32850614 5884.67 32.79 353.51 4442.96 4519.76 3355.82 3410.74 3405.59 3390.08 -324.75 0.28 5981626.54 582663.54 N 70.35978836 W 149.32855186 5977.02 32.50 352.97 4520.72 4597.52 3405.08 3460.56 3455.40 3439.55 -330.61 0.45 5981675.94 582657.13 N 70.35992351 W 149.32859950 6070.61 33.51 354.16 4599.21 4676.01 3455.45 3511.54 3506.37 3490.20 -336.31 1.28 5981726.52 582650.86 N 70.36006190 W 149.32864586 6164.15 33.80 354.91 4677.07 4753.87 3506.53 3563.38 3558.21 3541.80 -341.25 0.54 5981778.06 582645.35 N 70.36020287 W 149.32868596 6257.67 34.98 354.74 4754.24 4831.04 3558.53 3616.20 3611.03 3594.41 -346.02 1.27 5981830.61 582640.01 N 70.36034658 W 149.32872469 6352.48 35.08 354.70 4831.88 4908.68 3612.13 3670.62 3665.45 3648.60 -351.02 0.11 5981884.73 582634.40 N 70.36049462 W 149.32876538 6446.81 34.80 354.23 4909.20 4986.00 3665.37 3724.64 3719.47 3702.37 -356.23 0.41 5981938.44 582628.59 N 70.36064152 W 149.32880772 6539.74 34.73 354.47 4985.55 5062.35 3717.62 3777.63 3772.46 3755.11 -361.45 0.17 5981991.11 582622.79 N 70.36078558 W 149.31 6632.08 34.52 354.80 5061.53 5138.33 3769.30 3830.10 3824.93 3807.34 -366.36 0.30 5982043.28 582617.31 N 70.36092829 W 149.328 98 6725.61 33.91 354.17 5138.87 5215.67 3821.13 3882.69 3877.52 3859.69 -371.41 0.75 5982095.57 582611.68 N 70.36107130 W 149.32893104 6817.78 33.46 354.04 5215.57 5292.37 3871.56 3933.81 3928.64 3910.54 -376.66 0.49 5982146.35 582605.87 N 70.36121021 W 149.32897370 6911.47 32.98 353.64 5293.95 5370.75 3922.24 3985.14 3979.96 3961.57 -382.17 0.56 5982197.31 582599.79 N 70.36134963 W 149.32901845 7004.52 32.67 353.21 5372.14 5448.94 3972.10 4035.58 4030.39 4011.68 -387.94 0.42 5982247.35 582593.47 N 70.36148652 W 149.32906537 7098.79 32.25 352.72 5451.68 5528.48 4022.17 4086.18 4080.97 4061.90 -394.14 0.53 5982297.49 582586.72 N 70.36162370 W 149.32911571 7192.58 32.13 348.94 5531.06 5607.86 4071.83 4136.13 4130.82 4111.20 -402.09 2.15 5982346.70 582578.21 N 70.36175839 W 149.32918036 7284.82 34.86 343.35 5608.00 5684.80 4122.67 4187.00 4181.13 4160.55 -414.36 4.46 5982395.90 582565.41 N 70.36189321 W 149.32927999 7379.32 34.49 342.69 5685.71 5762.51 4176.41 4240.76 4233.87 4211.97 -430.06 0.56 5982447.14 582549.14 N 70.36203368 W 149.32940753 7472.08 36.50 338.28 5761.24 5838.04 4230.08 4294.60 4286.17 4262.69 -448.08 3.51 5982497.65 582530.55 N 70.36217223 W 149.32955400 7565.55 39.52 334.06 5834.89 5911.69 4286.96 4352.14 4340.95 4315.28 -471.39 4.26 5982549.97 582506.67 N 70.36231590 W 149.32974333 7658.32 42.03 329.55 5905.16 5981.96 4345.96 4412.70 4397.14 4368.61 -500.05 4.17 5982602.98 582477.42 N 70.36246160 W 149.32997617 7751.95 45.04 324.85 5973.04 6049.84 4407.40 4477.17 4454.99 4422.74 -535.02 4.72 5982656.72 582441.85 N 70.36260948 W 149.33026028 7844.76 48.63 321.70 6036.53 6113.33 4470.36 4544.84 4513.79 4476.95 -575.53 4.59 5982710.46 582400.75 N 70.36275755 W 149.33058934 7937.78 50.20 320.66 6097.05 6173.85 4535.12 4615.48 4574.17 4531.98 -619.82 1.89 5982765.00 582355.86 N 70.36290788 W 149.33094912 8032.38 52.52 317.88 6156.12 6232.92 4601.81 4689.36 4636.32 4587.94 -668.04 3.36 5982820.42 582307.02 N 70.36306075 W 149.33134088 8125.10 54.22 316.67 6211.44 6288.24 4667.83 4763.77 4697.87 4642.59 -718.53 2.11 5982874.50 582255.94 N 70.36321004 W 149.'3'3103 8217.89 56.34 314.67 6264.29 6341.09 4734.49 4840.03 4760.12 4697.13 -771.83 2.89 5982928.44 582202.04 N 70.36335902 W 149. 03 8312.65 60.18 313.24 6314.14 6390.94 4803.71 4920.60 4824.94 4753.04 -829.85 4.25 5982983.69 582143.42 N 70.36351174 W 149.3 535 Tie -In Survey 8404.48 65.07 312.20 6356.35 6433.15 4872.83 5002.12 4889.96 4808.33 -889.75 5.42 5983038.32 582082.91 N 70.36366277 W 149.33314200 Top Whipstock ( Blind) 8487.00 69.96 310.30 6387.90 6464.70 4936.40 5078.34 4950.01 4858.57 -947.07 6.30 5983087.91 582025.04 N 70.36380000 W 149.33360767 Base Whipstock ( Blind 8499.00 71.54 309.14 6391.86 6468.66 4945.68 5089.67 4958.79 4865.81 -955.78 16.02 5983095.05 582016.25 N 70.36381977 W 149.33367846 First Inc + Trend (Blind) 8513.17 72.15 308.66 6396.27 6473.07 4956.60 5103.14 4969.11 4874.26 -966.26 5.38 5983103.39 582005.68 N 70.36384287 W 149.33376359 8532.04 74.02 308.04 6401.76 6478.56 4971.13 5121.19 4982.87 4885.46 -980.42 10.40 5983114.43 581991.40 N 70.36387346 W 149.33387861 8562.88 77.17 307.04 6409.43 6486.23 4994.93 5151.06 5005.41 4903.66 -1004.10 10.69 5983132.36 581967.52 N 70.36392316 W 149.33407101 8593.93 80.14 306.05 6415.54 6492.34 5018.86 5181.50 5028.11 4921.78 -1028.56 10.06 5983150.21 581942.87 N 70.36397267 W 149.33426969 8625.17 85.32 305.08 6419.49 6496.29 5042.88 5212.47 5050.94 4939.80 -1053.76 16.86 5983167.95 581917.47 N 70.36402188 W 149.33447443 Last Inc + Trend (Blind) 8656.32 86.35 304.12 6421.76 6498.56 5066.64 5243.54 5073.58 4957.44 -1079.33 4.51 5983185.30 581891.71 N 70.36407006 W 149.33468218 First MWD+IFR+MS 8686.60 89.61 303.20 6422.82 6499.62 5089.45 5273.80 5095.36 4974.21 -1104.51 11.19 5983201.79 581866.34 N 70.36411586 W 149.33488678 SurveyEditor Ver Bid( doc40x_37 ) L-124\L-124\L-124PB2\L-124PB2 Generated 5/17/2005 11:29 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub -Sea ND TO Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude 91.26 Depth 6295.88 294.00 5343.94 6418.22 Section I Departure 6403.71 93.42 6480.51 290.25 90.50 6416.28 6493.08 8871.77 91.26 ft de de ft ft ft ft ft ft ft de /100 ft ftUS ftUS 6489.46 8934.44 8118.32 91.t)U 3U1.Ub b4ZZ.bZ b4Vv.3Z 8749.11 92.25 6467.62 298.69 5296.61 6421.51 6498.31 8781.02 265.77 93.35 6404.65 295.66 6481.45 6419.95 6496.75 8809.51 91.26 93.59 6295.88 294.00 5343.94 6418.22 6495.02 8841.27 6403.71 93.42 6480.51 290.25 90.50 6416.28 6493.08 8871.77 91.26 93.49 6389.83 288.47 6466.63 6414.44 6491.24 8902.63 90.88 93.15 5352.47 284.74 257.18 6412.66 6489.46 8934.44 90.50 93.28 5388.35 280.62 6410.87 6487.67 8965.44 90.47 92.77 278.17 6409.23 6486.03 8996.74 90.85 91.63 274.73 6408.03 6484.83 9026.93 90.95 91.77 271.69 6407.14 6483.94 9057.48 9089.10 9121.33 9151.49 9182.65 9213.59 9242.27 9274.09 9304.27 9335.48 9366.40 9397.46 9428.26 9459.70 9491.71 9522.49 9553.50 9584.79 9616.02 9647.18 9678.27 9709.31 9740.96 9772.58 9802.94 9834.33 9865.67 9896.80 9928.12 9959.64 92.49 268.61 6467.62 6406.00 5296.61 6482.80 5362.41 92.39 265.77 253.03 6404.65 6402.46 6481.45 6479.26 90.37 264.38 91.26 6403.88 6295.88 6480.68 5343.94 90.26 261.24 5302.69 6403.71 253.02 6480.51 6401.06 90.50 257.38 6403.51 91.26 6480.31 6389.83 0"11 Z.OU 5134.61 5156.12 5174.44 5193.70 5211.00 5227.27 5242.16 5255.08 5266.66 5276.23 5284.35 5291.17 5296.96 5301.21 5303.70 91.19 254.27 6467.62 6403.05 5296.61 6479.85 5362.41 5304.30 91.15 253.03 255.45 6402.46 6391.56 6479.26 6468.36 5303.76 91.26 252.54 6295.88 6401.79 5343.94 6478.59 256.90 5302.69 91.53 253.02 5298.77 6401.06 5374.64 6477.86 5301.66 91.26 253.08 6389.83 6400.30 6466.63 6477.10 5295.96 5300.75 90.88 253.70 5352.47 6399.72 257.18 6476.52 6470.43 5300.04 90.50 253.01 5388.35 6399.35 6476.15 5299.30 90.47 252.85 6399.09 6475.89 5298.34 90.85 252.87 6398.73 6475.53 5297.31 90.95 253.35 6398.22 6475.02 5296.42 91.36 253.51 6397.60 6474.40 5295.72 91.40 254.33 6396.86 6473.66 5295.29 91.84 254.51 6395.97 6472.77 5295.13 91.98 255.06 6394.93 6471.73 5295.16 92.12 255.50 6393.82 6470.62 5295.47 92.08 92.05 91.50 91.22 88.48 88.17 88.21 88.89 89.06 89.23 OJU0.0Z 5336.29 5368.16 5396.60 5428.30 5458.74 5489.55 5521.31 5552.27 5583.54 5613.72 5644.25 5675.84 5708.06 5738.22 5769.38 5800.31 5828.99 5860.80 5890.97 5922.17 5953.09 5984.15 6014.94 6046.38 6078.39 6109.16 6140.16 6171.44 6202.65 6233.79 0"1 It. fu 5138.59 5159.22 5176.82 5195.37 5212.09 5227.89 5242.42 5255.14 5266.66 5276.33 5284.72 5292.00 5298.44 5303.47 5306.96 5308.73 5309.45 5309.94 5310.58 5311.57 5312.92 5314.43 5315.88 5317.51 5319.50 5321.76 5324.48 5327.68 5331.25 5335.26 255.39 6392.68 6467.62 6469.48 5296.61 5295.86 5362.41 6264.86 5339.52 255.45 256.87 6391.56 6468.61 6468.36 5297.60 5296.24 5368.36 6295.88 5343.94 254.43 256.90 6390.58 6469.40 6467.38 5298.77 5296.36 5374.64 6327.52 5348.37 253.56 257.69 6389.83 6469.96 6466.63 5300.18 5295.96 5381.35 6359.13 5352.47 255.77 257.18 6389.91 6470.43 6466.71 5301.67 5295.93 5388.35 6389.49 5356.92 4`J`.1 Luo 1 1151.01 5006.40 -1158.06 5020.96 -1186.40 5032.90 -1212.21 5044.83 -1241.57 5054.93 -1270.30 5063.73 -1299.81 5070.70 -1330.79 5075.75 -1361.33 5079.26 -1392.41 5080.95 -1422.53 5081.03 -1453.06 5079.49 -1484.61 5076.72 -1516.71 5072.94 -1546.62 5067.17 -1577.24 5059.59 -1607.23 5051.52 -1634.74 5042.10 -1665.13 5033.17 -1693.95 5024.08 -1723.79 5015.24 -1753.42 5006.34 -1783.17 4997.30 -1812.62 4988.04 -1842.66 4978.74 -1873.28 4969.96 -1902.78 4961.38 -1932.57 4952.98 -1962.69 4944.78 -1992.81 4936.87 -2022.93 4929.06 -2053.00 4921.25 -2083.02 4913.03 -2113.57 4904.32 -2143.96 4896.29 -2173.23 256.17 6390.82 6467.62 5296.61 6420.86 5362.41 4888.68 -2203.67 256.87 6391.81 6468.61 5297.60 6452.19 5368.36 4881.38 -2234.13 256.90 6392.60 6469.40 5298.77 6483.31 5374.64 4874.32 -2264.44 257.69 6393.16 6469.96 5300.18 6514.62 5381.35 4867.43 -2294.99 257.18 6393.63 6470.43 5301.67 6546.14 5388.35 4860.58 -2325.75 `J.UZ Wjo3Z10.00 0018SJAV IV /U.00141U I`J3 W I+V.3301 U4yy 8.04 5983233.38 581812.45 N 70.36420378 W 149.33532177 10.09 5983247.62 581783.94 N 70.36424353 W 149.33555208 5.88 5983259.27 581758.01 N 70.36427615 W 149.33576175 11.80 5983270.88 581728.52 N 70.36430874 W 149.33600028 5.83 5983280.66 581699.69 N 70.36433630 W 149.33623361 12.12 5983289.13 581670.08 N 70.36436033 W 149.33647342 12.94 5983295.76 581639.03 N 70.36437936 W 149.33672509 8.06 5983300.47 581608.44 N 70.36439315 W 149.33697318 11.57 5983303.64 581577.33 N 70.36440273 W 149.33722561 10.08 5983304.99 581547.19 N 70.36440733 W 149.34 10.35 5983304.74 581516.67 N 70.36440753 W 149.33 32 8.98 5983302.84 581485.14 N 70.36440329 W 149.33797461 7.61 5983299.72 581453.08 N 70.36439571 W 149.33823536 10.42 5983295.61 581423.20 N 70.36438538 W 149.33847840 12.41 5983289.49 581392.66 N 70.36436958 W 149.33872708 10.30 5983281.59 581362.76 N 70.36434887 W 149.33897069 4.32 5983273.21 581335.34 N 70.36432680 W 149.33919418 1.58 5983263.46 581305.06 N 70.36430106 W 149.33944102 1.82 5983254.21 581276.34 N 70.36427664 W 149.33967511 0.89 5983244.79 581246.60 N 70.36425177 W 149.33991755 2.35 5983235.62 581217.08 N 70.36422761 W 149.34015819 2.54 5983226.40 581187.43 N 70.36420329 W 149.34039989 0.53 5983217.03 581158.09 N 70.36417857 W 149.34063904 1.21 5983207.44 581128.16 N 70.36415324 W 149.34088307 1.53 5983197.80 581097.64 N 70.36412782 W 149.34113183 1.43 5983188.70 581068.25 N 70.36410382 W 149.34137142 2.65 5983179.78 581038.56 N 70.36408034 W 14938 1.52 5983171.05 581008.53 N 70.36405737 W 14910 1.82 5983162.53 580978.51 N 70.36403497 W 149.3 275 1.48 5983154.28 580948.48 N 70.36401334 W 149.34234739 0.38 5983146.14 580918.50 N 70.36399198 W 149.34259166 0.22 5983138.00 580888.57 N 70.36397063 W 149.34283551 3.66 5983129.45 580858.12 N 70.36394815 W 149.34308364 2.89 5983120.39 580827.83 N 70.36392431 W 149.34333046 11.59 5983112.04 580798.65 N 70.36390236 W 149.34356825 1.61 5983104.10 580768.30 N 70.36388156 W 149.34381550 2.24 5983096.46 580737.92 N 70.36386158 W 149.34406293 2.19 5983089.07 580707.70 N 70.36384227 W 149.34430911 2.58 5983081.84 580677.23 N 70.36382343 W 149.34455725 1.71 5983074.65 580646.55 N 70.36380467 W 149.34480711 SurveyEditor Ver Bid( doc40x_37 ) L-124\L-124\L-124PB2\L-124PB2 Generated 5/17/2005 11:29 AM Page 4 of 5 9990.50 10021.58 10052.72 10084.19 10116.27 10146.13 10177.60 10209.22 10239.87 10270.58 10301.84 10332.82 10363.97 10395.56 10427.69 10457.86 10490.18 10519.02 10550.00 Last MWD+IFR+MS 10562.79 TD ( Projected ) 10615.00 89.10 89.24 88.82 89.82 91.26 91.60 92.49 92.53 91.88 91.91 91.88 91.77 92.80 94.31 94.07 92.39 90.95 89.03 89.03 87.90 87.90 257.77 Measured 6394.08 580156.33 6470.88 N 70.36358525 W 149.34879689 Vertical Along Hole 5395.40 4853.89 12.88 -2355.87 1.96 Comments 257.85 Inclination Azimuth Sub -Sea ND ND 5304.83 Closure NS EW DLS Northing Easting Latitude Longitude Depth 5983060.72 260.07 6395.06 Section I Departure 5307.13 6639.21 5411.08 4841.36 ft de de ft k ft ft ft ft ft deg/1 00 it ftUS ftUS 5420.29 9990.50 10021.58 10052.72 10084.19 10116.27 10146.13 10177.60 10209.22 10239.87 10270.58 10301.84 10332.82 10363.97 10395.56 10427.69 10457.86 10490.18 10519.02 10550.00 Last MWD+IFR+MS 10562.79 TD ( Projected ) 10615.00 89.10 89.24 88.82 89.82 91.26 91.60 92.49 92.53 91.88 91.91 91.88 91.77 92.80 94.31 94.07 92.39 90.95 89.03 89.03 87.90 87.90 257.77 5982989.07 6394.08 580156.33 6470.88 N 70.36358525 W 149.34879689 5303.16 6576.99 5395.40 4853.89 12.88 -2355.87 1.96 5983067.62 257.85 4.91 6394.53 6471.33 5304.83 11.95 6608.07 5402.85 4847.32 0.00 -2386.25 0.52 5983060.72 260.07 6395.06 6471.86 5307.13 6639.21 5411.08 4841.36 -2416.81 7.25 5983054.42 260.61 6395.43 6472.23 5310.22 6670.67 5420.29 4836.08 -2447.83 3.61 5983048.80 260.71 6395.13 6471.93 5313.54 6702.75 5430.03 4830.88 -2479.48 4.50 5983043.25 260.68 6394.39 6471.19 5316.64 6732.60 5439.26 4826.05 -2508.94 1.14 5983038.09 261.29 6393.26 6470.06 5320.07 6764.05 5449.29 4821.12 -2540.00 3.43 5983032.82 261.52 6391.88 6468.68 5323.75 6795.64 5459.76 4816.40 -2571.23 0.74 5983027.76 262.35 6390.70 6467.50 5327.60 6826.27 5470.32 4812.10 -2601.56 3.44 5983023.12 262.81 6389.68 6466.48 5331.80 6856.96 5481.39 4808.14 -2631.99 1.50 5983018.82 262.63 262.21 260.96 260.73 260.91 260.04 260.36 257.18 258.70 257.67 257.67 6388.65 6465.45 6387.66 6464.46 6386.42 6463.22 6384.46 6461.26 6382.11 6458.91 6380.41 6457.21 6379.47 . 6456.27 6379.48 6456.28 6380.00 6456.80 6380.34 6457.14 6382.26 6459.06 5336.14 5340.29 5344.01 5347.38 5350.78 5353.80 5356.89 5358.92 5360.66 5361.44 5364.12 6888.20 5492.87 6919.17 5504.26 6950.29 5515.43 6981.82 5526.52 7013.87 5537.94 7043.99 5548.66 7076.29 5560.17 7105.13 5569.90 7136.11 5580.08 7148.89 5584.38 7201.07 5601.75 4804.18 -2662.98 4800.10 -2693.68 4795.54 -2724.47 4790.53 -2755.59 4785.41 -2787.23 4780.43 -2816.93 4774.93 -2848.77 4769.31 -2877.05 4762.84 -2907.34 4760.23 -2919.86 4749.08 -2970.83 0.58 5983014.52 1.40 5983010.10 5.20 5983005.20 4.83 5982999.84 0.93 5982994.38 580616.51 N 70.36378636 W 149.34505179 580586.21 N 70.36376841 W 149.34529853 580555.72 N 70.36375210 W 149.34554674 580524.77 N 70.36373764 W 149.34579872 580493.18 N 70.36372339 W 149.34605582 580463.78 N 70.36371018 W 149.34629510 580432.77 N 70.36369669 W 149.34654740 580401.60 N 70.36368376 W 149.34680112 580371.32 N 70.36367200 W 149.34704744 580340.94 N 70.36366114 W 149.34729467 580310.00 N 70.36365029 W 149.3 580279.35 N 70.36363910 W 149.34 3 580248.62 N 70.36362663 W 149.34804582 580217.55 N 70.36361290 W 149.34829865 580185.98 N 70.36359890 W 149.34855561 6.27 5982989.07 580156.33 N 70.36358525 W 149.34879689 4.56 5982983.22 580124.57 N 70.36357020 W 149.34905547 12.88 5982977.29 580096.35 N 70.36355483 W 149.34928519 4.91 5982970.48 580066.13 N 70.36353711 W 149.34953124 11.95 5982967.73 580053.65 N 70.36352995 W 149.34963288 0.00 5982956.02 580002.81 N 70.36349946 W 149.35004690 Survey Type: Definitive Survey NOTES: GYD-GC-MS - ( Gyrodata - gyro compassing m/s -- Older Gyrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex -BP "Gyrodata multishot into open hole" model. Not to be run above 70 degrees inclination.. ) MWD + IFR + MS - ( In -field referenced MWD with mult-station analysis and correction applied in post -processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Leaal Description: Surface: 2520 FSL 3889 FEL S34 T12N R11 E UM BHL : 1989 FSL 1571 FEL S28 T1 2N R11 E UM Northing (Y) [ftUS] Easting (X) [ftUS] 5978240.59 583025.79 is 5982956.02 580002.81 SurveyEditor Ver Bid( doc40x_37 ) L-124\L-124\L-124PB2\L-124PB2 Generated 5/17/2005 11:29 AM Page 5 of 5 4-1/2" 12.6# L-80 3.958" ID 9 5/8", 40.0#, L-80, 3,227 BTC 1 3-1/2" 9.2 # L-80 2.992" I D I HES 3 1/2" BHG w/ I w ire to surface8,211 Baker 7" X 3 1/2" Prenuer Packer 8,231 3 1/2", 9.2#, L-80, IBT-M tubing 8,537 Baker HMC liner hngr, ZXP pkr, w / 11.41' x 8,285 5.25" ID TBS Baker Whip stock, 8,487 (Top of w indoor ) H I HES 7" ¢SV 8,500 7", 26.0#, L-80, BTG M ]�—g , 096 L-1 24 FROM FT ��. 67 4 1/2" —X3 1/2" tubing crossover 2,015 HES 3 1/2"'X' nipple; I.D. = 2.813" TREE= 4 1/16" CIW WELLHEAD = FMC ACTUATOR= LEO KB. ELEV = 72.60' AMSL CB. ELEV = KOP = 48.30' AMSL 300' Max Angle = 94° @ 10396' Datum MD = Datum TVD = 8,646' 6,498' Minimum ID = 2.813" @ 2015', 8191', 8257', 8278' GAS LIFT MANDRELS ST MD I TVD DEV TYPE VLV LATCH PORT DATE 7 2318 1990 48 MMG DOME RK 16 06/01/05 6 3222 2598 46 MMG DMY RK 0 05/14/05 5 4405 3396 48 MMG DMY RK 0 05/14/05 4 5367 4088 34 MMG DOME RK 16 06/01/05 3 6217 4798 34 MMG DMY RK 0 06/01/05 2 7054 5491 32 MMG DOME RK 16 06/01/05 1 8132 6290 55 MMG SO RK 20 06/01/05 8,191 HES 3 1/2"'X' nipple; I.D. = 2.813" 8,257 HES 3 1/2"'X' nipple; I.D. = 2.813" $,278 HES 3 1/2" 'X' nipple; 1. D. = 2.813" 8315' - 8398' Solid liner 9102' - 9269' Solid liner w / 'RA' Tag in box end of upper joint PBTD 10,725 4 1/2", 12.6 #, L-80 IBT-M slotted liner IT 10,727 DATE REV BY COMMENTS DATE REV BY COMMENTS 02/16/05 DEW Proposed Completion (Wp05) 04/05/05 STG Proposed Completion (Wp06) 05/14/05 9es As Built 06/07/05 MGS/TLH GLV C/O PRUDHOE BAY UNIT WELL: L-124 PERMIT No: 205-043 API No: 50-029-23255 BP Exploration (Alaska) SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Borealis Well ...................... L-124 API number ...............: 50-029-23255-00 Engineer .................: F. Medina Rig: ..................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods ------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 48.40 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 76.80 ft ----- Vertical section origin ---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)......... 0.00 ft ----- Platform reference point --------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 344.72 degrees 11 -May -2005 11:00:50 Page 1 of 7 Spud date ................: 26 -Apr -05 Last survey date.........: 11 -May -05 Total accepted surveys...: 171 MD of first survey.......: 0.00 ft MD of last survey........: 10774.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 05 -May -2005 Magnetic field strength..: 1152.22 HCNT Magnetic dec (+E/W-).....: 24.48 degrees Magnetic dip .............: 80.81 degrees ----- MWD survey Reference Criteria --------- Reference G ............... 1002.68 mGal Reference H ..............: 1152.22 HCNT Reference Dip ............: 80.81 degrees Tolerance of G...........: (+/-) 2.50 mGal Tolerance of H...........: (+/-) 6.00 HCNT Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections ---------------------- Magnetic dec (+E/W-)..... : 24.48 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.48 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCHLUMBERGER Survey Report 11 -May -2005 11:00:50 Page 2 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ------ ----- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type (deg) ----- ------ --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 -------- 0.00 -------- 0.00 ---------------- 0.00 0.00 --------------- 0.00 0.00 ----- 0.00 ----- ------ TIP None 2 100.00 0.20 271.64 100.00 100.00 0.05 0.00 -0.17 0.17 271.64 0.20 GYRO None 3 200.00 0.33 49.75 100.00 200.00 0.22 0.20 -0.13 0.23 326.63 0.50 GYRO None 4 300.00 1.82 21.25 100.00 299.98 1.62 1.86 0.67 1.98 19.69 1.54 GYRO None 5 400.00 2.70 5.81 100.00 399.90 5.09 5.69 1.48 5.88 14.59 1.06 GYRO None 6 500.00 3.78 359.68 100.00 499.74 10.48 11.33 1.70 11.45 8.54 1.13 GYRO None 7 600.00 5.59 349.43 100.00 599.40 18.52 19.41 0.79 19.43 2.33 1.99 GYRO None 8 700.00 7.64 345.53 100.00 698.73 30.02 30.64 -1.77 30.69 356.70 2.10 GYRO None 9 800.00 10.20 343.51 100.00 797.52 45.52 45.56 -5.94 45.95 352.57 2.58 GYRO None 10 850.00 10.96 342.90 50.00 846.67 54.70 54.35 -8.60 55.03 351.01 1.54 GYRO None 11 900.00 13.75 343.59 50.00 895.50 65.39 64.60 -11.67 65.64 349.76 5.59 GYRO None 12 950.00 14.85 343.00 50.00 943.95 77.74 76.43 -15.22 77.93 348.73 2.22 GYRO None 13 1000.00 17.34 344.83 50.00 991.99 91.59 89.75 -19.05 91.75 348.02 5.08 GYRO None 14 1050.00 19.56 344.20 50.00 1039.42 107.42 104.99 -.23.28 107.54 347.50 4.46 GYRO None 15 1100.00 20.97 344.73 50.00 1086.32 124.73 121.68 -27.91 124.84 347.08 2.84 GYRO None 16 1150.00 23.54 345.82 50.00 1132.59 143.67 139.99 -32.72 143.77 346.85 5.21 GYRO None 17 1189.00 24.93 345.83 39.00 1168.15 159.67 155.51 -36.64 159.77 346.74 3.56 GYRO None 18 1223.53 26.97 347.57 34.53 1199.20 174.77 170.22 -40.10 174.88 346.74 6.31 MWD_IFR_MS 19 1318.56 30.12 350.35 95.03 1282.67 220.04 214.78 -48.74 220.24 347.21 3.60 MWD_IFR_MS 20 1411.57 33.23 353.54 93.01 1361.82 268.46 263.13 -55.52 268.92 348.08 3.80 MWD_IFR_MS 21 1503.89 37.07 353.91 92.32 1437.30 320.94 315.95 -61.32 321.85 349.02 4.17 MWD_IFR_MS 22 1597.02 42.40 353.85 93.13 1508.89 379.69 375.12 -67.67 381.18 349.77 5.72 MWD_IFR_MS 23 1691.41 48.99 356.15 94.39 1574.78 446.10 442.37 -73.48 448.43 350.57 7.20 MWD_IFR_MS 24 1782.67 50.23 356.39: 91.26 1633.92 514.20 511.73 -78.00 517.64 351.33 1.37 MWD_IFR_MS 25 1876.53 48.39 355.33 93.86 1695.11 584.02 582.71 -83.13 588.61 351.88 2.14 MWD_IFR_MS 26 1971.48 48.87 354.60 94.95 1757.87 654.14 653.69 -89.38 659.77 352.21 0.77 MWD_IFR_MS 27 2063.32 48.71 352.62 91.84 1818.38 722.39 722.35 -97.07 728.84 352.35 1.63 MWD_IFR_MS 28 2156.39 47.68 352.60 93.07 1880.41 791.11 791.15 -105.99 798.22 352.37 1.11 MWD_IFR_MS 29 2250.51 47.61 353.04 94.12 1943.83 859.97 860.15 -114.68 867.77 352.41 0.35 MWD_IFR_MS 30 2344.98 48.30 353.62 94.47 2007.09 929.33 929.83 -122.83 937.91 352.47 0.86 MWD_IFR_MS SCHLUMBERGER Survey Report 11 -May -2005 11:00:50 Page 3 of 7 --- - --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ------ ----- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ----- (deg) ------ 31 2439.32 47.74 353.37 94.34 2070.19 998.64 999.51 -130.78 1008.03 352.55 0.63 MWD -IFR -MS 32 2531.44 47.60 354.75 92.12 2132.23 1065.84 1067.25 -137.82 1076.11 352.64 1.12 MWD -IFR -MS 33 2625.95 48.38 355.43 94.51 2195.48 1134.91 1137.21 -143.83 1146.27 352.79 0.98 MWD_IFR_MS 34 2718.09 48.26 354.82 92.14 2256.75 1202.60 1205.78 -149.68 1215.03 352.92 0.51 MWD -IFR -MS 35 2810.94 48.26 354.39 92.85 2318.57 1270.85 1274.75 -156.19 1284.29 353.01 0.35 MWD_IFR_MS 36 2905.05 47.71 353.70 94.11 2381.56 1339.85 1344.30 -163.45 1354.20 353.07 0.80 MWD -IFR _MS • 37 2997.88 47.32 354.34 92.83 2444.25 1407.41 1412.38 -170.58 1422.64 353.11 0.66 MWD -IFR _MS 38 3092.44 46.68 353.91 94.56 2508.74 1475.63 1481.17 -177.66 1491.79 353.16 0.75 MWD -IFR _MS 39 3184.34 46.34 353.95 91.90 2571.99 1541.44 1547.47 -184.71 1558.46 353.19 0.37 MWD_IFR_MS 40 3267.71 45.04 355.35 83.37 2630.23 1600.21 1606.86 -190.28 1618.09 353.25 1.97 MWD -IFR -MS 41 3361.06 46.28 354.23 93.35 2695.47 1665.94 1673.35 -196.35 1684.83 353.31 1.58 MWD_IFR_MS 42 3454.83 47.62 356.46 93.77 2759.49 1733.28 1741.64 -201.89 1753.30 353.39 2.25 MWD_IFR_MS 43 3546.94 48.34 355.61 92.11 2821.15 1800.37 1809.90 -206.63 1821.66 353.49 1.04 MWD_IFR_MS 44 3640.51 48.21 356.83 93.57 2883.42 1868.81 1879.58 -211.23 1891.41 353.59 0.98 MWD_IFR_MS 45 3733.20 47.78 356.40 92.69 2945.45 1936.20 1948.34 -215.30 1960.20 353.69 0.58 MWD -IFR -MS 46 3827.42 48.44 355.24 94.22 3008.36 2005.03 2018.29 -220.41 2030.29 353.77 1.15 MWD_IFR_MS 47 3920.43 47.88 355.58 93.01 3070.40 2073.12 2087.36 -225.96 2099.55 353.82 0.66 MWD_IFR_MS 48 4013.97 46.74 356.18 93.54 3133.83 2140.57 2155.94 -230.90 2168.26 353.89 1.31 MWD_IFR_MS 49 4107.15 47.04 356.63 93.18 3197.51 2207.19 2223.83 -235.17 2236.23 353.96 0.48 MWD -IFR -MS 50 4205.93 48.71 357.37 98.78 3263.76 2278.77 2296.99 -238.99 2309.39 354.06 1.78 MWD_IFR_MS 51 4299.33 48.21 358.47 93.40 3325.70 2346.83 2366.85 -241.53 2379.14 354.17 1.03 MWD_IFR_MS 52 4393.07 47.70 358.91 93.74 3388.48 2414.38 2436.44 -243.13 2448.54 354.30 0.65 MWD_IFR_MS 53 4485.81 47.23 359.69 92.74 3451.18 2480.52 2504.77 -243.96 2516.63 354.44 0.80 MWD_IFR_MS 54 4579.05 47.97 358.02 93.24 3514.05 2547.29 2573.61 -245.34 2585.27 354.55 1.54 MWD_IFR_MS 55 4671.46 48.52 358.29 92.41 3575.59 2614.34 2642.51 -247.56 2654.08 354.65 0.63 MWD -IFR -MS 56 4765.16 47.65 357.81 93.70 3638.18 2682.18 2712.19 -249.93 2723.68 354.73 1.00 MWD_IFR_MS 57 4859.58 46.89 356.33 94.42 3702.25 2749.93 2781.46 -253.47 2792.98 354.79 1.40 MWD_IFR_MS 58 4951.15 45.59 354.65 91.57 3765.59 2814.89 2847.38 -258.66 2859.11 354.81 1.94 MWD_IFR_MS 59 5043.16 42.99 353.84 92.01 3831.44 2878.25 2911.30 -265.09 2923.35 354.80 2.89 MWD_IFR_MS 60 5136.17 39.23 352.25 93.01 3901.51 2938.74 2972.00 -272.47 2984.46 354.76 4.20 MWD_IFR_MS SCHLUMBERGER Survey Report 11 -May -2005 11:00:50 Page 4 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 -------- 5229.31 ------ 36.72 ------- 351.91 ------ 93.14 -------- 3974.93 2995.57 3028.76 -280.36 3041.70 354.71 2.70 MWD_IFR_MS 62 5322.70 34.28 351.59 93.39 4050.95 3049.39 3082.42 -288.13 3095.86 354.66 2.62 MWD_IFR_MS 63 5416.91 33.93 351.82 94.21 4128.96 3101.82 3134.69 -295.76 3148.62 354.61 0.40 MWD_IFR_MS 64 5509.82 33.67 353.60 92.91 4206.17 3153.00 3185.96 -302.32 3200.27 354.58 1.10 MWD_IFR_MS 65 5603.32 33.52 353.93 93.50 4284.05 3204.09 3237.38 -307.94 3252.00 354.57 0.26 MWD_IFR_MS 66 5697.77 33.10 353.69 94.45 4362.98 3255.31 3288.95 -313.54 3303.86 354.55 0.47 MWD_IFR_MS 67 5791.30 33.02 353.75 93.53 4441.37 3305.71 3339.67 -319.12 3354.88 354.54 0.09 MWD_IFR_MS 68 5884.67 32.79 353.51 93.37 4519.76 3355.82 3390.08 -324.75 3405.60 354.53 0.28 MWD_IFR_MS 69 5977.02 32.50 352.97 92.35 4597.52 3405.08 3439.55 -330.61 3455.40 354.51 0.45 MWD_IFR_MS 70 6070.61 33.51 354.16 93.59 4676.01 3455.45 3490.20 -336.31 3506.37 354.50 1.28 MWD_IFR_MS 71 6164.15 33.80 354.91 93.54 4753.87 3506.53 3541.81 -341.25 3558.21 354.50 0.54 MWD_IFR_MS 72 6257.67 34.98 354.74 93.52 4831.04 3558.53 3594.41 -346.02 3611.03 354.50 1.27 MWD_IFR_MS 73 6352.48 35.08 354.70 94.81 4908.68 3612.13 3648.60 -351.02 3665.45 354.50 0.11 MWD_IFR_MS 74 6446.81 34.80 354.23 94.33 4986.00 3665.37 3702.37 -356.23 3719.47 354.50 0.41 MWD_IFR_MS 75 6539.74 34.73 354.47 92.93 5062.35 3717.62 3755.11 -361.45 3772.46 354.50 0.17 MWD_IFR_MS 76 6632.08 34.52 354.80 92.34 5138.33 3769.30 3807.34 -366.36 3824.93 354.50 0.30 MWD_IFR_MS 77 6725.61 33.91 354.17 93.53 5215.67 3821.13 3859.69 -371.41 3877.52 354.50 0.75 MWD_IFR_MS 78 6817.78 33.46 354.04 92.17 5292.37 3871.56 3910.54 -376.66 3928.64 354.50 0.49 MWD_IFR_MS 79 6911.47 32.98 353.64 93.69 5370.75 3922.24 3961.57 -382.17 3979.96 354.49 0.56 MWD_IFR_MS 80 7004.52 32.67 353.21 93.05 5448.94 3972.10 4011.68 -387.94 4030.40 354.48 0.42 MWD_IFR_MS 81 7098.79 32.25 352.72 94.27 5528.48 4022.17 4061.90 -394.14 4080.97 354.46 0.53 MWD _ IFR _MS 82 7192.58 32.13 348.94 93.79 5607.86 4071.83 4111.20 -402.09 4130.82 354.41 2.15 MWD -IFR _MS 83 7284.82 34.86 343.35 92.24 5684.80 4122.67 4160.55 -414.36 4181.13 354.31 4.46 MWD -IFR -MS 84 7379.32 34.49 342.69 94.50 5762.51 4176.41 4211.97 -430.05 4233.87 354.17 0.56 MWD_IFR_MS 85 7472.08 36.50 338.28 92.76 5838.04 4230.08 4262.69 -448.08 4286.17 354.00 3.51 MWD_IFR_MS 86 7565.55 39.52 334.06 93.47 5911.69 4286.96 4315.28 -471.39 4340.95 353.77 4.26 MWD_IFR_MS 87 7658.32 42.03 329.55 92.77 5981.96 4345.96 4368.61 -500.05 4397.14 353.47 4.17 MWD_IFR_MS 88 7751.95 45.04 324.85 93.63 6049.84 4407.40 4422.75 -535.02 4454.99 353.10 4.72 MWD_IFR_MS 89 7844.76 48.63 321.70 92.81 6113.33 4470.36 4476.95 -575.53 4513.79 352.67 4.59 MWD_IFR_MS 90 7937.78 50.20 320.66 93.02 6173.85 4535.12 4531.98 -619.82 4574.17 352.21 1.89 MWD_IFR_MS SCHLUMBERGER Survey Report 11 -May -2005 11:00:50 Page 5 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8032.38 52.52 317.88 94.60 6232.92 4601.81 4587.94 -668.04 4636.32 351.72 3.36 MWD_IFR_MS 92 8125.10 54.22 316.67 92.72 6288.24 4667.83 4642.59 -718.53 4697.87 351.20 2.11 MWD_IFR_MS 93 8217.89 56.34 314.67 92.79 6341.09 4734.49 4697.13 -771.83 4760.12 350.67 2.89 MWD_IFR_MS 94 8312.65 60.18 313.24 94.76 6390.94 4803.71 4753.04 -829.85 4824.94 350.10 4.25 MWD_IFR_MS 95 8404.48 65.07 312.20 91.83 6433.15 4872.84 4808.33 -889.75 4889.96 349.52 5.42 MWD_IFR_MS 96 8487.00 69.96 310.30 82.52 6464.70 4936.40 4858.57 -947.07 4950.01 348.97 6.30 BLIND 97 8499.00 71.54 309.14 12.00 6468.66 4945.68 4865.81 -955.78 4958.79 348.89 16.02 BLIND 98 8513.17 72.15 308.66 14.17 6473.07 4956.60 4874.26 -966.26 4969.11 348.79 5.38 INC_TREND 99 8532.04 74.02 308.04 18.87 6478.56 4971.14 4885.46 -980.42 4982.87 348.65 10.40 INC_TREND 100 8562.88 77.17 307.04 30.84 6486.23 4994.93 4903.66 -1004.10 5005.41 348.43 10.69 INC_TREND 101 8593.93 80.14 306.05 31.05 6492.34 5018.86 4921.78 -1028.56 5028.11 348.20 10.06 INC_TREND 102 8625.17 85.32 305.08 31.24 6496.29 5042.88 4939.80 -1053.76 5050.94 347.96 16.86 INC_TREND 103 8656.32 86.35 304.12 31.15 6498.55 5066.64 4957.44 -1079.33 5073.58 347.72 4.51 INC_TREND 104 8686.60 89.61 303.20 30.28 6499.62 5089.45 4974.21 -1104.51 5095.36 347.48 11.19 MWD_IFR_MS_SAG 105 8718.32 91.50 301.05 31.72 6499.31 5112.80 4991.08 -1131.37 5117.70 347.23 9.02 MWD_IFR_MS_SAG 106 8749.11 92.25 298.69 30.79 6498.31 5134.61 5006.40 -1158.06 5138.60 346.98 8.04 MWD -IFR -MS -SAG 107 8781.02 93.35 295.66 31.91 6496.75 5156.12 5020.96 -1186.40 5159.22 346.71 10.09 MWD_IFR_MS_SAG 108 8809.51 93.59 294.00 28.49 6495.02 5174.44 5032.90 -1212.21 5176.83 346.46 .5.88 MWD_IFR_MS_SAG 109 8841.27 93.42 290.25 31.76 6493.08 5193.70 5044.84 -1241.57 5195.37 346.17 11.80 MWD_IFR_MS_SAG 110 8871.77 93.49 288.47 30.50 6491.24 5211.00 5054.93 -1270.30 5212.10 345.89 5.83 MWD_IFR_MS_SAG 111 8902.63 93.15 284.74 30.86 6489.46 5227.27 5063.73 -1299.81 5227.89 345.60 12.12 MWD_IFR_MS_SAG 112 8934.44 93.28 280.62 31.81 6487.67 5242.16 5070.70 -1330.79 5242.42 345.29 12.94 MWD -IFR -MS -SAG 113 8965.44 92.77 278.17 31.00 6486.03 5255.08 5075.75 -1361.33 5255.14 344.99 8.06 MWD -IFR -MS -SAG 114 8996.74 91.63 274.73 31.30 6484.83 5266.66 5079.27 -1392.41 5266.66 344.67 11.57 MWD_IFR_MS_SAG 115 9026.93 91.77 271.69 30.19 6483.94 5276.23 5080.96 -1422.53 5276.33 344.36 10.08 MWD_IFR_MS_SAG 116 9057.48 92.49 268.61 30.55 6482.80 5284.35 5081.04 -1453.06 5284.72 344.04 10.35 MWD_IFR_MS_SAG 117 9089.10 92.39 265.77 31.62 6481.46 5291.17 5079.49 -1484.61 5292.00 343.71 8.98 MWD_IFR_MS_SAG 118 9121.33 90.37 264.38 32.23 6480.68 5296.96 5076.72 -1516.71 5298.44 343.37 7.61 MWD_IFR_MS_SAG 119 9151.49 90.26 261.24 30.16 6480.51 5301.21 5072.95 -1546.62 5303.47 343.04 10.42 MWD_IFR_MS_SAG 120 9182.65 90.50 257.38 31.16 6480.31 5303.70 5067.17 -1577.24 5306.96 342.71 12.41 MWD_IFR_MS_SAG SCHLUMBERGER Survey Report 11-May-2005 11:00:50 Page 6 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ----- (deg) ------ --- 121 -------- 9213.59 ------ 91.19 ------- 254.27 ------ 30.94 -------- 6479.85 -------- 5304.30 ---------------- 5059.59 -1607.23 --------------- 5308.73 342.38 ----- 10.30 ----- MWD_IFR_MS_SAG ------ 122 9242.27 91.15 253.03 28.68 6479.26 5303.76 5051.52 -1634.74 5309.45 342.07 4.32 MWD_IFR_MS_SAG 123 9274.09 91.26 252.54 31.82 6478.60 5302.69 5042.11 -1665.13 5309.94 341.72 1.58 MWD_IFR_MS_SAG 124 9304.27 91.53 253.02 30.18 6477.86 5301.67 5033.17 -1693.95 5310.58 341.40 1.82 MWD_IFR_MS_SAG 125 9335.48 91.26 253.08 31.21 6477.10 5300.76 5024.08 -1723.79 5311.57 341.06 0.89 MWD_IFR_MS_SAG 126 9366.40 90.88 253.70 30.92 6476.52 5300.04 5015.24 -1753.42 5312.92 340.73 2.35 MWD_IFR_MS_SAG 127 9397.46 90.50 253.01 31.06 6476.15 5299.30 5006.34 -1783.17 5314.43 340.40 2.54 MWD_IFR_MS_SAG 128 9428.26 90.47 252.85 30.80 6475.89 5298.34 4997.30 -1812.62 5315.88 340.06 0.53 MWD_IFR_MS_SAG 129 9459.70 90.85 252.87 31.44 6475.53 5297.32 4988.04 -1842.66 5317.51 339.73 1.21 MWD_IFR_MS_SAG 130 9491.71 90.95 253.35 32.01 6475.02 5296.42 4978.74 -1873.28 5319.50 339.38 1.53 MWD-IFR-MS-SAG 131 9522.49 91.36 253.51 30.78 6474.40 5295.72 4969.96 -1902.78 5321.76 339.05 1.43 MWD_IFR_MS_SAG 132 9553.50 91.40 254.33 31.01 6473.66 5295.29 4961.38 -1932.57 5324.48 338.72 2.65 MWD_IFR_MS_SAG 133 9584.79 91.84 254.51 31.29 6472.77 5295.13 4952.98 -1962.69 5327.68 338.38 1.52 MWD_IFR_MS_SAG 134 9616.02 91.98 255.06 31.23 6471.73 5295.16 4944.79 -1992.81 5331.25 338.05 1.82 MWD_IFR_MS_SAG 135 9647.18 92.12 255.50 31.16 6470.61 5295.47 4936.87 -2022.93 5335.26 337.72 1.48 MWD-IFR-MS-SAG 136 9678.27 92.08 255.39 31.09 6469.48 5295.86 4929.06 -2053.00 5339.52 337.39 0.38 MWD_IFR_MS_SAG 137 9709.31 92.05 255.45 31.04 6468.36 5296.24 4921.26 -2083.02 5343.95 337.06 0.22 MWD_IFR_MS_SAG 138 9740.96 91.50 254.43 31.65 6467.38 5296.36 4913.04 -2113.57 5348.38 336.72 3.66 MWD_IFR_MS_SAG 139 9772.58 91.22 253.56 31.62 6466.63 5295.96 4904.32 -2143.96 5352.47 336.39 2.89 MWD_IFR_MS_SAG 140 9802.94 88.48 255.77 30.36 6466.71 5295.93 4896.29 -2173.23 5356.92 336.07 11.59 MWD_IFR_MS_SAG 141 9834.33 88.17 256.17 31.39 6467.62 5296.62 4888.69 -2203.67 5362.41 335.74 1.61 MWD_IFR_MS_SAG 142 9865.67 88.21 256.87 31.34 6468.61 5297.60 4881.38 -2234.13 5368.36 335.41 2.24 MWD IFR_MS_SAG 143 9896.80 88.89 256.90 31.13 6469.40 5298.78 4874.32 -2264.44 5374.64 335.08 2.19 MWD-IFR-MS-SAG 144 9928.12 89.06 257.69 31.32 6469.96 5300.18 4867.44 -2294.99 5381.35 334.76 2.58 MWD_IFR_MS_SAG 145 9959.64 89.23 257.18 31.52 6470.43 5301.68 4860.58 -2325.75 5388.35 334.43 1.71 D MW~IFR MS SAG 146 9990.50 89.10 257.77 30.86 6470.88 5303.16 4853.89 -2355.87 5395.40 334.11 1.96 MWD-IFR-MS SAG 147 10021.58 89.24 257.85 31.08 6471.33 5304.84 4847.33 -2386.25 5402.85 333.79 0.52 MWD_IFR_MS_-SAG 148 10052.72 88.82 260.07 31.14 6471.86 5307.14 4841.36 -2416.81 5411.08 333.47 7.25 MWD_IFR_MS_SAG 149 10084.19 89.82 260.61 31.47 6472.23 5310.22 4836.08 -2447.83 5420.29 333.15 3.61 MWD_IFR_MS_SAG 150 10116.27 91.26 260.71 32.08 6471.93 5313.54 4830.88 -2479.48 5430.03 332.83 4.50 MWD IFR MS SAG SCHLUMBERGER Survey Report 11 -May -2005 11:00:50 Page 7 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ------ ----- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ----- (deg) ------ --- 151 -------- 10146.13 ------ 91.60 ------- 260.68 ------ 29.86 -------- 6471.18 -------- 5316.65 ---------------- 4826.05 -2508.94 --------------- 5439.26 332.53 ----- 1.14 ----- MWD_IFR_MS_SAG ------ 152 10177.60 92.49 261.29 31.47 6470.06 5320.08 4821.12 -2540.00 5449.30 332.22 3.43 MWD_IFR_MS_SAG -MS -SAG 153 10209.22 92.53 261.52 31.62 6468.68 5323.75 4816.40 -2571.23 5459.76 331.90 0.74 MWD -IFR -MS -SAG 154 10240.11 91.73 261.58 30.89 6467.53 5327.43 4811.87 -2601.77 5470.22 331.60 2.60 MWD_IFR_MS_SAG 155 10270.43 89.68 264.01 30.32 6467.16 5331.68 4808.06 -2631.84 5481.25 331.30 10.49 MWD -IFR -MS -SAG 156 10301.81 157 10332.86 158 10364.16 159 10395.82 160 10426.38 161 10457.06 162 10488.58 163 10518.95 164 10549.84 165 10581.57 166 10610.83 167 10643.14 168 10674.13 169 10705.21 170 10720.69 171 10774.00 87.52 263.18 31.38 6467.92 5336.52 4804.57 -2663.01 5493.22 331.00 7.37 MWD_IFR_MS_SAG 87.52 263.25 31.05 6469.27 5341.11 4800.90 -2693.82 5505.03 330.70 0.23 MWD_IFR_MS_SAG 89.06 265.25 31.30 6470.20 5346.29 4797.77 -2724.94 5517.60 330.41 8.06 MWD_IFR_MS_SAG 90.19 266.90 31.66 6470.41 5352.52 4795.60 -2756.53 5531.39 330.11 6.32 MWD_IFR_MS_SAG 89.75 268.36 30.56 6470.42 5359.35 4794.34 -2787.06 5545.57 329.83 4.99 MWD -IFR -MS -SAG 89.34 269.92 30.68 6470.67 5366.99 4793.88 -2817.73 5560.65 329.55 5.26 MWD_IFR_MS_SAG 88.58 269.86 31.52 6471.24 5375.23 4793.82 -2849.25 5576.64 329.27 2.42 MWD_IFR_MS_SAG 87.90 270.82 30.37 6472.17 5383.41 4794.00 -2879.60 5592.36 329.01 3.87 MWD_IFR_MS_SAG 85.08 270.05 30.89 6474.06 5391.76 4794.23 -2910.43 5608.50 328.74 9.46 MWD_IFR_MS_SAG 84.53 269.04 31.73 6476.94 5399.84 4793.98 -2942.03 5624.75 328.46 3.61 MWD -IFR -MS -SAG 85.91 268.03 29.26 6479.37 5406.80 4793.23 -2971.18 5639.41 328.21 5.84 MWD_IFR_MS_SAG 88.99 266.73 32.31 6480.81 5413.88 4791.76 -3003.42 5655.21 327.92 10.35 MWD -IFR -MS -SAG 90.13 266.09 30.99 6481.05 5420.16 4789.82 -3034.34 5670.06 327.65 4.22 MWD_IFR_MS_SAG 88.41 266.11 31.08 6481.44 5426.29 4787.70 -3065.35 5684.93 327.37 5.53 MWD_IFR_MS_SAG 87.28 263.85 15.48 6482.03 5429.04 4786.35 -3080.76 5692.12 327.23 16.31 MWD -IFR -MS -SAG 87.28 263.85 [(c)2005 IDEAL ID9_1C_01.41 53.31 6484.56 5437.49 4780.65 -3133.70 5716.17 326.76 0.00 Projection to TD* SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) INc. Field ..................... Borealis Well ...................... L-124PB1 API number ...............: 50-029-23255-70 Engineer .................. St. Amour RIG: ..................... NABORS 9ES STATE :.................... Alaska ----- Survey calculation methods ------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference -----------------------. Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 44.10 ft KB above permanent.......: N/A (Topdrive) DF above permanent.......: 72.60 ft ----- Vertical section origin ---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)......... 0.00 ft ----- Platform reference point --------------- Latitude (+N/S-).......... -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 344.72 degrees 3 -May -2005 23:15:19 Page 1 of 5 Spud date ................. 26 -April -2005 Last survey date.........: 03 -May -05 Total accepted surveys...: 103 MD of first survey.......: 0.00 ft MD of last survey........: 9106.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............. 26 -Apr -2005 Magnetic field strength..: 1152.21 HCNT Magnetic dec (+E/W-).....: 24.49 degrees Magnetic dip .............. 80.81 degrees ----- MWD survey Reference Criteria --------- Reference G ............... 1002.68 mGal Reference H ............... 1152.21 HCNT Reference Dip........ ... 80.81 degrees Tolerance of G............ (+/-) 2.50 mGal Tolerance of H............ (+/-) 6.00 HCNT Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)..... : 24.49 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.49 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCHLUMBERGER Survey Report 3 -May -2005 23:15:19 Page 2 of 5 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 -------- 0.00 -------- 0.00 ---------------- 0.00 0.00 --------------- 0.00 0.00 ----- 0.00 ----- TIP ------ None 2 100.00 0.20 271.64 100.00 100.00 0.05 0.00 -.0.17 0.17 271.64 0.20 GYRO None 3 200.00 0.33 49.75 100.00 200.00 0.22 0.20 -0.13 0.23 326.63 0.50 GYRO None 4 300.00 1.82 21.25 100.00 299.98 1.62 1.86 0.67 1.98 19.69 1.54 GYRO None 5 400.00 2.70 5.81 100.00 399.90 5.09 5.69 1.48 5.88 14.59 1.06 GYRO None 6 500.00 3.78 359.68 100.00 499.74 10.48 11.33 1.70 11.45 8.54 1.13 GYRO None • 7 600.00 5.59 349.43 100.00 599.40 18.52 19.41 0.79 19.43 2.33 1.99 GYRO None 8 700.00 7.64 345.53 100.00 698.73 30.02 30.64 -1.77 30.69 356.70 2.10 GYRO None 9 800.00 10.20 343.51 100.00 797.52 45.52 45.56 -5.94 45.95 352.57 2.58 GYRO None 10 850.00 10.96 342.90 50.00 846.67 54.70 54.35 -8.60 55.03 351.01 1.54 GYRO None 11 900.00 13.75 343.59 50.00 895.50 65.39 64.60 -11.67 65.64 349.76 5.59 GYRO None 12 950.00 14.85 343.00 50.00 943.95 77.74 76.43 -15.22 77.93 348.73 2.22 GYRO None 13 1000.00 17.34 344.83 50.00 991.99 91.59 89.75 -19.05 91.75 348.02 5.08 GYRO None 14 1050.00 19.56 344.20 50.00 1039.42 107.42 104.99 -23.28 107.54 347.50 4.46 GYRO None 15 1100.00 20.97 344.73 50.00 1086.32 124.73 121.68 -27.91 124.84 347.08 2.84 GYRO None 16 1150.00 23.54 345.82 50.00 1132.59 143.67 139.99 -32.72 143.77 346.85 5.21 GYRO None 17 1189.00 24.93 345.83 39.00 1168.15 159.67 155.51 -36.64 159.77. 346.74 3.56 GYRO None 18 1223.53 26.97 347.57 34.53 1199.20 174.77 170.22 -40.10 174.88 346.74 6.31 MWD_IFR_MS 19 1318.56 30.12 350.35 95.03 1282.67 220.04 214.78 -48.74 220.24 347.21 3.60 MWD_IFR_MS 20 1411.57 33.23 353.54 93.01 1361.82 268.46 263.13 -55.52 268.92 348.08 3.80 MWD_IFR_MS 21 1503.89 37.07 353.91 92.32 1437.30 320.94 315.95 -61.32 321.85 349.02 4.17 MWD_IFR_MS 22 1597.02 42.40 353.85 93.13 1508.89 379.69 375.12 -67.67 381.18 349.77 5.72 MWD_IFR_MS 23 1691.41 48.99 356.15 94.39 1574.78 446.10 442.37 -73.48 448.43 350.57 7.20 MWD_IFR_MS 24 1782.67 50.23 356.39 91.26 1633.92 514.20 511.73 -78.00 517.64 351.33 1.37 MWD_IFR_MS 25 1876.53 48.39 355.33 93.86 1695.11 584.02 582.71 -83.13 588.61 351.88 2.14 MWD -IFR -MS 26 1971.48 48.87 354.60 94.95 1757.87 654.14 653.69 -89.38 659.77 352.21 0.77 MWD IFR_MS 27 2063.32 48.71 352.62 91.84 1818.38 722.39 722.35 -97.07 728.84 352.35 1.63 MWD -IFR -MS 28 2156.39 47.68 352.60 93.07 1880.41 791.11 791.15 -105.99 798.22 352.37 1.11 MWD_IFR_MS 29 2250.51 47.61 353.04 94.12 1943.83 859.97 860.15 -114.68 867.77 352.41 0.35 MWD IFR_MS 30 2344.98 48.30 353.62 94.47 2007.09 929.33 929.83 -122.83 937.91 352.47 0.86 MWD^IFR MS SCHLUMBERGER Survey Report 3 -May -2005 23:15:19 Page 3 of 5 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ----- (deg) ------ --- 31 -------- 2439.32 ------ 47.74 ------- 353.37 ------ 94.34 -------- 2070.19 -------- 998.64 ---------------- 999.51 -130.78 --------------- 1008.03 352.55 ----- 0.63 ----- MWD_IFR_MS ------ 32 2531.44 47.60 354.75 92.12 2132.23 1065.84 1067.25 -137.82 1076.11 352.64 1.12 MWD_IFR_MS 33 2625.95 48.38 355.43 94.51 2195.48 1134.91 1137.21 -143.83 1146.27 352.79 0.98 MWD_IFR_MS 34 2718.09 48.26 354.82 92.14 2256.75 1202.60 1205.78 -149.68 1215.03 352.92 0.51 MWD_IFR_MS 35 2810.94 48.26 354.39 92.85 2318.57 1270.85 1274.75 -156.19 1284.29 353.01 0.35 MWD -IFR -MS 36 2905.05 47.71 353.70 94.11 2381.56 1339.85 1344.30 -163.45 1354.20 353.07 0.80 MWD_IFR_MS • 37 2997.88 47.32 354.34 92.83 2444.25 1407.41 1412.38 -170.58 1422.64 353.11 0.66 MWD_IFR_MS 38 3092.44 46.68 353.91 94.56 2508.74 1475.63 1481.17 -177.66 1491.79 353.16 0.75 MWD -IFR -MS 39 3184.34 46.34 353.95 91.90 2571.99 1541.44 1547.47 -184.71 1558.46 353.19 0.37 MWD_IFR_MS 40 3267.71 45.04 355.35 83.37 2630.23 1600.21 1606.86 -190.28 1618.09 353.25 1.97 MWD -IFR -MS 41 3361.06 46.28 354.23 93.35 2695.47 1665.94 1673.35 -196.35 1684.83 353.31 1.58 MWD_IFR_MS 42 3454.83 47.62 356.46 93.77 2759.49 1733.28 1741.64 -201.89 1753.30 353.39 2.25 MWD_IFR_MS 43 3546.94 48.34 355.61 92.11 2821.15 1800.37 1809.90 -206.63 1821.66 353.49 1.04 MWD_IFR_MS 44 3640.51 48.21 356.83 93.57 2883.42 1868.81 1879.58 -211.23 1891.41 353.59 0.98 MWD_IFR_MS 45 3733.20 47.78 356.40 92.69 2945.45 1936.20 1948.34 -215.30 1960.20 353.69 0.58 MWD_IFR_MS 46 3827.42 48.44 355.24 94.22 3008.36 2005.03 2018.29 -220.41 2030.29 353.77 1.15 MWD_IFR_MS 47 3920.43 47.88 355.58 93.01 3070.40 2073.12 2087.36 -225.96 2099.55 353.82 0.66 MWD_IFR_MS 48 4013.97 46.74 356.18 93.54 3133.83 2140.57 2155.94 -230.90 2168.26 353.89 1.31 MWD_IFR_MS 49 4107.15 47.04 356.63 93.18 3197.51 2207.19 2223.83 -235.17 2236.23 353.96 0.48 MWD_IFR_MS 50 4205.93 48.71 357.37 98.78 3263.76 2278.77 2296.99 -238.99 2309.39 354.06 1.78 MWD_IFR_MS 51 4299.33 48.21 358.47 93.40 3325.70 2346.83 2366.85 -241.53 2379.14 354.17 1.03 MWD_IFR_MS i 52 4393.07 47.70 358.91 93.74 3388.48 2414.38 2436.44 -243.13 2448.54 354.30 0.65 MWD_IFR_MS 53 4485.81 47.23 359.69 92.74 3451.18 2480.52 2504.77 -243.96 2516.63 354.44 0.80 MWD_IFR_MS 54 4579.05 47.97 358.02 93.24 3514.05 2547.29 2573.61 -245.34 2585.27 354.55 1.54 MWD_IFR_MS 55 4671.46 48.52 358.29 92.41 3575.59 2614.34 2642.51 -247.56 2654.08 354.65 0.63 MWD -IFR -MS 56 4765.16 47.65 357.81 93.70 3638.18 2682.18 2712.19 -249.93 2723.68 354.73 1.00 MWD_IFR_MS 57 4859.58 46.89 356.33 94.42 3702.25 2749.93 2781.46 -253.47 2792.98 354.79 1.40 MWD_IFR_MS 58 4951.15 45.59 354.65 91.57 3765.59 2814.89 2847.38 -258.66 2859.11 354.81 1.94 MWD -IFR -MS 59 5043.16 42.99 353.84 92.01 3831.44 2878.25 2911.30 -265.09 2923.35 354.80 2.89 MWD_IFR_MS 60 5136.17 39.23 352.25 93.01 3901.51 2938.74 2972.00 -272.47 2984.46 354.76 4.20 MWD_IFR_MS SCHLUMBERGER Survey Report 3 -May -2005 23:15:19 Page 4 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5229.31 36.72 351.91 93.14 3974.93 2995.57 3028.76 -280.36 3041.70 354.71 2.70 MWD -IFR -MS 62 5322.70 34.28 351.59 93.39 4050.95 3049.39 3082.42 -288.13 3095.86 354.66 2.62 MWD_IFR_MS 63 5416.91 33.93 351.82 94.21 4128.96 3101.82 3134.69 -295.76 3148.62 354.61 0.40 MWD_IFR_MS 64 5509.82 33.67 353.60 92.91 4206.17 3153.00 3185.96 -302.32 3200.27 354.58 1.10 MWD_IFR_MS 65 5603.32 33.52 353.93 93.50 4284.05 3204.09 3237.38 -307.94 3252.00 354.57 0.26 MWD -IFR -MS 66 5697.77 33.10 353.69 94.45 4362.98 3255.31 3288.95 -313.54 3303.86 354.55 0.47 MWD_IFR_MS 67 5791.30 33.02 353.75 93.53 4441.37 3305.71 3339.67 -319.12 3354.88 354.54 0.09 MWD_IFR_MS 68 5884.67 32.79 353.51 93.37 4519.76 3355.82 3390.08 -324.75 3405.60 354.53 0.28 MWD_IFR_MS 69 5977.02 32.50 352.97 92.35 4597.52 3405.08 3439.55 -330.61 3455.40 354.51 0.45 MWD_IFR_MS 70 6070.61 33.51 354.16 93.59 4676.01 3455.45 3490.20 -336.31 3506.37 354.50 1.28 MWD -IFR -MS 71 6164.15 33.80 354.91 93.54 4753.87 3506.53 3541.81 -341.25 3558.21 354.50 0.54 MWD -IFR -MS 72 6257.67 34.98 354.74 93.52 4831.04 3558.53 3594.41 -346.02 3611.03 354.50 1.27 MWD_IFR_MS 73 6352.48 35.08 354.70 94.81 4908.68 3612.13 3648.60 -351.02 3665.45 354.50 0.11 MWD_IFR_MS 74 6446.81 34.80 354.23 94.33 4986.00 3665.37 3702.37 -356.23 3719.47 354.50 0.41 MWD -IFR -MS 75 6539.74 34.73 354.47 92.93 5062.35 3717.62 3755.11 -361.45 3772.46 354.50 0.17 MWD -IFR -MS 76 6632.08 34.52 354.80 92.34 5138.33 3769.30 3807.34 -366.36 3824.93 354.50 0.30 MWD_IFR_MS 77 6725.61 33.91 354.17 93.53 5215.67 3821.13 3859.69 -371.41 3877.52 354.50 0.75 MWD_IFR_MS 78 6817.78 33.46 354.04 92.17 5292.37 3871.56 3910.54 -376.66 3928.64 354.50 0.49 MWD_IFR_MS 79 6911.47 32.98 353.64 93.69 5370.75 3922.24 3961.57 -382.17 3979.96 354.49 0.56 MWD_IFR_MS 80 7004.52 32.67 353.21 93.05 5448.94 3972.10 4011.68 -387.94 4030.40 354.48 0.42 MWD -IFR -MS 81 7098.79 32.25 352.72 94.27 5528.48 4022.17 4061.90 -394.14 4080.97 354.46 0.53 MWD_IFR_MS 82 7192.58 32.13 348.94 93.79 5607.86 4071.83 4111.20 -402.09 4130.82 354.41 2.15 MWD IFR_MS 83 7284.82 34.86 343.35 92.24 5684.80 4122.67 4160.55 -414.36 4181.13 354.31 4.46 MWD -IFR -MS 84 7379.32 34.49 342.69 94.50 5762.51 4176.41 4211.97 -430.05 4233.87 354.17 0.56 MWD_IFR_MS 85 7472.08 36.50 338.28 92.76 5838.04 4230.08 4262.69 -448.08 4286.17 354.00 3.51 MWD -IFR -MS 86 7565.55 39.52 334.06 93.47 5911.69 4286.96 4315.28 -471.39 4340.95 353.77 4.26 MWD_IFR_MS 87 7658.32 42.03 329.55 92.77 5981.96 4345.96 4368.61 -500.05 4397.14 353.47 4.17 MWD_IFR_MS 88 7751.95 45.04 324.85 93.63 6049.84 4407.40 4422.75 -535.02 4454.99 353.10 4.72 MWD_IFR_MS 89 7844.76 48.63 321.70 92.81 6113.33 4470.36 4476.95 -575.53 4513.79 352.67 4.59 MWD -IFR -MS 90 7937.78 50.20 320.66 93.02 6173.85 4535.12 4531.98 -619.82 4574.17 352.21 1.89 MWD -IFR -MS s SCHLUMBERGER Survey Report 3 -May -2005 23:15:19 Page 5 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8032.38 52.52 317.88 94.60 6232.92 4601.81 4587.94 -668.04 4636.32 351.72 3.36 MWD_IFR_MS 92 8125.10 54.22 316.67 92.72 6288.24 4667.83 4642.59 -718.53 4697.87 351.20 2.11 MWD_IFR_MS 93 8217.89 56.34 314.67 92.79 6341.09 4734.49 4697.13 -771.83 4760.12 350.67 2.89 MWD_IFR_MS 94 8312.65 60.18 313.24 94.76 6390.94 4803.71 4753.04 -829.85 4824.94 350.10 4.25 MWD_IFR_MS 95 8404.48 65.07 312.20 91.83 6433.15 4872.84 4808.33 -889.75 4889.96 349.52 5.42 MWD_IFR_MS 96 8499.19 70.69 310.03 94.71 6468.80 49 84 4958.96 348.89 6.30 MWD_IFR_MS • 97 8592.14 73.18 309.03 92.95 6497.62 5018.07 4922.21 -1023.99 5027.59 348.25 2.87 MWD_IFR_MS 98 8685.01 73.22 309.28 92.87 6524.46 5090.39 4978.35 -1092.94 5096.90 347.62 0.26 MWD_IFR_MS 99 8779.47 72.86 309.11 94.46 6552.02 5163.92 5035.44 -1162.96 5168.00 347.00 0.42 MWD_IFR_MS 100 8870.97 72.33 308.84 91.50 6579.39 5234.78 5090.36 -1230.83 5237.05 346.41 0.64 MWD_IFR_MS 101 8964.75 72.39 308.44 93.78 6607.81 5307.01 5146.17 -1300.64 5307.98 345.82 0.41 MWD_IFR_MS 102 9036.70 72.63 308.50 71.95 6629.43 5362.35 5188.86 -1354.37 5362.70 345.37 0.34 MWD_IFR_MS 103 9106.00 72.63 308.50 69.30 6650.12 5415.71 5230.03 -1406.13 5415.76 344.95 0.00 Projected to TD [(c)2005 IDEAL ID9_1C_01.41 SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Borealis Well ...................... L-124PB2 API number ...............: 50-029-23255-71 Engineer .................. F. Medina Rig: ..................... Nabors 9ES STATE: ................... Alaska ----- Survey calculation methods ------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 48.40 ft KB above permanent.......: N/A Top Drive DF above permanent.......: 76.80 ft ----- Vertical section origin ---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point --------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)......... -999.25 ft Azimuth from Vsect Origin to target: 344.72 degrees O V,I W 10 -May -2005 16:16:44 Page 1 of 7 Spud date ................. 26 -Apr -05 Last survey date.........: 10 -May -05 Total accepted surveys...: 166 MD of first survey.......: 0.00 ft MD of last survey........: 10615.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 05 -May -2005 Magnetic field strength..: 1152.22 HCNT Magnetic dec (+E/W-).....: 24.48 degrees Magnetic dip .............: 80.81 degrees ----- MWD survey Reference Criteria --------- Reference G ..............: 1002.68 mGal Reference H ............... 1152.22 HCNT Reference Dip ............: 80.81 degrees Tolerance of G...........: (+/-) 2.50 mGal Tolerance of H............ (+/-) 6.00 HCNT Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)..... : 24.48 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corn (+E/W-)....: 24.48 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • [(c)2005 IDEAL ID9_1C_01.41 SCHLUMBERGER Survey Report 10 -May -2005 16:16:44 Page 2 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ----- (deg) ------ --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 -------- 0.00 -------- 0.00 ---------------- 0.00 0.00 --------------- 0.00 0.00 ----- 0.00 ----- TIP ------ None 2 100.00 0.20 271.64 100.00 100.00 0.05 0.00 -0.17 0.17 271.64 0.20 GYRO None 3 200.00 0.33 49.75 100.00 200.00 0.22 0.20 -0.13 0.23 326.63 0.50 GYRO None 4 300.00 1.82 21.25 100.00 299.98 1.62 1.86 0.67 1.98 19.69 1.54 GYRO None 5 400.00 2.70 5.81 100.00 399.90 5.09 5.69 1.48 5.88 14.59 1.06 GYRO None 6 500.00 3.78 359.68 100.00 499.74 10.48 11.33 1.70 11.45 8.54 1.13 GYRO None 7 600.00 5.59 349.43 100.00 599.40 18.52 19.41 0.79 19.43 2.33 1.99 GYRO None 8 700.00 7.64 345.53 100.00 698.73 30.02 30.64 -1.77 30.69 356.70 2.10 GYRO None 9 800.00 10.20 343.51 100.00 797.52 45.52 45.56 -5.94 45.95 352.57 2.58 GYRO None 10 850.00 10.96 342.90 50.00 846.67 54.70 54.35 -8.60 55.03 351.01 1.54 GYRO None 11 900.00 13.75 343.59 50.00 895.50 65.39 64.60 -11.67 65.64 349.76 5.59 GYRO None 12 950.00 14.85 343.00 50.00 943.95 77.74 76.43 -15.22 77.93 348.73 2.22 GYRO None 13 1000.00 17.34 344.83 50.00 991.99 91.59 89.75 -19.05 91.75 348.02 5.08 GYRO None 14 1050.00 19.56 344.20 50.00 1039.42 107.42 104.99 -23.28 107.54 347.50 4.46 GYRO None 15 1100.00 20.97 344.73 50.00 1086.32 124.73 121.68 -27.91 124.84 347.08 2.84 GYRO None 16 1150.00 23.54 345.82 50.00 1132.59 143.67 139.99 -32.72 143.77 346.85 5.21 GYRO None 17 1189.00 24.93 345.83 39.00 1168.15 159.67 155.51 -36.64 159.77 346.74 3.56 GYRO None 18 1223.53 26.97 347.57 34.53 1199.20 174.77 170.22 -40.10 174.88 346.74 6.31 MWD -IFR -MS 19 1318.56 30.12 350.35 95.03 1282.67 220.04 214.78 -48.74 220.24 347.21 3.60 MWD_IFR_MS 20 1411.57 33.23 353.54 93.01 1361.82 268.46 263.13 -55.52 268.92 348.08 3.80 MWD_IFR_MS 21 1503.89 37.07 353.91 92.32 1437.30 320.94 315.95 -61.32 321.85 349.02 4.17 MWD 22 1597.02 42.40 353.85 93.13 1508.89 379.69 375.12 -67.67 381.18 349.77 5.72 -IFR MWD_IFR_MS -MS 23 1691.41 48.99 356.15 94.39 1574.78 446.10 442.37 -73.48 448.43 350.57 7.20 MWD_IFR_MS 24 1782.67 50.23 356.39 91.26 1633.92 514.20 511.73 -78.00 517.64 351.33 1.37 MWD_IFR_MS 25 1876.53 48.39 355.33 93.86 1695.11 584.02 582.71 -83.13 588.61 351.88 2.14 MWD_IFR_MS 26 1971.48 48.87 354.60 94.95 1757.87 654.14 653.69 -89.38 659.77 352.21 0.77 MWD_IFR_MS 27 2063.32 48.71 352.62 91.84 1818.38 722.39 722.35 -97.07 728.84 352.35 1.63 MWD_IFR_MS 28 2156.39 47.68 352.60 93.07 1880.41 791.11 791.15 -105.99 798.22 352.37 1.11 MWD_IFR_MS 29 2250.51 47.61 353.04 94.12 1943.83 859.97 860.15 -114.68 867.77 352.41 0.35 MWD_IFR_MS 30 2344.98 48.30 353.62 94.47 2007.09 929.33 929.83 -122.83 937.91 352.47 0.86 MWD_IFR_MS [(c)2005 IDEAL ID9_1C_01.41 SCHLUMBERGER Survey Report 10 -May -2005 16:16:44 Page 3 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ----- (deg) ------ --- 31 -------- 2439.32 ------ 47.74 ------- 353.37 ------ 94.34 -------- 2070.19 -------- 998.64 ---------------- 999.51 -130.78 --------------- 1008.03 352.55 ----- 0.63 ----- MWD_IFR_MS ------ 32 2531.44 47.60 354.75 92.12 2132.23 1065.84 1067.25 -137.82 1076.11 352.64 1.12 MWD_IFR_MS 33 2625.95 48.38 355.43 94.51 2195.48 1134.91 1137.21 -143.83 1146.27 352.79 0.98 MWD -IFR -MS 34 2718.09 48.26 354.82 92.14 2256.75 1202.60 1205.78 -149.68 1215.03 352.92 0.51 MWD_IFR_MS 35 2810.94 48.26 354.39 92.85 2318.57 1270.85 1274.75 -156.19 1284.29 353.01 0.35 MWD -IFR -MS 36 2905.05 47.71 353.70 94.11 2381.56 1339.85 1344.30 -163.45 1354.20 353.07 0.80 MWD_IFR_MS 37 2997.88 47.32 354.34 92.83 2444.25 1407.41 1412.38 -170.58 1422.64 353.11 0.66 MWD_IFR_MS 38 3092.44 46.68 353.91 94.56 2508.74 1475.63 1481.17 -177.66 1491.79 353.16 0.75 MWD IFR_MS 39 3184.34 46.34 353.95 91.90 2571.99 1541.44 1547.47 -184.71 1558.46 353.19 0.37 MWD -IFR -MS 40 3267.71 45.04 355.35 83.37 2630.23 1600.21 1606.86 -190.28 1618.09 353.25 1.97 MWD -IFR -MS 41 3361.06 46.28 354.23 93.35 2695.47 1665.94 1673.35 -196.35 1684.83 353.31 1.58 MWD IFR_MS 42 3454.83 47.62 356.46 93.77 2759.49 1733.28 1741.64 -201.89 1753.30 353.39 2.25 MWD -IFR -MS 43 3546.94 48.34 355.61 92.11 2821.15 1800.37 1809.90 -206.63 1821.66 353.49 1.04 MWD_IFR_MS 44 3640.51 48.21 356.83 93.57 2883.42 1868.81 1879.58 -211.23 1891.41 353.59 0.98 MWD IFR_MS 45 3733.20 47.78 356.40 92.69 2945.45 1936.20 1948.34 -215.30 1960.20 353.69 0.58 MWD -IFR -MS 46 3827.42 48.44 355.24 94.22 3008.36 2005.03 2018.29 -220.41 2030.29 353.77 1.15 MWD_IFR_MS 47 3920.43 47.88 355.58 93.01 3070.40 2073.12 2087.36 -225.96 2099.55 353.82 0.66 MWD IFR_MS 48 4013.97 46.74 356.18 93.54 3133.83 2140.57 2155.94 -230.90 2168.26 353.89 1.31 MWD -IFR -MS 49 4107.15 47.04 356.63 93.18 3197.51 2207.19 2223.83 -235.17 2236.23 353.96 0.48 MWD_IFR_MS 50 4205.93 48.71 357.37 98.78 3263.76 2278.77 2296.99 -238.99 2309.39 354.06 1.78 MWD -IFR -MS 51 4299.33 48.21 358.47 93.40 3325.70 2346.83 2366.85 -241.53 2379.14 354.17 1.03 MWD _IFR _MS • 52 4393.07 47.70 358.91 93.74 3388.48 2414.38 2436.44 -243.13 2448.54 354.30 0.65 MWD IFR MS 53 4485.81 47.23 359.69 92.74 3451.18 2480.52 2504.77 -243.96 2516.63 354.44 0.80 MWD IFR MS 54 4579.05 47.97 358.02 93.24 3514.05 2547.29 2573.61 -245.34 2585.27 354.55 1.54 MWD -IFR _MS 55 4671.46 48.52 358.29 92.41 3575.59 2614.34 2642.51 -247.56 2654.08 354.65 0.63 MWD -IFR -MS 56 4765.16 47.65 357.81 93.70 3638.18 2682.18 2712.19 -249.93 2723.68 354.73 1.00 MWD_IFR_MS 57 4859.58 46.89 356.33 94.42 3702.25 2749.93 2781.46 -253.47 2792.98 354.79 1.40 MWD -IFR -MS 58 4951.15 45.59 354.65 91.57 3765.59 2814.89 2847.38 -258.66 2859.11 354.81 1.94 MWD_IFR_MS 59 5043.16 42.99 353.84 92.01 3831.44 2878.25 2911.30 -265.09 2923.35 354.80 2.89 MWD_IFR_MS 60 5136.17 39.23 352.25 93.01 3901.51 2938.74 2972.00 -272.47 2984.46 354.76 4.20 MWD -IFR -MS [(c)2005 IDEAL ID9_1C_01.41 SCHLUMBERGER Survey Report 10 -May -2005 16:16:44 Page 4 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ----- (deg) ------ --- 61 -------- 5229.31 ------ 36.72 ------- 351.91 ------ 93.14 -------- 3974.93 -------- 2995.57 ---------------- 3028.76 -280.36 --------------- 3041.70 354.71 ----- 2.70 ----- MWD -IFR ------ -MS 62 5322.70 34.28 351.59 93.39 4050.95 3049.39 3082.42 -288.13 3095.86 354.66 2.62 MWD -IFR -MS 63 5416.91 33.93 351.82 94.21 4128.96 3101.82 3134.69 -295.76 3148.62 354.61 0.40 MWD_IFR_MS 64 5509.82 33.67 353.60 92.91 4206.17 3153.00 3185.96 -302.32 3200.27 354.58 1.10 MWD_IFR_MS 65 5603.32 33.52 353.93 93.50 4284.05 3204.09 3237.38 -307.94 3252.00 354.57 0.26 MWD -IFR -MS 66 5697.77 33.10 353.69 94.45 4362.98 3255.31 3288.95 -313.54 3303.86 354.55 0.47 MWD_IFR_MS 67 5791.30 33.02 353.75 93.53 4441.37 3305.71 3339.67 -319.12 3354.88 354.54 0.09 MWD_IFR_MS 68 5884.67 32.79 353.51 93.37 4519.76 3355.82 3390.08 -324.75 3405.60 354.53 0.28 MWD_IFR_MS 69 5977.02 32.50 352.97 92.35 4597.52 3405.08 3439.55 -330.61 3455.40 354.51 0.45 MWD_IFR_MS 70 6070.61 33.51 354.16 93.59 4676.01 3455.45 3490.20 -336.31 3506.37 354.50 1.28 MWD -IFR -MS 71 6164.15 33.80 354.91 93.54 4753.87 3506.53 3541.81 -341.25 3558.21 354.50 0.54 MWD_IFR_MS 72 6257.67 34.98 354.74 93.52 4831.04 3558.53 3594.41 -346.02 3611.03 354.50 1.27 MWD -IFR -MS 73 6352.48 35.08 354.70 94.81 4908.68 3612.13 3648.60 -351.02 3665.45 354.50 0.11 MWD_IFR_MS 74 6446.81 34.80 354.23 94.33 4986.00 3665.37 3702.37 -356.23 3719.47 354.50 0.41 MWD_IFR_MS 75 6539.74 34.73 354.47 92.93 5062.35 3717.62 3755.11 -361.45 3772.46 354.50 0.17 MWD -IFR -MS 76 6632.08 34.52 354.80 92.34 5138.33 3769.30 3807.34 -366.36 3824.93 354.50 0.30 MWD_IFR_MS 77 6725.61 33.91 354.17 93.53 5215.67 3821.13 3859.69 -371.41 3877.52 354.50 0.75 MWD_IFR_MS 78 6817.78 33.46 354.04 92.17 5292.37 3871.56 3910.54 -376.66 3928.64 354.50 0.49 MWD_IFR_MS 79 6911.47 32.98 353.64 93.69 5370.75 3922.24 3961.57 -382.17 3979.96 354.49 0.56 MWD_IFR_MS 80 7004.52 32.67 353.21 93.05 5448.94 3972.10 4011.68 -387.94 4030.40 354.48 0.42 MWD -IFR -MS 81 7098.79 32.25 352.72 94.27 5528.48 4022.17 4061.90 -394.14 4080.97 354.46 0.53 MWD_IFR_MS 82 7192.58 32.13 348.94 93.79 5607.86 4071.83 4111.20 -402.09 4130.82 354.41 2.15 MWD_IFR_MS 83 7284.82 34.86 343.35 92.24 5684.80 4122.67 4160.55 -414.36 4181.13 354.31 4.46 MWD_IFR_MS 84 7379.32 34.49 342.69 94.50 5762.51 4176.41 4211.97 -430.05 4233.87 354.17 0.56 MWD_IFR_MS 85 7472.08 36.50 338.28 92.76 5838.04 4230.08 4262.69 -448.08 4286.17 354.00 3.51 MWD -IFR -MS 86 7565.55 39.52 334.06 93.47 5911.69 4286.96 4315.28 -471.39 4340.95 353.77 4.26 MWD_IFR_MS 87 7658.32 42.03 329.55 92.77 5981.96 4345.96 4368.61 -500.05 4397.14 353.47 4.17 MWD_IFR_MS 88 7751.95 45.04 324.85 93.63 6049.84 4407.40 4422.75 -535.02 4454.99 353.10 4.72 MWD_IFR_MS 89 7844.76 48.63 321.70 92.81 6113.33 4470.36 4476.95 -575.53 4513.79 352.67 4.59 MWD -IFR -MS 90 7937.78 50.20 320.66 93.02 6173.85 4535.12 4531.98 -619.82 4574.17 352.21 1.89 MWD -IFR -MS • [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 10 -May -2005 16:16:44 Page 5 of 7 ----------- ------------- ----------------------------------------------------- ----- ----- ------ ----------- ------------- ----------------------------------------------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) ----------- ------------- ----------------------------------------------------- ----- ----- ------ ----------- ------------- ----------------------------------------------------- ----- ----- ------ 91 8032.38 52.52 317.88 94.60 6232.92 4601.81 4587.94 -668.04 4636.32 351.72 3.36 MWD_IFR_MS 92 8125.10 54.22 316.67 92.72 6288.24 4667.83 4642.59 -718.53 4697.87 351.20 2.11 MWD_IFR_MS 93 8217.89 56.34 314.67 92.79 6341.09 4734.49 4697.13 -771.83 4760.12 350.67 2.89 MWD_IFR_MS 94 8312.65 60.18 313.24 94.76 6390.94 4803.71 4753.04 -829.85 4824.94 350.10 4.25 MWD_IFR_MS 95 8404.48 65.07 312.20 91.83 6433.15 4872.84 4808.33 -889.75 4889.96 349.52 5.42 MWD -IFR -MS 96 8487.00 69.96 310.30 82.52 6464.70 4936.40 4858.57 -947.07 4950.01 348.97 6.30 BLIND 97 8499.00 71.54 309.14 12.00 6468.66 4945.68 4865.81 -955.78 4958.79 348.89 16.02 BLIND 98 8513.17 72.15 308.66 14.17 6473.07 4956.60 4874.26 -966.26 4969.11 348.79 5.38 INC_TREND 99 8532.04 74.02 308.04 18.87 6478.56 4971.14 4885.46 -980.42 4982.87 348.65 10.40 INC_TREND 100 8562.88 77.17 307.04 30.84 6486.23 4994.93 4903.66 -1004.10 5005.41 348.43 10.69 INC TREND 101 8593.93 80.14 306.05 31.05 6492.34 5018.86 4921.78 -1028.56 5028.11 348.20 10.06 INC_TREND 102 8625.17 85.32 305.08 31.24 6496.29 5042.88 4939.80 -1053.76 5050.94 347.96 16.86 INC_TREND 103 8656.32 86.35 304.12 31.15 6498.55 5066.64 4957.44 -1079.33 5073.58 347.72 4.51 INC_TREND 104 8686.60 89.61 303.20 30.28 6499.62 5089.45 4974.21 -1104.51 5095.36 347.48 11.19 MWD_IFR_MS_SAG 105 8718.32 91.50 301.05 31.72 6499.31 5112.80 4991.08 -1131.37 5117.70 347.23 9.02 MWD -IFR -MS -SAG 106 8749.11 92.25 298.69 30.79 6498.31 5134.61 5006.40 -1158.06 5138.60 346.98 8.04 MWD_IFR_MS_SAG 107 8781.02 93.35 295.66 31.91 6496.75 5156.12 5020.96 -1186.40 5159.22 346.71 10.09 MWD_IFR_MS_SAG 108 8809.51 93.59 294.00 28.49 6495.02 5174.44 5032.90 -1212.21 5176.83 346.46 5.88 MWD_IFR_MS_SAG 109 8841.27 93.42 290.25 31.76 6493.08 5193.70 5044.84 -1241.57 5195.37 346.17 11.80 MWD_IFR_MS_SAG 110 8871.77 93.49 288.47 30.50 6491.24 5211.00 5054.93 -1270.30 5212.10 345.89 5.83 MWD -IFR -MS -SAG 111 8902.63 93.15 284.74 30.86 6489.46 5227.27 5063.73 -1299.81 5227.89 345.60 12.12 MWD_IFR_MS_SAG 112 8934.44 93.28 280.62 31.81 6487.67 5242.16 5070.70 -1330.79 5242.42 345.29 12.94 MWD_IFR_MS_SAG 113 8965.44 92.77 278.17 31.00 6486.03 5255.08 5075.75 -1361.33 5255.14 344.99 8.06 MWD_IFR_MS_SAG 114 8996.74 91.63 274.73 31.30 6484.83 5266.66 5079.27 -1392.41 5266.66 344.67 11.57 MWD_IFR_MS_SAG 115 9026.93 91.77 271.69 30.19 6483.94 5276.23 5080.96 -1422.53 5276.33 344.36 10.08 MWD -IFR -MS -SAG 116 9057.48 92.49 268.61 30.55 6482.80 5284.35 5081.04 -1453.06 5284.72 344.04 10.35 MWD_IFR_MS_SAG 117 9089.10 92.39 265.77 31.62 6481.46 5291.17 5079.49 -1484.61 5292.00 343.71 8.98 MWD_IFR_MS_SAG 118 9121.33 90.37 264.38 32.23 6480.68 5296.96 5076.72 -1516.71 5298.44 343.37 7.61 MWD -IFR -MS -SAG 119 9151.49 90.26 261.24 30.16 6480.51 5301.21 5072.95 -1546.62 5303.47 343.04 10.42 MWD -IFR -MS -SAG 120 9182.65 90.50 257.38 31.16 6480.31 5303.70 5067.17 -1577.24 5306.96 342.71 12.41 MWD -IFR -MS -SAG r1 �J [(c)2005 IDEAL ID9_1C_01.41 SCHLUMBERGER Survey Report 10 -May -2005 16:16:44 Page 6 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 9213.59 91.19 254.27 30.94 6479.85 5304.30 5059.59 -1607.23 5308.73 342.38 10.30 MWD_IFR_MS_SAG 122 9242.27 91.15 253.03 28.68 6479.26 5303.76 5051.52 -1634.74 5309.45 342.07 4.32 MWD IFR_MS_SAG 123 9274.09 91.26 252.54 31.82 6478.60 5302.69 5042.11 -1665.13 5309.94 341.72 1.58 MWD -IFR -MS -SAG 124 9304.27 91.53 253.02 30.18 6477.86 5301.67 5033.17 -1693.95 5310.58 341.40 1.82 MWD_IFR_MS_SAG 125 9335.48 91.26 253.08 31.21 6477.10 5300.76 5024.08 -1723.79 5311.57 341.06 0.89 MWD_IFR_MS_SAG . 126 9366.40 90.88 253.70 30.92 6476.52 5300.04 5015.24 -1753.42 5312.92 340.73 2.35 MWD_IFR_MS_SAG 127 9397.46 90.50 253.01 31.06 6476.15 5299.30 5006.34 -1783.17 5314.43 340.40 2.54 MWD_IFR_MS_SAG 128 9428.26 90.47 252.85 30.80 6475.89 5298.34 4997.30 -1812.62 5315.88 340.06 0.53 MWD -IFR _MS_SAG 129 9459.70 90.85 252.87 31.44 6475.53 5297.32 4988.04 -1842.66 5317.51 339.73 1.21 MWD -IFR _MS_SAG 130 9491.71 90.95 253.35 32.01 6475.02 5296.42 4978.74 -1873.28 5319.50 339.38 1.53 MWD -IFR -MS -SAG 131 9522.49 91.36 253.51 30.78 6474.40 5295.72 4969.96 -1902.78 5321.76 339.05 1.43 MWD_IFR_MS_SAG 132 9553.50 91.40 254.33 31.01 6473.66 5295.29 4961.38 -1932.57 5324.48 338.72 2.65 MWD -IFR _MS_SAG 133 9584.79 91.84 254.51 31.29 6472.77 5295.13 4952.98 -1962.69 5327.68 338.38 1.52 MWD IFR MS SAG 134 9616.02 91.98 255.06 31.23 6471.73 5295.16 4944.79 -1992.81 5331.25 338.05 1.82 MWD_IFR_MS_SAG 135 9647.18 92.12 255.50 31.16 6470.61 5295.47 4936.87 -2022.93 5335.26 337.72 1.48 MWD -IFR -MS -SAG 136 9678.27 92.08 255.39 31.09 6469.48 5295.86 4929.06 -2053.00 5339.52 337.39 0.38 MWD -IFR -MS -SAG 137 9709.31 92.05 255.45 31.04 6468.36 5296.24 4921.26 -2083.02 5343.95 337.06 0.22 MWD_IFR_MS_SAG 138 9740.96 91.50 254.43 31.65 6467.38 5296.36 4913.04 -2113.57 5348.38 336.72 3.66 MWD_IFR_MS_SAG 139 9772.58 91.22 253.56 31.62 6466.63 5295.96 4904.32 -2143.96 5352.47 336.39 2.89 MWD -IFR _MS_SAG 140 9802.94 88.48 255.77 30.36 6466.71 5295.93 4896.29-2173.23 5356.92 336.07 11.59 MWD -IFR -MS -SAG 141 9834.33 88.17 256.17 31.39 6467.62 5296.62 4888.69 -2203.67 5362.41 335.74 1.61 MWD IFR_MS_SAG 142 9865.67 88.21 256.87 31.34 6468.61 5297.60 4881.38 -2234.13 5368.36 335.41 2.24 MWD -IFR -MS -SAG 143 9896.80 88.89 256.90 31.13 6469.40 5298.78 4874.32 -2264.44 5374.64 335.08 2.19 MWD -IFR _MS _SAG 144 9928.12 89.06 257.69 31.32 6469.96 5300.18 4867.44 -2294.99 5381.35 334.76 2.58 MWD -IFR -MS MS_SAG -SAG 145 9959.64 89.23 257.18 31.52 6470.43 5301.68 4860.58 -2325.75 5388.35 334.43 1.71 MWD -IFR -MS -SAG 146 9990.50 89.10 257.77 30.86 6470.88 5303.16 4853.89 -2355.87 5395.40 334.11 1.96 MWD -IFR _MS_SAG 147 10021.58 89.24 257.85 31.08 6471.33 5304.84 4847.33 -2386.25 5402.85 333.79 0.52 MWD -IFR _MS_SAG 148 10052.72 88.82 260.07 31.14 6471.86 5307.14 4841.36 -2416.81 5411.08 333.47 7.25 MWD -IFR -MS -SAG 149 10084.19 89.82 260.61 31.47 6472.23 5310.22 4836.08 -2447.83 5420.29 333.15 3.61 MWD -IFR -MS -SAG 150 10116.27 91.26 260.71 32.08 6471.93 5313.54 4830.88 -2479.48 5430.03 332.83 4.50 MWD_IFR_MS_SAG [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 10 -May -2005 16:16:44 Page 7 of 7 --- Seq -------- Measured ------ Incl ------- Azimuth ---- Course - TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 151 10146.13 91.60 260.68 29.86 6471.18 5316.65 4826.05 -2508.94 5439.26 332.53 1.14 MWD_IFR_MS_SAG 152 10177.60 92.49 261.29 31.47 6470.06 5320.08 4821.12 -2540.00 5449.30 332.22 3.43 MWD_IFR_MS_SAG 153 10209.22 92.53 261.52 31.62 6468.68 5323.75 4816.40 -2571.23 5459.76 331.90 0.74 MWD_IFR_MS_SAG 154 10239.87 91.88 262.35 30.65 6467.50 5327.60 4812.11 -2601.56 5470.33 331.60 3.44 MWD_IFR_MS_SAG 155 10270.58 91.91 262.81 30.71 6466.48 5331.80 4808.14 -2631.99 5481.39 331.30 1.50 MWD_IFR_MS_SAG 156 10301.84 91.88 262.63 31.26 6465.45 5336.15 4804.18 -2662.98 5492.87 331.00 0.58 MWD_IFR_MS_SAG 157 10332.82 91.77 262.21 30.98 6464.46 5340.30 4800.10 -2693.68 5504.26 330.70 1.40 MWD_IFR_MS_SAG 158 10363.97 92.80 260.96 31.15 6463.22 5344.02 4795.54 -2724.47 5515.43 330.40 5.20 MWD_IFR_MS_SAG 159 10395.56 94.31 260.73 31.59 6461.26 5347.38 4790.53-2755.59 5526.52 330.09 4.83 MWD_IFR_MS_SAG 160 10427.69 94.07 260.91 32.13 6458.91 5350.79 4785.42 -2787.23 5537.95 329.78 0.93 MWD_IFR_MS_SAG 161 10457.86 92.39 260.04 30.17 6457.21 5353.81 4780.43 -2816.93 5548.66 329.49 6.27 MWD_IFR_MS_SAG 162 10490.18 90.95 260.36 32.32 6456.27 5356.89 4774.93 -2848.77 5560.17 329.18 4.56 MWD_IFR_MS_SAG 163 10519.02 89.03 257.18 28.84 6456.28 5358.93 4769.32 -2877.05 5569.90 328.90 12.88 MWD_IFR_MS_SAG 164 10550.00 89.03 258.70 30.98 6456.80 5360.67 4762.85 -2907.34 5580.08 328.60 4.91 MWD_IFR_MS_SAG 165 10562.79 87.90 257.67 12.79 6457.14 5361.44 4760.23 -2919.85 5584.38 328.48 11.95 MWD_IFR_MS_SAG 166 10615.00 87.90 257.67 52.21 6459.06 5364.13 4749.09 -2970.83 5601.75 327.97 0.00 Projection to TD • [(c)2005 IDEAL ID9_1C_01.41 0 Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No L-124 Date Dispatched: 0 -Jan -00 Installation/Rig Nabors 9ES Dispatched By: 0 Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling &Measurements LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel@slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, 10-02-03 Schlumberger Private Schlumberger Private Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No L-124PB1 Date Dispatched: 0 -Jan -00 Installation/Rig Nabors 9ES Dispatched By: 0 Data No Of Prints No of Floppies Surveys 2 1 Received By: � Please sign and return to: Drilling &Measurements LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosei@sl6.com Fax: 907-561-8417 LWD Log Delivery V1.1, 10-02-03 Schlumberger Private Schlumberger Private Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No L-124PB2 Date Dispatched: 0 -Jan -00 Installation/Rig Nabors 9ES Dispatched By: 0 Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling &Measurements LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nroselCa?slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, 10-02-03 Schlumberger Private Schlumberger Private • gno2data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP L -PAD #L-124 NABORS #9ES PRUDHOE BAY, AK AK0405G_546 APRIL 27, 2005 Serving the Worldwide Energy industry with Precision Survey Instrumentation )0S' -o1 -f3 gyrodata 1_ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 May 9, 2005 Ms. Sharmaine Copeland BP Exploration (Alaska) Inc. 900 E. Benson Blvd. Petrotechnical Data Center, LR2-1 Anchorage, Alaska 99508 Re: L -Pad, Well #L-124 Prudhoe Bay, Alaska Enclosed, please find one (1) original, two (2) copies, and two (2) disks of the completed survey of the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincely, Paul E. Neumann Operations/Account Manager PEN:tmf Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directional Survey for BP EXPLORATION Lease: L -Pad Well: L-124,4" Drillpipe Location: Nabors OES, Greater Prudhoe Bay, Alaska Job Number: AK0405G 546 Run Date: 27 Apr 2005 Surveyor: Jeff Smith Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350527 deg. N Longitude: 149.325914 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 330.000 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey BP Exploration Lease: L -Pad Well: L-124, 4" Drillpipe Location: Nabors #9ES, Greater Prudhoe Bay, Alaska Job Number: AK0405G 546 MEASURED I N C L AZIMUTH VERTICAL DOGLEG VERTICAL CLOSURE DEPTH SECTION SEVERITY DEPTH DIST. AZIMUTH feet deg. deg. feet deg./ feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.00 0.00 0.00 0.0 0.00 0.00 0.0 0.0 0.00 N ---------------------------------------------------------------------------------------------------------------------------------------------------- 0 - 1189 FT. RATE GYROSCOPIC MULTISHOT AND MOTOR ORIENTATION RUN INSIDE 5" DRLLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9ES R.K.B. OF 28.5 FT. GYRO TOOLFACE EQUALS THE DIRECTION OF THE KEYWAY 100.00 0.20 271.64 0.1 0.20 200.00 0.33 49.75 0.2 0.50 300.00 1.82 21.25 1.3 1.54 400.00 2.70 5.81 4.2 1.06 500.00 3.78 359.68 9.0 1.13 600.00 5.59 349.43 16.4 1.99 700.00 7.64 345.53 27.4 2.10 800.00 10.20 343.51 42.4 2.58 850.00 10.96 342.90 51.4 1.54 900.00 13.75 343.59 61.8 5.59 950.00 14.85 343.77 73.8 2.20 1000.00 17.34 344.83 87.2 5.01 1050.00 19.56 344.20 102.6 4.46 1100.00 20.97 344.73 119.3 2.84 1150.00 23.54 345.82 137.6 5.22 1189.00 24.93 345.83 153.0 3.56 Final Station Closure: Distance: 159.81 ft Az: 346.81 deg. 0.00 E 100.00 0.2 271.6 0.00 N 0.17W 200.00 0.2 328.6 0.20 N 0.12 W 299.98 2.0 19.9 1.87 N 0.68 E 399.90 5.9 14.7 5.69 N 1.49 E 499.74 11.5 8.6 11.33 N 1.71 E 599.40 19.4 2.4 19.42 N 0.80 E 698.73 30.7 356.7 30.65 N 1.75 W 797.51 46.0 352.6 45.58 N 5.93 W 846.66 55.0 351.0 54.37 N 8.59W 895.50 65.7 349.8 64.62 N 11.66W 943.95 78.0 348.8 76.48 N 15.13 W 991.99 91.8 348.1 89.82 N 18.88 W 1039.41 107.6 347.6 105.07 N 23.10W 1086.32 124.9 347.2 121.76 N 27.74 W 1132.59 143.8 346.9 140.07 N 32.54W 1168.15 159.8 346.8 155.60 N 36.46W 2 BP Exploration ' Well: L -Pod L'1244" DhUpipe Location: Nabors #9ES, Greater Prudhoe Bay, Alaska 150 125 100 75 50 25 rel - [>UtrUO Gyrodata AK0405C] 546 DEFINITIVE BOTTOM HOLE LOCATED -35 -30 -25 -30 -15 -10 EASTING (ft) -35 -30 -25 -30 -15 -10 EASTING (ft) BP Exploration - Well: L -Pad L-1244" DhUpipe Location: Nabors #gES,Greater Prudhoe Bay, Alaska 15.0 7.5 5.0 2.5 C)UtrUD Gvrodata AK0405(S_546OEFINITIVE 100 200 300 400 500 600 700 800 MEASURED DEPTH (ft) | | | | | 900 1000 1100 1200 1300 BOTTOM HOLE A LOCATED MD: 1189.00 100 200 300 400 500 600 700 800 MEASURED DEPTH (ft) | | | | | 900 1000 1100 1200 1300 BP Exploration _ Well: L -Pad L-1344" OhUp|pe Location: Nabors #9ES, Greater Prudhoe Bay, Alaska 25 20 15 10 Elm - OUt[UD <3yn]data AK0405G546 DEFINITIVE | | | I | | I I 100 200 300 400 500 600 700 800 MEASURED DEPTH (ft) | | | | | 900 1000 1100 1200 1300 3OTTOM OLE | | | I | | I I 100 200 300 400 500 600 700 800 MEASURED DEPTH (ft) | | | | | 900 1000 1100 1200 1300 ' BP Exploration _ Well: L -Pad L-124 4" [)hUp|pe Location: Nabors #9ES, Greater Prudhoe Bay, Alaska 150 125 50 25 IC ° ' (JUtrUD Gymdata AK0405G546 DEFINITIVE 100 200 300 400 500 600 700 800 900 1000 1100 MEASURED DEPTH (ft) | | 1200 1300 -HOLE BOTTOI� 100 200 300 400 500 600 700 800 900 1000 1100 MEASURED DEPTH (ft) | | 1200 1300 ^ - BP Exploration _ VVeU:L-Pad L-1244"OhUp|pe Location: Nabors #9ES, Greater Prudhoe Bay, Alaska - - Outrun Gvrodata AK0405G546 DEFINITIVE 100 200 300 400 SOO 600 700 800 900 MEASURED DEPTH (ft) | | | | 1000 1100 1200 1300 M 1189.00 100 200 300 400 SOO 600 700 800 900 MEASURED DEPTH (ft) | | | | 1000 1100 1200 1300 qqj FRANK H. MURKOWSKI, GOVERNOR ALA RA OIL AND GALS iy333 W. 7' AVENUE, SUITE 100 CONSERVATION COMI�IISSION i ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Rob Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-124 BP Exploration (Alaska) Inc. Permit No: 205-043 Surface Location: 2521' NSL, 3889' WEL, SEC. 34, T12N, RUE, UM Bottomhole Location: 1927NSL, 1914' WEL, SEC. 28, T12N, RI IE, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissio o fitness any required test. Contact the Commission's petroleum field inspector at (907) 65 -36 (pager). la DATED this' day of March, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. c t"6,+ 312-21wo!; STATE OF ALASKA RECEIVED ALA RA OIL AND GAS CONSERVATIONPOMMISSION PERMIT TO DRILL 20 AAC 25.005 /Aleska Oil & Gas Cons, conlTission 1a. Type of work ® Drill ❑ Redrill ❑ Re -Entry 1b. Current Well Class ❑ Exploratory ® Development ht: �y�tiple Zone ❑ Stratigraphic Test ❑ Service ❑ Development & SfMitjle Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ® Blanket ❑ Single Well Bond No. 25100302630-277 11. Well Name and Number: PBU L-124 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10967 TVD 6473 12. Field / Pool(s): Prudhoe Bay Field / Borealis Pool 4a. Location of Well (Governmental Section): Surface: 2521' NSL, 3889' WEL, SEC. 34, T1 2N, Fill 1E, UM Top. of Productive Horizon: 2173' NSL, 4908'W EL, SEC. 27, T1 2N, R11 E, UM Total Depth: 1927' NSL, 1914' WEL, SEC. 28, T12N, R11 E, UM 7. Property Designation: ADL 028239 8. Land Use Permit: 13. Approximate Spud Date: April 4, 2005 9. Acres in Property: 2560 14. Distance to Nearest Property: 5,850' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583026 -5978241 Zone-ASP4 10. KB Elevation Planned (Height above GL): 72,6 teetl 15. Distance to Nearest well Within Pool 1,575' from L-117 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole Angle: 93 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3350 Surface: 2697 18. CasingProgram: Size Specifications Setting Depth Quantity o Cement To Bottom c.f. or sacks) Hole Casing Weight Grade Coupling Lencith MD TVD MD TVD(including stage data 42" 20" 215.5# A-53 Weld 80' 29' 29' 109' 109' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3196' 29' 29' 3194' 2588' 530 sx AS Lite, 378 sx Class'G' 8-3/4" 7" 26# L-80 BTC -M 10938' 29' 29' 9170' 6713' 81 sx Class 'G', 211 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2427' 8540' 6460' 10967' 6473' 80 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor IntermediateSurface Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ® Filing Fee, $100 ❑ BOP Sketch ® Property Plat ❑ Diverter Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21, Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Gagliardi, 564-5251 Printed Name Rob Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Signature �� f- 3 /�' r Phone 564-4166 Date /1� 5j Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: , API Number: 50-Q 2 — — 3.Z Permit Approval Date: ��a�flo� See cover letter for other requirements Conditions of Approval: Sam Required ❑ Yes ) No Mud Log Required !_._; Yes X No H rog Sulfide Measures ' Yes No Directional Survey Required yX Yes El No Other: to SOO S tR . APPROVED BY A roved —, , THE COMMISSION Date (/ Form 10-401 Revised 6/ 04NAL ubmi n Duplicate • i Well Name: I L-124 Well Plan Summary Type of Well(producer or injector): I Horizontal Producer Surface Location: 2,521' FSL, 3,889' FEL, Sec. 34, T12N, R11 E Wt/Ft ''! X = 583,026 Y = 5,978,241 L-124 Target 1 334' FSL, 4,195' FEL, Sec. 27, TI 2N, R11 E Schrader Bluff X = 582,680 Y = 5,981,330 Z = 3,970' TVDss L-124 Target 2 Kuparuk C: 2,173' FSL, 4,908' FEL, Sec. 27, T1 2N, R11 E 42" X = 581,942 Y = 5,983,160 Z = 6,410' TVDss L-124 Production BHL: 1,927' FSL, 1914' FEL, Sec. 28, T1 2N, R11 E Weld X = 579,660 Y = 5,982,890 Z = 6,400' TVDss AFE Number: I BRD5M4145 =FR-7ig-.j =FR-7i-.jNabors 9ES GL: 1 44.1' KB: 1 28.5' Estimated Start Date: I Aril e, 2005 FO-perating days to co, m tete: I15,0 TD: I 10,967' MD I TVD: I I Max Inc: 93.5°� I KBE: 1 72.6' Well Design: USH Grassroots Producer 3-1/2" IBT-M Completion. Wt/Ft ''! The Ku aruk C sand will have a 4-'/2" IBT-M liner completion. Current Well Information General Distance to Nearest Property: Distance to Nearest Well in Pool API Number: Well Type: Current Status: Conductor: BHP: BHT: Cacinn/Tnhinn Prnnram 5,850' to the nearest PBU property line 1,575' from L-124 to L-117 50-029-XXXXX Development - Borealis Producer j New well, 20" X 34" insulated conductor / 20" X 34", 215.5 Ib/ft, A53 ERW set at 109' RKB 3,350 psi @ 6,530' TVDss (9.8 ppg EMW). 155°F @ 6,600' TVDss estimated Hole Size Csg / Tbg O.D. Wt/Ft ''! Grade Conn /�(psi) Burst Collapse (psi) Length Top MD / TVDrkb Bottom MD / TVDrkb 42" 20" 215.5# A-53 Weld 80' 29'/ 29' 1091/109, 12-1/a" 9-%" 40# L-80 BTC 5,750 3,090 3,165' 29'/ 29' 3,194'/ 2,588' 8-3/a" 7" 26# L-80 BTC -M 7,240 5,410 9,141' 29'/ 29' 9,170'/ 6,713' 6-%" 4-1/2" 12.60# L-80 IBT-M 1 8,430 7,500 2,427' 1 8,540'/ 6460' 10,967'/ 6,473' Tubing 3-1/2" 9.20# L-80 IBT-M 1 10,160 10,530 8511' 1 29'/ 29' 8,540'/ 6,473' L-124 Permit to Drill Page 1 Formation Markers L-124 (Based on Schlumberger PBI (1135)) Formation Tops MD TVD TVDss Pore psi EMW ppg Hydrocarbons G1 328 400 260 113 8.4 No SV6 977 968 895 391 8.4 No SV5 1,780 1,643 1,570 685 8.4 No Base Permafrost 1,913 1,733 1,675 731 8.4 No SW 1,981 1,778 1,705 744 8.4 No SV3 2,333 2,013 1,940 847 8.4 No SV2 2,565 2,168 2,095 914 8.4 No SV1 3,045 2,588 2,415 1,054 8.4 No UG4 3,479 2,778 2,705 1,180 8.4 No UG4A 3,524 2,807 2,735 1,193 8.4 No UG3 4,026 3,143 3,070 1,340 8.4 No UG1 4,745 3,623 3,550 1,549 8.4 No Fault #1 4,954 3,763 3,690 8.4 Top Schrader/Ma Sand 5,031 3,818 3,745 1,634 8.4 No Na 5,329 4,048 3,975 1,735 8.4 Yes OA 5,517 4,203 4,130 1,802 8.4 Yes Obf_Base 5,958 4,568 4,495 1,961 8.4 No CM2 (Colville Shales K-10 5,357 4,898 4,815 No CM1 Colville Shales 7,066 5,483 5,410 1 No THRZ 7,873 6,107 6,035 No Kalubik 8,232 6,323 6,250 No K-1 8,343 6,378 6,305 No TKUP 8,560 6,468 6,395 Yes Ku aruk C 8,603 6,482 6,410 3,075 9.2 Yes LCU Ku aruk B 8,927 6,603 6,5301 3,350 9.8 No Intermediate T.D. * 9,170 6,713 6,641 Production T.D.** 10,967 6,473 6,400 *Intermediate TD is based on 250' MD below the LCU (Kuparuk B)* ** Production TD is based on 50' short of polygon hardline ** Mud Proaram: 121/4" Surface Hole Mud Properties: PV Spud - Freshwater Mud I LSRV I HTHP FL pH Interval Density Funnel Vis PV YP FL Chlorides PH Initial 8.5-9.2 250-300 20-50 50-70 NC -8.0 <500 8.5-9.0 Base Perm 9.0-9.5 300-250 20-45 40-55 8.0 <500 8.5-9.0 Interval TD 9.5-9.6 200-250 20-35 35-45 5.0-7.0 <500 8.5-9.0 8 3/4" Intermediate Hole Mud Properties: I Freshwater Mud (LSND) Interval Density Funnel Vis PV YP FL pH Chlorides MBT Surface shoe to 7,673' 9.0,,-%3 38-50 12-18 26-35 4-6 9.0-9.5 <600 < 20 7,673'- 9,170' A1.51 38-50 12-18 24-32 3.0-4.5 9.0-9.5 <600 < 15 6 %" Production Hole Mud Properties: (KUP C Only) I Freshwater Mud (Flo Pro SF) Interval Density PV YP I LSRV I HTHP FL pH 8,690'- 10,967' 9.4-9.7 8-15 22-28 >20,000 4-6 9.0 - 9.5 Survey and Logging Program: 12-1/4" Hole Section: Surface Gyro will be needed (run to 1200' or as conditions dictate) Open Hole: MWD / GR Cased hole: None 8-3/4" Hole Section: MWD / GR / Res / Den / Neu / PWD (Neutron Density in record mode) Cased Hole: None 6-%" Hole Section: MWD / GR / Res / Den / Neu (All real time) Cased Hole: None L-124 Permit to Drill Page 2 ?Z q•1 Surface and Anti -Collision Issues Surface Shut-in Wells: Nearby Well I L-1121 Distance to L-1121 15' L-1 12i will require surface shut-in and well house removal in order to move over well L-124. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautionary Comment L-02 32.18 -ft 390 -ft 25.44 -ft Use Traveling Cylinder (Gyro) L -02A 31.61 -ft 346 -ft 25.35 -ft Use Traveling Cylinder (Gyro) L-101 19.90 -ft 694 -ft 7.87 -ft Use Traveling Cylinder (Gyro) L-1121 12.79 -ft 440 -ft 4.06 -ft Use Traveling Cylinder (Gyro) L-115 91.66 -ft 345 -ft 86.00 -ft Use Traveling Cylinder (Gyro) L-122 46.04 -ft 936 -ft 29.93 -ft Use Traveling Cylinder (Gyro) L-211 59.22 -ft 1,685 -ft 28.22 -ft Use Traveling Cylinder (Gyro) L-113 15.72 -ft 400 -ft 7.12 -ft Use Traveling Cylinder (Gyro) Cement Calculations: Casing Size: 19-%" in 40-Ib/ft L-80 BTC - Single Stage Basis: Lead: 250% excess over gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 750' of open hole with 30% excess, plus 80' shoe track Tail TOC: 2,444' MD Total Cement Volume: Spacer 180 bbls of Viscosified 51Wer weighted to 10.0 ppg (Mud P II) Lead 1404bbls, 2,268cultrWsks 10.7 ASL G + adds cuft/sk Tail 179bbis, 441 cuft 3 ks 15.8 ppg Class G + adds 1. 1Y cuft/sk Temp I BHST - 50° F, B 80° F estimated by Schlumberdefl- In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 7" 26 Ib/ft L-80 BTC -M - Single Stage Basis: Lead: 3529' pen hole with 30% excess over gauge hole Lead TOC. 4,5,1' MD 500' MD above planned Ma top at 5,032' MD Tail: 1,110' o open hole with 30% excess, plus 80' shoe track Tail TOC: 8,060' MD 500' MD above planned top KUP C at 8,560' Total Cement Volume: Spacer 165 bbls of Viscosifie pacer (Mudpush II Design) ghted to 10.3 ppg Lead 119 bbls, 668 cuft, sks 12.0 G +adds - uft/sk Tail 44 bbls, 247 cuft, PIA sks 15.8 ppg G + Gasblok - cuft/sk Temp BHST = 90° F, B 80° F estimated by Schlumber. er Casino Size 14-1/2" Production Liner Basis: Tail: Based on 2,264' of open holew % excess + 200' excess (4" DP) + 80' shoe track Cement Placement: From shoe to ,54 'MD TOL Total Cement Volume: Lead Tail 58 bbls /ft / sks of Dowell Premium "G" with Gasblok at 15.8 ppq and cuf sk L-124 Permit to Drill Page 3 Centralizer Recommendations: 9-%" Casing Centralizer Placement a) Run (25) 9-1/8" Bow -spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,225' MD (1,000' MD above the shoe). b) Run 2 Bow -spring centralizers on either side of the TAM Port Collar (if run). c) This centralizer program is subject to change due to actual hole conditions. 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 4,531' MD (500' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. 4-'/z" Liner Centralizer Placement a) Place 1 rigid straight blade centalizer per joint, floating across the entire joint up to 8623' MD (two joints from window). Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Due to test pressures not exceeding -- 5, 000psi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for L-124 will be 14 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: 7" Casing Test: Integrity Test — 8-3/4" hole: Kick Tolerance: Planned completion fluid: Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: 41/2" Casing Test: Integrity Test — 6-%" hole: Kick Tolerance: Planned completion fluid: Disposal 3,350 psi — Base of Kuparuk B (9.8 ppg @ 6,530' TVDss)/ 2,697 psi— Based on a full column of gas @ 0.10 psi/ft 3,500 psi/250 psi Rams 2,500 psi/250 psi Annular 3,500 psi 12.3 ppg minimum EMW LOT 20' from 9-%" shoe 50.5 bbls with an 12.3 ppg EMW LOT Estimated 9.0 ppg Brine / 6.8 ppg Diesel 3,075 psi— Base of Kuparuk C (9.2 ppg @ 6,410' TVDss) 2,434 psi — Based on a full column of gas @ 0.10 psi/ft 3,500 psi/250 psi Rams 2,500 psi/250 psi Annular 3,500 psi 11 p g minimum EMW FIT 20' from 7" shoe tinitmeated 9.0 ppg Brine / 6.8 ppg Diesel No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS - 04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul all Class I waste to Pad 3 for disposal. L-124 Permit to Drill Page 4 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control A. The Kuparuk is expected to be slightly over pressured @ 9.2 – 9.8 EMW. However, a 10.6 ppg EMW was required in L-110 which is supported by injector L-109. Hydrates and Shallow gas A. Gas Hydrates are present at L -pad and have been encountered in wells as close as L-02 and L-1121 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Occasionally hydrates are encountered below the SV1. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to L-02 and L-1121 had to have the mud treated and were able to drill to section TD. Ill. Lost Circulation/Breathing A. Lost circulation is possible. Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 95/6" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail and 12.0 Ib/gal lead cement to 500' MD above the Top Ma --4,532' MD. a. The Kick Tolerance for the surface casing i0. / Is with 10.8 ppg mud, 12.3 ppg LOT, and a 9.8 ppg pore pressure. Integrity Testing –1 . g EMW LOT C. The 4-1/2" production liner will be cemented with 15.8 ppg tail cement to the liner top. a. The Kick Tolerance for the intermediate casing isnfi with 9.4 ppg mud, 11.0 ppg FIT and a 9.2 ppg pore pressure. Integrity Testing –11.0 p MW FIT V. Stuck Pipe A. 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. B. 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 C. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should / be follow—ea-at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-1 13i 0 ppm L-122 10 ppm L -02A 10 ppm L-1 15i 0 ppm VII. Faults A. Two faults are expected to be crossed by L-124. No losses are expected to be associated with either fault. Details are listed below for reference: Fault 1 (UG1): 4,954' MD 3,763' TVD 3,690' TVDss Throw: 120'S Fault 2 (Kup C): 10,200' MD 6,519' TVD 6,447' TVDss Throw: 20'W CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION L-124 Permit to Drill Page 5 L-124 Drill and Complete Procedure Summary Pre -Rig Work: 1. The L-124 conductor has been set (Slot N -C). See As -Built. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in L-1121 and remove well house as necessary. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-'/a" drilling assembly with Dir/GR and directionally drill surface hole to approximately 3,194' MD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. An intermediate wiper/bit trip to surface will be performed prior to exiting the permafrost. 4. Run and cement the 9-%", 40.0-Ib/ft. surface casing back to surface. A TAM Port Collar should be on location; however, lost circulation is not expected. A TAM port collar will be run in the casing string only if hole conditions dictate. Bump plug and test the 9-5/6" casing to 3,500 psi for 30 minutes. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 3,500 psi. 6. MU 8-3/a" drilling assembly with Dir/GR/Res/Azi-Den/Neu(recorded)/PWD and RIH to float collar. Circulate and condition cement contaminated mud. Displace over to new 9.0 ppg LSND mud. 7. Drill new formation to 20' below 9-1/8" shoe and perform LOT (If a 12.3 ppg EMW is not obtained contact ,. ODE). 8. Drill to t 200' above the HRZ, ensure mud is conditioned to 11.0 ppg and perform short trip as needed. Ensure pre -reservoir meeting is held highlighting kick tolerance and detection prior to entering the HRZ. 9. Drill ahead to target TD at 9,170' MD, (approx 250' MD below LCU Kup B). 10. Circulate and condition hole, POOH to run casing. Perform wiper trip only if hole conditions dictate. 11. Run and cement the 7" production casing. Displace the casing with 9.4 ppg Flo -pro mud during cementing operations. Pressure test casing to 3,500 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-%" annulus. 12. RU Schlumberger a -line. RIH w/ GR-CCUJB to float collar. MU 7" EZSV and RIH. Set (at 8,703 MD) such that Baker window top is at top Kuparuk C sand (8,687' MD). 13. MU and RIH w/ 7" Whipstock assembly. Set Whipstock such that window top is at the top of the Kuparuk C sand (8,687' MD). Mill Window and drill 20' of new formation. Perform FIT test to 11.0 ppg EMW. POOH and LD milling assembly. 14. MU 6-%" drilling assembly with MWD / GR / Res / Den / Neu (All real time). 15. Build to horizontal @ 100/100 ft and then drill ahead to proposed TD @ 10,967'MD / 6,473' TVD. Short trip as required and condition hole for running 4-'/2" liner. 16. Run 4-1/2 " solid liner. There will be 150' of overlap into the 7" intermediate casing. Cement liner as directed" Set liner top packer. Release from liner and displace well to filtered 9.4 ppg KCI brine and POOH. 17. PU DPC guns and RIH w/ -1,000' of 2-%" HSD UJ 2906 6 spf, 600 phasing perf guns. Tag PBTD for depth control. 18. Run 3-1/2" 9.2 ppf, L-80 IBT-M completion w/ Halliburton pressure gauge (@8,423' MD). RILD. Set packer % @ 8,360' MD and test tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes. 19. Shear DCK valve and install TWC. 20. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Remove TWC. 21. RU hot oil truck. Freeze protect the well from lowest GLM. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-1/2" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 22. Rig down and move off. Post -Rig Work: 1. R/U Slickline and pull ball and rod / RHC. Replace the DCK shear valve with a dummy GLV. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. L-124 Permit to Drill Page 6 #1 0 L-124 Detailed Drilling Procedure Job 1: MIRU Critical Issues: ➢ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted. Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. ➢ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ➢ L-1121 will have to be shut in and require wellhouse removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre -job safety meeting and designate a spotter to ensure there is no danger of a collision. Nearby Wells I L-1 12i Distance to L-1121 1 15' ➢ L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-1131 0 ppm (Not drilled) L-122 10 ppm L -02A 10 ppm L-1 15i 0 ppm Reference SOP: ❖ "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 12'/4" Surface Hole Critical Issues: ➢ At L -Pad, no significant surface hole drilling problems are present. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. ➢ Close Approach: The L-1121 will be required to be shut in and have the wellhouse removed due to surface location proximity to the L-124. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. A gyro should be run to at least 900'-1200'. ➢ Faults: No faults are expected in the L-124 surface hole section. ➢ Directional: Every effort should be made to ensure a `smooth' well profile that will benefit torque / drag in the later hole sections and allow for easier 9-%" casing running. A graduated build profile is planned. It is preferred that DLS are not pushed ahead of plan on the surface hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. ➢ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80 -rpm while drilling because of the 1.830 motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +100 -rpm prior to POOH to run casing. At this time flowrates should be increased to 650 — 700 GPM to increase hole cleaning. Before pulling out of the hole for the final time, make sure that the hole is clean, full returns are observed, and that the pipe pulls without significant overpull. Lost circulation is possible while cementing if these conditions are not satisfied. L-124 Permit to Drill Page ➢ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back -reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. ➢ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. Reference RPs: ❖ "Prudhoe Bay Directional Guidelines" ❖ "Well Control Operations Station Bill" ❖ Follow Schlumberger logging practices and recommendations Job 3: Run 9-%" Surface Casing Critical Issues: ➢ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. Hydrates are prevalent on L -pad all the way through the SV1 and slightly beyond. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ➢ Casing drift: 9-%", 40# special drift casing is being used (8.835" ID, 8.75" drift). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-3/4" bit (float equipment, casing hanger, etc). ➢ Cement to surface: A single -stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar should be placed at 1,000 -ft MD as a contingency, if hole conditions warrant. If displacement goes according to plan, bump plug and walk pressure to 3,500 psi and hold for 30 minutes for casing pressure test. ➢ Losses during cement job: Lost circulation has been experienced on offset pads while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7-ppg EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. ➢ Requirements for future annular disposal: 1. Pipe reciprocation during cement displacement. 2. Top of tail cement >500' TVD above shoe using 30% excess. 3. Casing shoe set approx 1 00'TVD below SV -1 sand. Reference RPs: ❖ "Casing and Liner Running Procedure" ❖ "Surface Casing and Cementing Guidelines" ❖ "Surface Casing Port Collar Procedure" Job 4: Drill 8-3/4" Intermediate Hole Critical Issues: ➢ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. L-124 Permit to Drill Page ➢ LOT: Perform a LOT (minimum 12.3 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Kuparuk reservoir pressure of 9.8 ppg and 10.8 ppg mud, a 12.3 ppg leak -off will provide 50.5 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 12.3 ppg. Based upon off -set drilling data, a minimum leak -off of 13 ppg is expected at the 9-%" shoe. ➢ Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for ECDs not to exceed 0.6ppg above calculated. If ECDs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. ECD should not exceed 11.0 ppg once the M sand has been penetrated. ➢ Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. ➢ Faults: One fault is expected to be crossed in the L-124 8-3/4" hole section. Losses are not expected to be associated with this fault. Details are listed below for reference: Fault 1: 4,954' MD 3,763' TVD 3,690' TVDss Throw: 120'S ➢ Screen Blinding: Add EMI 697 as per MI mud program while drilling the Ugnu/heavy oil sands ➢ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the production hole section. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the KUP B sand using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. ➢ 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the Kup B sand. After seeing the top Kup B, TD will be picked based on drilling 250' MD past the top of the Kuparuk B sand to allow MWD logs over the entire Kuparuk C formation. This footage is critical for future well work. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. Reference RPs: ❖ Standard Operating Procedure for Leak -off and Formation Integrity Tests ❖ Prudhoe Bay Directional Guidelines ❖ Lubricants for Torque and Drag Management. ❖ "ERD Operating Practices" Job 6: Run and Cement 7" Intermediate Casing Critical Issues: ➢ Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. ➢ Cement Job: The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 500' above the top of the Kuparuk to 500' above the top of the Schrader Ma and the tail will cover from the shoe to 500' above the top of the Kuparuk. Ensure a minimum hydrostatic equivalent of 11.0 ppg across the HRZ during pumping of cement pre -flushes. Reciprocate pipe as long as possible while cementing. Keep cementing ECD's below 12.3 ppg EMW during the displacement. ➢ Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the 7" x 9-%" casing outer annulus with 72 bbls of dead crude (2,614' MD, 2,200'TVD), the hydrostatic pressure will be 7.7 ppg vs. 8.4 ppg EMW of the formation pressure immediately below the shoe. Ensure a double -barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be over 100 psi underbalance to the open hole. ➢ Central ization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any L-124 Permit to Drill Page 0 i permeable zones if the casing is left stationary while running in the hole. ➢ Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. If EMI 776 is used, a larger spacer may be necessary. ➢ Franks Casing Fill -up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. ➢ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC -M casing is on the rig floor before running casing. Reference RPs: ❖ "Intermediate Casing and Cementing Guidelines" ❖ "Freeze Protecting an Outer Annulus" Job 7: Set Whipstock and Drill 6%" Horizontal Production Hole Critical Issues: ➢ A Whipstock will be set in the 7" intermediate casing to facilitate kicking off the horizontal production hole. Once Milling is complete, make sure that all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which have accumulated. ➢ There are no "close approach" issues with the production hole interval of L-124. ➢ Mud losses of 10-80 bph have been encountered in offset horizontal sections. In particular V-117 lost 5,400 barrels of mud while drilling this interval. Contingency LCM material and mud product should be available at the rigsite/mud plant. ➢ Under no circumstances add any LCM (including Walnut sweeps, cellulose material) other than calcium carbonate for losses < 50 BPH without prior discussions with the Drilling Engineer/Asset Production Engineer. Significant mud losses > 50 BPH may include the use of cellulose material to arrest losses. See LCM discussion in MI Mud Program. ➢ There are no restrictions concerning adding lubricants to the mud whilst drilling the horizontal hole. Lubetex concenetrations of 2% may be needed to improve weight transfer in critical kick-off section. ➢ Fault # 2 will be cut in the 6-%8" horizontal section @ approximately 10,200' MD / 6,519' TVD with 20' of throw to the West. ➢ MWD, gamma ray, resistivity, neutron and density will be run real time in this section of the hole. ➢ FIT: Perform a FIT (minimum 11.0 ppg EMW). Contact Anchorage personnel if FIT is less than i 11.0 ppg. Reference RPs ❖ "Standard Operating Procedure for Leak -off and Formation Integrity Tests" ❖ "Prudhoe Bay Directional Guidelines" ❖ "Lubricants for Torque and Drag Management" ❖ ERD Recommended Practice Section 5.2 Operating Practices ❖ Whipstock Sidetracks- RP Job 9: Install 41/2" Production Liner L-124 Permit to Drill Page 10 40 0 Hazards and Contingencies ➢ Differential sticking could be a problem. The mud system will be approximately 140 psi over balance to the Kuparuk formation. Minimize the time the pipe is left stationary while running the liner. ➢ In the event additional weight is required to get the liner to TD, have 6 stands of weight pipe in the derrick. Reference RPs ❖ "Running and Cementing a Liner Conventionally' Job 10: DPC Perforate Well Critical Issues: ➢ The Kuparuk interval of the well will be TCP perforated prior to running the completion. After placing a KCL brine perf pill weighted to 9.4 ppg the well will be perforated across a 9.2 ppg EMW reservoir for an overbalance of ±100 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. ➢ The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach depth due to cement/fill. ➢ It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, Schlumberger perforating crew. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100 -ft below the rotary table. ➢ Contact Schlumberger to prepare for approximately 1000' of 2-%" Power Jet guns at 6 spf to be run on DP. Exact perforation depths will be provided after reviewing the LWD logs. Reference RPs: ❖ "Wireline Pressure Control SOP" ❖ "Alaska Wells Group Standard Operating Procedure: Perforating" ❖ Follow Schlumberger perforating practices and recommendations Job 12: Run 4-1/2" Completion Critical Issues: ➢ Keep in mind that the Kuparuk interval will be open during the running of the completion. Watch hole fill closely, verify no light fluids are introduced down hole and verify proper safety valves are on the rig floor while running this completion. ➢ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. ➢ Extreme care should be taken when running the completion to avoid damaging the 1 -wire associated with the down hole pressure gauge. Reference RPs: ❖ "Completion Design and Running" RP ❖ "Tubing Connections" RP L-124 Permit to Drill Page 11 0 Job 13: ND/NU/Release Rig Critical Issues: ➢ See Job 1 for adjacent well spacing. Identify hazards in a pre -move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ➢ Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs: ❖ "Freeze Protecting an Inner Annulus" RP L-124 Permit to Drill Page 12 L-124 Prop 9 5/8", 40.0#, L-80, BTC 3,194 HES 3 1/2" BHG w / I wire to surface8,338 Baker 7" X 3 1/2" 8,360 Premier Packer 8537 8,540 Baker HMC liner hngr, ZXPpkr, w/ 8,537 TBS Baker Whip stock, (Top of w indow) 8,687 8703 8,706 7", 26.0#, L-80, BTC -M H I 9,170 ed Completioff/, 40 4 1/2" X 3 1/2" tubing crossover 1,800 HES 3 112"'X nipple; I.D. = 2.813" Minimum ID = 2.813" TREE = 4 1/16" CNV WELLHEAD= FMC ACTUATOR = LEO KB. ELEV = 72.60' AMSL CB. ELEV = 48.30' AMSL KOP = 300' Max Angle = 930 @ 9,164' Datum MD = 8,646' Datum TV D = 6,498' GAS LIFT MANDRELS ST MD I TVD DEV I TYPE VLV LATCH FORT DATE 1 8290 62° MMG Dum BK -5 2 7086 5500 34° MMG Dum BK -5 3 6240 4800 34° MMG Dum BK -5 4 5393 4100 34° MMG DCK BK -5 5 4410 3400 48° MMG Dum BK -5 6 3214 2600 48° MMG Dum BK -5 7 1 2315 12000, 48° 1 MMG I Dum 1 BK -5 PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I Opn/Soz I DATE 8,315 HES 3 1/2"'X' nipple; I.D. = 2.813" 87425 HES 3 1/2"'X' nipple; I.D. =2.813" 8,445--H HES 3 1/2"'X' nipple; I.D. = 2.813" 9,455 Pup WPFW Tag 9,835 PupW/'RA'Tag 10,210 Pup W/'RA' Tag 0 0 0 PBTD --L10,881 J 4 1/2", 12.6 #, L-80 IBT-M liner 10,967 DATE REV BY PRUDHOE BAY UNIT WELL: L-124 PERMIT No: API No: 50-029- DATE REV BY COMMENTS 02/16/05 DEW Proposed Completion (Wp05) BP Exploration (Alaska) DATE REV BY COMMENTS DATE REV BY COMMENTS 02/16/05 DEW Proposed Completion (Wp05) PLANT � L15'00'00" 1 � ARID L -111i ■ L-114 ■ L -SD ■ L-121 ■ L-110 ■ L -SI ■ L-116 ■ L-109 ■ L -SL ■ L -PAD ■ N -L (NWE-1) ■ N -A (NWE-2) L / L-124 -113 L-1121 ■ L-02 / L-211 i L-122 L -115i ■ L-117 ■ L-118 swo soe 9(ID 51] VICINITY MAP LEGEND N.T.S. + AS—BUILT CONDUCTOR ■ EXISTING CONDUCTOR SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL _ __...... _., DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 5, 2004. N OTES 1. DATE OF SURVEY: JANUARY 5, 2004. 2. REFERENCE FIELD BOOK: W004-01 PAGES 04-05. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS L—PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS L—PAD OPERATOR MONUMENTS. ELEVATIONS ARE BP MSL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL L-01 ■ PLANT ■ L-200 GEODETIC L-107 ■ SKID 502 NO. COORDINATES COORDINATES POSITION DMS a BOX ELEV. OFFSETS L-124 L -108i ■ N= 10,000.09 70'21'01.897" 70.3505269' ■ L-123 2,521' FSL L-1051 ■ X= 583,025.79 = ■ L-1031 —149.3259142' L-106 ■ ❑ L -211i Y= 5,978,259.93 N= 10,000.02 70'21'02.080" 70.3505778' 48 5' ■ L-201 L-104 ■ E= 5,105.05 ■ L -119i —149.3253242' S -W ■ 3,816' FEL ■ L -210i L-102 ■ ■ L-120 swo soe 9(ID 51] VICINITY MAP LEGEND N.T.S. + AS—BUILT CONDUCTOR ■ EXISTING CONDUCTOR SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL _ __...... _., DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 5, 2004. N OTES 1. DATE OF SURVEY: JANUARY 5, 2004. 2. REFERENCE FIELD BOOK: W004-01 PAGES 04-05. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS L—PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS L—PAD OPERATOR MONUMENTS. ELEVATIONS ARE BP MSL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION DMS POSITION D.DD BOX ELEV. OFFSETS L-124 Y= 5,978,240.59 N= 10,000.09 70'21'01.897" 70.3505269' 48.3 2,521' FSL X= 583,025.79 E= 5,030.01 —149'19'33.292" —149.3259142' 3,889' FEL L -211i Y= 5,978,259.93 N= 10,000.02 70'21'02.080" 70.3505778' 48 5' 2,540' FSL X= 583,098.29 E= 5,105.05 —149'19'31.167" —149.3253242' 3,816' FEL REVISION F. Robert O I MEMO O 1�Y.11�U\U�\ �I IU�5 DRAWN. COTTON CHECKED: HACKLEI DATE: 1/08/0 DRAWING: FR804 WOL 02. JOB NO: SCALE: 1'= 130' u�w�¢�.�iwsic Vsssw T12N T11 N 0 by GPB WOA L—PAD SHEET AS -BUILT CONDUCTORS WELLS L-124 & L-211 i 1 OF t L-124PB1 (P5b Report Date: February 9, 2005 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: L -PAD I N -C Well: Plan L-124 (N -C) • Borehole: Plan L-124PB1 19 Ily UWIIAPI#: 50029 9-119 Survey Name I Date: L-124PB1 (P5b) I February 9, 2005 Tort I AND 1 DDI 1 ERD ratio: 127.170° 15741.56 it / 5.999 / 0.855 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 70.35052676, W 149.32591432 Location Grid WE YIX: N 5978240.500 ftUS, E 583025.800 ftUS Grid Convergence Angle: +0.63483527° Schlumberger Survey I DLS Computation Method: Minimum Curvature I Li Vertical Section Azimuth: 345.310° Vertical Section Origin: N 0.000 ft, E 0.000 ft TO Reference Datum: Rotary Table TO Reference Elevation: 72.60 ft relative to MSL Sea Bed I Ground Level Elevation: 44.10 ft relative to MSL Magnetic Declination: 24.517° Total Field Strength: 57608.284 nT Magnetic Dip: 80.811 ° Declination Date: April 05, 2005 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North -> True North: +24.517° Comments Measured Inclination Azimuth Sub -Sea TO TO Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude ,., ......�... Depth 300.00 0.00 330.00 Section Departure I 0.00 0.00 0.00 0.00 -30.00M 0.00 0.00 5978240.50 583025.80 ft de de ft ft ft ft ft ft de 1100 ft deg de 1100 ft de 1100 ft ftUS ftUS c.1 -4n AI 7n--C7G \n/!An Q09n4AQO Kit 0.00 0.00 asu.uv -fc.ov v.w v.vv v.vv V.VV U.w v.w - . -- ,., ......�... KOP Bid 1.5/100 300.00 0.00 330.00 227.40 300.00 0.00 0.00 0.00 0.00 0.00 -30.00M 0.00 0.00 5978240.50 583025.80 N 70.35052676 W 149.32591432 G1 332.60 0.49 330.00 260.00 332.60 0.13 0.14 0.12 -0.07 1.50 -30.00M 1.50 0.00 5978240.62 583025.73 N 70.35052709 W 149.32591488 Bid 2.5/100 400.00 1.50 330.00 327.39 399.99 1.26 1.31 1.13 -0.65 1.50 -30.00M 1.50 0.00 5978241.63 583025.13 N 70.35052986 W 149.32591963 500.00 4.00 330.00 427.27 499.87 5.89 6.11 5.29 -3.05 2.50 -30.00M 2.50 0.00 5978245.75 583022.69 N 70.35054121 W 149.32593910 600.00 6.50 330.00 526.84 599.44 14.71 15.26 13.21 -7.63 2.50 O.00G 2.50 0.00 5978253.63 583018.03 N 70.35056286 W 149.32597624 Cry 3.51100 700.00 9.00 330.00 625.92 698.52 27.72 28.74 24.89 -14.37 2.50 29.44G 2.50 0.00 5978265.23 583011.16 N 70.35059476 W 149.32603097 800.00 12.17 338.18 724.21 796.81 45.73 47.08 41.45 -22.20 3.50 21.40G 3.17 8.18 5978281.70 583003.14 N 70.35064001 W 149.32609454 900.00 15.48 342.97 821.30 893.90 69.53 70.96 64.01 -30.03 3.50 16.75G 3.31 4.79 5978304.16 582995.07 N 70.35070162 W 149.32615808 SV6 976.98 18.08 345.47 895.00 967.60 91.74 93.17 85.39 -36.03 3.50 14.35G 3.37 3.25 5978325.48 582988.83 N70.35076005 W 149.32620683 1000.00 18.86 346.09 916.83 989.43 99.03 100.46 92.46 -37.82 3.50 13.76G 3.40 2.68 5978332.53 582986.96 N 70.35077936 W 149.320 1100.00 22.27 348.29 1010.45 1083.05 134.13 135.58 126.72 -45.56 3.50 11.71G 3.41 2.20 5978366.69 582978.85 N 70.35087294 W 149.32 1200.00 25.71 349.92 1101.80 1174.40 174.68 176.23 166.64 -53.20 3.50 10.21G 3.44 1.64 5978406.52 582970.76 N 70.35098200 W 149.32634 1 1300.00 29.16 351.20 1190.54 1263.14 220.55 222.30 212.08 -60.73 3.50 9.08G 3.45 1.27 5978451.88 582962.73 N 70.35110615 W 149.32640731 1400.00 32.62 352.22 1276.34 1348.94 271.56 273.63 262.88 -68.11 3.50 8.20G 3.46 1.02 5978502.58 582954.79 N 70.35124492 W 149.32646723 1500.00 36.09 353.07 1358.89 1431.49 327.51 330.05 318.84 -75.31 3.50 7.50G 3.47 0.85 5978558.45 582946.97 N 70.35139780 W 149.32652572 1600.00 39.56 353.78 1437.87 1510.47 388.21 391.36 379.75 -82.32 3.50 6.94G 3.47 0.72 5978619.28 582939.29 N 70.35156420 W 149.32658259 1700.00 43.04 354.40 1512.98 1585.58 453.42 457.35 445.39 -89.09 3.50 6.47G 3.48 0.62 5978684.83 582931.79 N 70.35174351 W 149.32663762 SV5 1779.84 45.81 354.84 1570.00 1642.60 508.56 513.23 501.02 -94.32 3.50 6.16G 3.48 0.55 5978740.40 582925.94 N 70.35189551 W 149.32668010 1800.00 46.51 354.95 1583.96 1656.56 522.90 527.77 515.50 -95.62 3.50 6.08G 3.48 0.52 5978754.86 582924.49 N 70.35193507 W 149.32669060 End Cry 1846.67 48.14 355.18 1615.59 1688.19 556.71 562.08 549.69 -98.57 3.50 O.00G 3.48 0.50 5978789.01 582921.16 N 70.35202845 W 149.32671457 Base Perm 1935.69 48.14 355.18 1675.00 1747.60 622.04 628.38 615.75 -104.14 0.00 O.00G 0.00 0.00 5978855.00 582914.85 N 70.35220895 W 149.32675982 SV4 1980.65 48.14 355.18 1705.00 1777.60 655.02 661.86 649.12 -106.96 0.00 O.00G 0.00 0.00 5978888.33 582911.67 N 70.35230009 W 149.32678266 SV3 2332.80 48.14 355.18 1940.00 2012.60 913.41 924.13 910.46 -129.00 0.00 0.00G 0.00 0.00 5979149.39 582886.74 N 70.35301405 W 149.32696165 SV2 2565.07 48.14 355.18 2095.00 2167.60 1083.84 1097.12 1082.83 -143.54 0.00 O.00G 0.00 0.00 5979321.58 582870.29 N 70.35348497 W 149.32707970 WellDesign Ver 3.1 RT-SP3.03-HF5.00 Bid( do31rt-546 ) N-C\Plan L-124 (N-C)\Plan L-124PB1\L-124PB1 (P5b) Generated 2/9/2005 3:15 PM Page 1 of 3 SO Measured 48.74 305.78 2470.UU 248/.ou Vertical Along Hole 7438./7 -7/3.55 0.00 0.OoG 0.00 0.00 59/90//.00 562836.34 IV /8.35445/1/ W 149.32/323417 Comments 3194.45 Inclination Azimuth Sub Sea ND ND 1545.64 1565.86 NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude UG4 Depth 48.14 355.18 2705.00 2777.60 Section Departure 1761.21 -200.75 0.00 0.00G 0.00 0.00 5979999.22 582805.57 N 70.35533823 W 149.32754437 UG4A M. de de ft ft ft ft ft ft de 1100 ft de de 1100 k de 1100 ft ftUS ftUS N 70.35542937 W 149.32756723 SO 3U44.ou 48.74 305.78 2470.UU 248/.ou 7430.o9 7404.20 7438./7 -7/3.55 0.00 0.OoG 0.00 0.00 59/90//.00 562836.34 IV /8.35445/1/ W 149.32/323417 9-5/8" Csg Pt 3194.45 48.14 355.18 2515.00 2587.60 1545.64 1565.86 1549.92 -182.93 0.00 0.00G 0.00 0.00 5979788.15 582825.73 N 70.35476098 W 149.32739963 UG4 3479.17 48.14 355.18 2705.00 2777.60 1754.55 1777.91 1761.21 -200.75 0.00 0.00G 0.00 0.00 5979999.22 582805.57 N 70.35533823 W 149.32754437 UG4A 3524.12 48.14 355.18 2735.00 2807.60 1787.54 1811.39 1794.58 -203.56 0.00 0.00G 0.00 0.00 5980032.54 582802.39 N 70.35542937 W 149.32756723 UG3 4026.12 48.14 355.18 3070.00 3142.60 2155.88 2185.26 2167.13 -234.98 0.00 0.00G 0.00 0.00 5980404.69 582766.85 N 70.35644715 W 149.32782245 UGI 4745.41 48.14 355.18 3550.00 3622.60 2683.65 2720.96 2700.94 -280.00 0.00 O.00G 0.00 0.00 5960937.91 582715.92 N 70.35790545 W 149.32818819 Cry 3/100 4884.56 48.14 355.18 3642.86 3715.46 2785.75 2824.59 2804.20 -288.71 0.00 178.26G 0.00 0.00 5981041.07 582706.07 N 70.35818756 W 149.32825895 4900.00 47.68 355.20 3653.21 3725.81 2797.04 2836.05 2815.62 -289.67 3.00 178.24G -3.00 0.12 5981052.47 582704.98 N 70.35821875 W 149.32826676 Fault Crossing 4953.82 46.06 355.27 3690.00 3762.60 2835.73 2875.33 2854.76 -292.94 3.00 178.20G -3.00 0.13 5981091.57 582701.28 N 70.35832568 W 149.32829328 5000.00 44.68 355.33 3722.44 3795.04 2868.09 2908.19 2887.51 -295.63 3.00 178.15G -3.00 0.13 5981124.29 582698.23 N 70.35841516 W 149.328 Ma 5031.47 43.73 355.37 3745.00 3817.60 2889.70 2930.13 2909.38 -297.41 3.00 178.12G -3.00 0.14 5981146.13 582696.20 N 70.35847490 W 149.3283 2 5100.00 41.68 355.47 3795.36 3867.96 2935.45 2976.61 2955.71 -301.12 3.00 178.05G -3.00 0.15 5981192.41 582691.98 N 70.35860147 W 149.32835976 5200.00 38.68 355.64 3871.75 3944.35 2998.94 3041.12 3020.03 -306.12 3.00 177.92G -3.00 0.16 5981256.67 582686.27 N 70.35877718 W 149.32840040 5300.00 35.68 355.82 3951.41 4024.01 3058.37 3101.55 3080.29 -310.62 3.00 177.78G -3.00 0.19 5981316.87 582681.10 N 70.35894180 W 149.32843699 L-124 Sch Tgt 5322.79 35.00 355.87 3970.00 4042.60 3071.33 3114.73 3093.43 -311.58 3.00 178.45G -3.00 0.20 5981330.00 582680.00 N 70.35897772 W 149.32844474 Na 5328.88 34.82 355.88 3975.00 4047.60 3074.76 3118.22 3096.91 -311.83 3.00 178.446 -3.00 0.14 5981333.48 582679.71 N 70.35898722 W 149.32844678 End Cry 5346.59 34.29 355.90 3989.58 4062.18 3084.63 3128.26 3106.93 -312.55 3.00 O.00G -3.00 0.14 5981343.48 582678.88 N 70.35901459 W 149.32845263 OA 5516.54 34.29 355.90 4130.00 4202.60 3178.73 3224.00 3202.42 -319.39 0.00 O.00G 0.00 0.00 5981438.88 582670.99 N 70.35927546 W 149.32850819 OBf Base 5958.30 34.29 355.90 4495.00 4567.60 3423.35 3472.86 3450.64 -337.16 0.00 O.00G 0.00 0.00 5981686.87 582650.46 N 70.35995357 W 149.32865263 CM2 6345.60 34.29 355.90 4815.00 4887.60 3637.80 3691.03 3668.26 -352.74 0.00 O.00G 0.00 0.00 5981904.28 582632.47 N 70.36054809 W 149.32877927 CMI 7065.73 34.29 355.90 5410.00 5482.60 4036.56 4096.70 4072.89 -381.72 0.00 O.00G 0.00 0.00 5982308.53 582599.02 N 70.36165350 W 149.32901476 Cry 4/100 7225.68 34.29 355.90 5542.16 5614.76 4125.13 4186.81 4162.77 -388.15 0.00 -72.69G 0.00 0.00 5982398.32 582591.59 N 70.36189903 W 149.32906707 7300.00 35.27 350.99 5603.21 5675.81 4167.06 4229.18 4204.85 -393.01 4.00 -68.65G 1.33 -6.62 5982440.34 582586.27 N 70.36201399 W 149.32910655 7400.00 36.89 344.77 5684.05 5756.65 4225.83 4288.03 4262.35 -405.42 4.00 -63.62G 1.62 -6.21 5982497.69 582573.22 N 70.36217107 W 149.32920739 7500.00 38.81 339.05 5763.03 5835.63 4287.02 4349.36 4320.60 -424.52 4.00 -59.1 OG 1.92 -5.72 5982555.72 582553.48 N 70.36233020 W 149.32936252 7600.00 40.99 333.81 5839.77 5912.37 4350.33 4413.47 4379.32 -450.20 4.00 -55.08G 2.18 -5.24 5982614.15 582527.15 N 70.36249061 W 149.32957120 7700.00 43.38 329.04 5913.88 5986.48 4415.46 4480.59 4438.22 -482.36 4.00 -51.54G 2.39 4.78 5982672.68 582494.35 N 70.36265151 W 149.32983239 7800.00 45.95 324.68 5985.02 6057.62 4482.08 4550.86 4497.01 -520.82 4.00 48.44G 2.57 4.36 5982731.04 582455.24 N 70.36281212 W 149.33014483 THRZ 7873.20 47.93 321.73 6035.00 6107.60 4531.61 4604.34 4539.81 -552.86 4.00 -46.42G 2.71 -4.03 5982773.48 582422.73 N 70.36292904 W 149.3304 7900.00 48.68 320.69 6052.83 6125.43 4549.88 4624.35 4555.41 -565.40 4.00 -45.74G 2.77 -3.86 5982788.93 582410.02 N 70.36297165 W 149.33 8000.00 51.53 317.03 6116.98 6189.58 4618.52 4701.05 4613.13 -615.89 4.00 43.39G 2.85 -3.66 5982846.09 582358.90 N 70.36312933 W 149.33091715 8100.00 54.48 313.66 6177.16 6249.76 4687.66 4780.90 4669.89 -672.03 4.00 41.36G 2.96 -3.38 5982902.22 582302.14 N 70.36328439 W 149.33137325 8200.00 57.53 310.53 6233.07 6305.67 4756.98 4863.79 4725.42 -733.56 4.00 -39.60G 3.04 -3.13 5982957.06 582240.00 N 70.36343607 W 149.33187311 Kalubik 8231.96 58.51 309.57 6250.00 6322.60 4779.12 4890.90 4742.86 -754.31 4.00 -39.10(3 3.09 -2.99 5982974.27 582219.06 N 70.36348372 W 149.33204171 8300.00 60.64 307.60 6284.45 6357.05 4826.13 4949.57 4779.44 -800.17 4.00 -38.1 OG 3.13 -2.89 5983010.34 582172.80 N 70.36358364 W 149.33241428 K-1 8342.81 61.99 306.41 6305.00 6377.60 4855.60 4987.13 4802.05 -830.17 4.00 -37.53G 3.16 -2.80 5983032.60 582142.56 N 70.36364538 W 149.33265795 8400.00 63.82 304.85 6331.05 6403.65 4894.78 5038.04 4831.70 -871.55 4.00 -36.82G 3.19 -2.71 5983061.79 582100.86 N 70.36372637 W 149.33299412 8500.00 67.04 302.25 6372.63 6445.23 4962.58 5128.97 4881.93 -947.34 4.00 -35.74G 3.23 -2.60 5983111.18 582024.52 N 70.36386358 W 149.33360982 Top Kuparuk 8559.77 68.99 300.76 6395.00 6467.60 5002.58 5184.39 4910.89 -994.59 4.00 -35.18G 3.26 -2.50 5983139.60 581976.96 N 70.36394266 W 149.33399370 End Cry 8590.60 70.00 300.00 6405.80 6478.40 5023.02 5213.26 4925.49 -1019.50 4.00 O.00G 3.27 -2.45 5983153.92 581951.89 N 70.36398254 W 149.33419606 Kup C 8602.88 70.00 300.00 6410.00 6482.60 5031.13 5224.81 4931.26 -1029.50 0.00 O.00G 0.00 0.00 5983159.59 581941.83 N 70.36399830 W 149.33427729 L-124 Tgt 1 8690.60 70.00 300.00 6440.00 6512.60 5089.10 5307.23 4972.47 -1100.88 0.00 180.00G 0.00 0.00 5983200.00 581870.00 N 70.36411087 W 149.33485720 8700.00 69.81 300.00 6443.23 6515.83 5095.31 5316.06 4976.89 -1108.53 2.00 180.00G -2.00 0.00 5983204.33 581862.31 N 70.36412293 W 149.33491934 8800.00 67.81 300.00 6479.37 6551.97 5160.88 5409.30 5023.50 -1189.27 2.00 180.00G -2.00 0.00 5983250.05 581781.06 N 70.36425025 W 149.33557531 WellDesign Ver 3.1RT-SP3.03-HF5.00 Bld(do3lrt-546) N-C\Plan L-124 (N-C)\Plan L-124PB1\L-124PB1 (P5b) Generated 2/9/2005 3:15 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub Sea ND TVD Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude N 70.36440955 W 149.33639610 Depth 2.00 180.00G -2.00 0.00 Section Departure 581622.11 N 70.36449933 W 149.33685868 2.00 180.00G -2.00 0.00 5983348.08 581606.83 ft de de R ft ft ft ft ft d 1100 ft d de 1100 ft de 100 ft ftUS ftUS -2.00 0.00 ODUUMV 00.0.1 3VU.UV Do 10./0 OD`V 1.3D D44D.D4 GDV I.41 GVUU.40 -1400.00 LCU I KUP B 8927.18 65.27 300.00 6530.00 6602.60 5242.92 5525.96 5081.83 -1290.30 9000.00 63.81 300.00 6561.30 6633.90 5289.16 5591.70 5114.71 -1347.24 9019.57 63.42 300.00 6570.00 6642.60 5301.49 5609.23 5123.47 -1362.42 9100.00 61.81 300.00 6606.99 6679.59 5351.72 5680.65 5159.18 -1424.27 TD / 7" Csg Pt 9169.57 60.42 300.00 6640.60 6713.20 5394.56 5741.56 5189.64 -1477.02 Legal Description: Northing (Y) MUST Easting (XI MUST Surface: 2520 FSL 3889 FEL S34 T12N R11E UM 5978240.50 583025.80 Schrader Target : 334 FSL 4195 FEL S27 T12N R11 E UM 5981330.00 582680.00 Kuparuk Target : 2213 FSL 4980 FEL S27 T12N R11 E UM 5983200.00 581870.00 BHL : 2430 FSL 76 FEL S28 T12N R11 E UM 5983412.97 581491.51 L.VV IoV.VVV -G.VV V.VV JJVJGJJ.- JVII VV.JV 1`I IV.J -, JII vv 1'tJ.JJ000Gv< 2.00 180.00G -2.00 0.00 5983307.25 581679.40 N 70.36440955 W 149.33639610 2.00 180.00G -2.00 0.00 5983339.48 581622.11 N 70.36449933 W 149.33685868 2.00 180.00G -2.00 0.00 5983348.08 581606.83 N 70.36452327 W 149.33698205 2.00 180.00G -2.00 0.00 5983383.10 581544.60 N 70.36462079 W 149.33748451 2.00 O.00G -2.00 0.00 5983412.97 581491.51 N 70.36470397 W 149.33791312 WellDesign Ver 3.1RT-SP3.03-HF5.00 Bld(do31rt-546 ) N-C\Plan L-124 (N-C)\Plan L-124PB1\L-124PB1 (P5b) Generated 2/9/2005 3:15 PM Page 3 of 3 by 0 Schlumbepoep WELL L-124PB1 (P5b) Prudhoe Bay Unit - WOA 3TRD"DRE L -PAD Magnetw Paramatxa Surlaca Location NPD2] Almke SMte Banes, Zore O4, U3 Feet Miscepareoua Motlel: EGGM 2004 Db: 80.811' Date: OP. 5,2005 Lal: 11]0211.898 N- w 59'!8240.50 flUS G. Cony: 111.6348352]° stilt N -c T R -t Rotary T—(T2b0ea5ov-MSL) Mag Dec. X24.51]° Fs: 5]805.3 nT Lm: W14919 33.292 E_aB 583025.80 flus Srale Fact: 0.99990]830fi RMn: L-12 m (P5) SMD— F—d O9, 2005 0 1000 2000 3000 4000 5000 0 1000 2000 F 3000 0 0 0 C 0) f0 U) 4000 5000 6000 7000 tTE COP Bld 1.51100 _.. _.. _.. _.. _ .. _..r............... lid 2.51100 Cry 3.51100 Csg Pt ICry 31100 Fault Crossing ..._.._...�.._.._.._.._......_ _,. ._ .._.._. _.._......_... L-124 Sch Tgt ................ _r_.. .._... End Cm _.._.._..:.._.._.._.._.._ ........ 2t3cfi'fiyf _.._... _.._.._..i..—.._.._.._..—.._.._.,_.._ .._......_.._.. 2 .............:....................................E...,.............,.,...., ,.. 41100 End Cry • `•` 9ebp�feawu _..i.._.._.._.._..iCD)KupB` L-124 Tgt 1; 1000 2000 3000 4000 5000 Vertical Section (ft) Azim = 345.31', Scale = 1(in):1000(ft) Origin = 0 N/ -S, 0 E/ -W 0 1000 2000 3000 4000 5000 6000 7000 ' by 0 Schlumberlgep L-124PB1 (P5b) FlE Prudhoe Bay Unit - WOA S RUCNRE L -PAD Megrelk Parameters T: uOam LocaBon N V A- Shce Plasm, Z m N. US Fa Mncel--N MaOel: BGGM 2004 D"q: 811.611' pale: APA 0S. 2005 Lat N70211.856 NaMtieg: 5578240.-S GIiE Cwrv: e0.6348352T SbL -C NDRef. Rglary Tads (7260fl aDma MSL) Mag pec: X24.517' FS: 57608.3 nT Lon: W 14S 19 33.282 Ease 583025.80 M1S Scale F.. -.78306 PNn: 1.124.1(P551 Sry pate: Fed 0S, 2005 -3200 -2400 -1600 -800 0 800 5600 4800 4000 Z 3200 s O O 00 C 0) 2400 In U) v v v 1600 800 n L-124 Flt 2 6450ss TD 17" Csg (P5b) L-144 Tgt 1 End Cry C7V 4/100 End Cry L-024 Sch Tgt Fault Crossin L-124:FIt 1 3690ss CM31100 P End Cm Cm 3.51100 Bid 2.51100 ...................... ............ 4 ...... ........... .............,..,. ....,........................,.,"............. KOP Bid 1.51100 RTE 3200 -2400 -1600 -800 0 80 <<< W Scale= 1(in):800(ft) E >>> 5600 4800 4000 3200 2400 1600 800 A • BP Alaska 0 Anticollision Report • BP Alaska 0 Anticollision Report Target: L-124 Tgtl Site: PB L Pad Drilling Target Conf.: 95% Based on: Planned Program Description: Map Northing: 5983200.00 ft Map Easting : 581870.00 ft Latitude: 70021150.799N Polygon X ft 1 -148.34 2 151.67 3 298.35 4 -151.67 Target: L-124 Tgtl IN 0 O M N — CD CCO O� LD .0 CI Well: Plan L-124 (N -C) Based on: Planned Program Vertical Depth: 6440.00 ft below Mean Sea Level Local +N/ -S: 4972.46 ft Local +E/ -W: -1100.88 ft Longitude: 149'20'05.486W Yft Map Eft Map Nft 151.67 581720.00 5983350.00 148.34 582020.00 5983350.00 -153.33 582170.00 5983050.00 -148.34 581720.00 5983050.00 IN 0 O M N — CD CCO O� LD .0 CI L-124 (P5b Schlumberger Report Date: February 9, 2005 Survey I DLS Computation Method: Minimum Curvature / Lubmski Client: BP Exploration Alaska Vertical Section Azimuth: 262.660° Field: Prudhoe Bay Unit - WOA Structure I Slot: L -PAD / N -C ®qtwdY Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table Well: Plan L-124 (N -C) • ;Uff TVD Reference Elevation: 72.60 ft relative to MSL Borehole: Plan L-124 Sea Bed I Ground Level Elevation: 44.10 ft relative to MSL UWVAPI#: 50029 Magnetic Declination: 24.517° Survey Name 1 Date: L-124 (P5b) / February 9, 2005 Total Field Strength: 57608.284 nT Tort I AHD 1 DDI I ERD ratio: 164.613° / 7572.01 ft / 6.317 / 1.150 Magnetic Dip: 80.811' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 05, 2005 Location LatlLong: N 70.35052676, W 149.32591432 Magnetic Declination Model: BGGM 2004 Location Grid N/E Y/X: N 5978240.500 ftUS, E 583025.800 ftUS North Reference: True North Grid Convergence Angle: +0.63483527° Total Corr Mag North -> True North: +24.517° Grid Scale Factor: 0.99990783 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub -Sea TVD TVD Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude W 149.33494029 Depth 79.96 -64.60G 8950.00 82.46 Section Departure 85.00 N 70.36414115 9050.00 87.57 90° Pt 9097.00 90.00 -9.45 9100.00 90.15 k de de ft ft R ft it ft de 1100 ft de de 1100 ft de 1100 tt ftus ftuS 4.73 -9.07 IOp vvnipSIOCK 60`JU.UU IV.UV Base Whipstock 8703.00 71.34 KOP Cry 10/100 8715.00 71.34 8750.00 72.87 10.39 8800.00 75.15 581859.71 8850.00 77.52 W 149.33494029 8900.00 79.96 -64.60G 8950.00 82.46 5983210.86 9000.00 85.00 N 70.36414115 9050.00 87.57 90° Pt 9097.00 90.00 -9.45 9100.00 90.15 9150.00 92.74 JUV.UV 04JU.OV 001 L.4V 400.1.7 0JU0.Of 4.7r4.IV -1 IVV.4V 298.32 6444.10 6516.70 466.01 5318.94 4978.17 -1111.11 298.32 6447.94 6520.54 475.25 5330.31 4983.56 -1121.12 295.01 6458.69 6531.29 502.85 5363.61 4998.50 -1150.88 290.38 6472.47 6545.07 544.46 5411.67 5017.03 -1195.21 285.85 6484.29 6556.89 588.31 5460.25 5032.12 -1241.37 281.40 6494.06 6566.66 634.09 5509.29 5043.65 -1289.02 277.01 6501.71 6574.31 681.45 5558.69 5051.55 -1337.78 272.68 6507.17 6579.77 730.01 5608.39 5055.74 -1387.29 268.38 6510.41 6583.01 779.42 5658.28 5056.20 -1437.16 264.36 6511.41 6584.01 826.30 5705.27 5053.22 -1484.04 264.10 6511.41 6584.01 829.30 5708.27 5052.92 -1487.03 259.82 6510.15 6582.75 879.26 5758.25 5045.93 -1536.51 End Cry 9164.42 93.48 258.58 6509.37 6581.97 893.64 5772.65 5043.24 -1550.65 Fault Crossing 10200.00 93.48 258.58 6446.54 6519.14 1924.69 6806.32 4838.56 -2563.86 TD / 4-1/2" Lnr 10967.11 / ' 93.48 258.58 6400.00 6472.60 2688.44 7572.01 4686.95 -3314.39 Legal Description: Northing (Y) MUS] Eastina (X) MUST Surface: 2520 FSL 3889 FEL S34 T12N R11E UM 5978240.50 583025.80 TD / BHL : 1926 FSL 1914 FEL S28 T12N R11 E UM 5982890.00 579660.00 V.UV -OV.VVV V.VV U.VV UDOJ IUU./J JOIOI VRV IV 1V.-1 IV IV VY I-- 16.00 1 O.00G 10.39 -12.85 5983205.58 581859.71 N 70.36412642 W 149.33494029 0.00 -64.60G 0.00 0.00 5983210.86 581849.65 N 70.36414115 W 149.33502161 10.00 -63.58G 4.37 -9.45 5983225.47 581819.72 N 70.36418196 W 149.33526339 10.00 -62.31G 4.55 -9.26 5983243.51 581775.19 N 70.36423255 W 149.33562354 10.00 -61.23G 4.73 -9.07 5983258.08 581728.87 N 70.36427375 W 149.33599857 10.00 -60.36G 4.88 -8.90 5983269.09 581681.11 N 70.36430525 W 149.33638561 10.00 -59.69G 5.00 -8.77 5983276.44 581632.27 N 70.36432679 W 149.33678173 10.00 -59.22G 5.08 -8.66 5983280.08 581582.72 N 70.36433822 W 149.33718391 10.00 -58.94G 5.14 -8.60 5983279.99 581532.85 N 70.36433945 W 149.33758908 10.00 -58.86G 5.17 -8.56 5983276.50 581486.00 N 70.36433130 W 149.337 10.00 -58.86G 5.17 -8.56 5983276.16 581483.02 N 70.36433047 W 149.337 10.00 -58.96G 5.17 -8.57 5983268.63 581433.63 N 70.36431135 W 149.3383 10.00 O.00G 5.15 -8.58 5983265.77 581419.52 N 70.36430397 W 149.33851100 0.00 O.00G 0.00 0.00 5983049.91 580408.74 N 70.36374407 W 149.34674118 0.00 O.00G 0.00 0.00 5982890.00 579660.00 N 70.36332907 W 149.35283742 WellDesign Ver 3.1 RT-SP3.03-HF5.00 Bld(do31 rt -546) N-C\Plan L-124 (N-C)\Plan L-1241-124 (P5b) Generated 2/9/2005 3:43 PM Page 1 of 1 CD M C 0) (0 W it 6300 6600 6900 by Schlumbepoep WELL L-124 (P5b) FIELD Prudhoe Bay Unit - WOA S1RUCTU� L -PAD Ma9ndk Paramelero Sunc�e Locatlon MD27 Alaska S— Planes, Zone D4, US Feel Mismpamoua M..I; BGGM2W4 Dip: 80.011° Dale: ApM 05, 2005 Lel: N)0211... NOAbiN: 5818240.WWS GM Com:..6348362]° Sld: N -C WDW ftWq Table(]2.Wftabove MSL) Mab Dec: 929.51]° FS: 5]606.3 nT Lon: .148 18 33 282 EmON. 583825.80 #US Scale Fed: 099980]8308 PMn: L-129IP5h) Srvy Date: Febmary 09, 2005 300 600 900 1200 1500 1800 2100 2400 2700 LCU / Kup B 300 600 ock ipstock TD 14-112' Lnr .._.._.._.._..............».:_.._....................... s................... ........... ......... ................................................. ................... ._.. ..................... .»,.» 101100 Fault Crossing .,_.._.._..».._.._......_.............°........._......,...z.._.._.._.._.._.._.._.._.._i°_.,_,..°.._...............,..:....-..... I .».._.._..» _ ....._.......... _....,._.._..» . ..4.�P 12 � 4Upewk•° Kup C ._.._ _.._.._.._.._.._.._.._.._.,.._.._.._.._.._.._.._.._........... ._.._....._.._.._.._.._ _,._.._.._„........ ._.._.................... .._.,_ _.._ I fnd Cry 124PB1-(P5) ......... i ..................................... L.................,.......,......... i ....... .........,,......<.<...,.....i.....................,....,.,..,....?.............<<...,............,,,..i.«...........<. <...,.,.... <...,,,,.L........ 900 1200 1500 1800 2100 2400 2700 Vertical Section (ft) Azim = 262.66°, Scale = 1(in):300(ft) Origin = 0 N/ -S, 0 E/ -W 6300 6600 6900 5400 A A 5100 bpi 01, Schiumber er L-124 (P5b) Prudhoe Bay Unit - WOA B RDDTURE L -PAD Magnetic Parametera Surtace Location NAD27 Alaska Slate %ane,— 04, US FeM Miscellaneous ,I: BGGM 2000 Dip: 60.611' D—ApM 05, 2005 Let "121 1.696 NI -1: 597621.11-8 GII C—:a0.6346352T SIM: N -C TVD Ref: Rotary Table (72.60 fl above MSL) Mag Dec: Q4.517' FS: 5]609.3 nT Lon: W149 19 33.292 EeMi SS3025.a0 *US Scale Fad: 0.99990]6306 Plan: L-124 (P5b) SMD.— 09,2005 le: -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 C 4800 CnU J V V V 4500 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 <<< W Scale= 1(in):300(ft) E >>> (P5) BP Alaska Anticollision Report Company iswo p qq1!1,gi,q � e 11 w k 4 Ye 2(9M015 Timer j J} Page_Al. 1 e, I -*Pad m� Co-d1� t 12eferenee. hell. Pian '-I ), True Nrtl t Pian L-12 (h}-C)Verti4 ry( 1NIn 11 9er,�nee_ L 124 Plan ht G' j -Pian L-i2r Db Ease. �= NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 8690.00 to 10967.11 ft Scan Method: Trav Cylinder North Maximum Radius: 10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/26/2004 Validated: No Version: 5 Planned From To Survey Toolcode Tool Name ft ft 28.50 8690.00 Planned: Plan #5 V2 (0) MWD+IFR+MS MWD + IFR + Multi Station 8690.00 10967.11 Planned: Plan #5 V2 BLIND Blind drilling Casing Points MD 1VI 116k i Name- ff it ft in __. 3321.82 2672.60 9.625 12.250 9 5/8" 8630.00 6491.88 7.000 8.750 7" 11204.33 0.00 4.500 6.125 4 1/2" Summary Vel Ileferc cc �I -N6-Go 6-1 well �VeBpathiiancc Arca aTWAg .. ft ✓ al�i e �m. PB L Pad L-01 L-01 V14 Out of range PB L Pad L-02 L-02 V1 10963.29 8100.00 3536.19 901.57 2634.62 Pass: Major Risk PB L Pad L-02 L -02A V5 10950.60 7350.00 3479.81 893.90 2585.90 Pass: Major Risk PB L Pad L-02 L-02PB1 V21 10963.29 8100.00 3536.19 901.64 2634.55 Pass: Major Risk PB L Pad L-101 L-101 V4 Out of range PB L Pad L-102 L-102 V2 Out of range PB L Pad L-102 L-102PB1 V10 Out of range PB L Pad L-102 L-102PB2 V2 Out of range PB L Pad L-103 L-103 V23 Out of range PB L Pad L-104 L-104 V7 Out of range PB L Pad L-105 L-105 V4 Out of range PB L Pad L-106 L-106 V14 Out of range PB L Pad L-107 L-107 V14 Out of range PB L Pad L-108 L-108 V18 Out of range PB L Pad L-109 L-109 V12 Out of range PB L Pad L-110 L-110 V11 10490.89 6650.00 8873.09 575.97 8297.12 Pass: Major Risk PB L Pad L-111 L-111 V24 Out of range PB L Pad L-112 L-112 V8 10940.89 4600.00 5099.85 873.12 4226.73 Pass: Major Risk PB L Pad L-114 L-114 V15 10955.26 6350.00 4085.31 892.05 3193.26 Pass: Major Risk PB L Pad L-115 L-115 V7 9987.39 8435.00 1447.22 337.50 1109.72 Pass: Major Risk PB L Pad L-116 L-116 V10 Out of range PB L Pad L-117 L-117 V11 Out of range PB L Pad L-118 L-118 V9 Out of range PB L Pad L-119 L-119 V9 Out of range PB L Pad L-120 L-120 V8 Out of range PB L Pad L-121 L-121 V14 10491.54 4250.00 8361.44 580.99 7780.45 Pass: Major Risk PB L Pad L-121 L -121A V1 10499.56 4400.00 8418.53 590.32 7828.21 Pass: Major Risk PB L Pad L-122 L-122 V5 10967.34 4250.00 5246.50 890.07 4356.43 Pass: Major Risk PB L Pad L-200 L-200 V7 8716.43 9600.00 2350.17 95.56 2254.62 Pass: Major Risk PB L Pad L-200 L-20OLl V3 8752.66 9650.00 2460.08 94.19 2365.89 Pass: Major Risk PB L Pad L-200 L-2001-2 V6 8757.26 9650.00 2503.66 93.69 2409.97 Pass: Major Risk PB L Pad L-201 L-201 V6 Out of range PB L Pad L-201 L-201 L1 V9 Out of range PB L Pad L-201 L-201L1PB1 V10 Out of range PB L Pad L-201 L-201 L2 V5 Out of range PB L Pad L-201 L-201 L3 V2 Out of range PB L Pad L-201 L-201L3PB1 V6 Out of range PB L Pad L-201 L-201PB1 V12 Out of range PB L Pad L-201 L-201 P62 V3 Out of range PB L Pad L-210 L-210 V6 Out of range PB L Pad L-210 L-210PB1 V8 Out of range PB L Pad L-211 L-211 V6 10952.25 8950.00 2473.35 884.67 1588.69 Pass: Major Risk BP Alaska Anticollision Report Summary PB L Pad L-211 L-211PB1 V6 10957.82 7000.00 3078.67 873.12 2205.55 Pass: Major Risk PB L Pad L-216 L-216 V6 Out of range PB L Pad NWE1-01 L-100 V2 10963.21 4150.00 6983.11 930.86 6052.25 Pass: Major Risk PB L Pad NWE1-01 NWE1-01 V5 10963.21 4150.00 6983.11 930.86 6052.25 Pass: Major Risk PB L Pad Plan L-03 (S -O) Plan L-03 V3 Plan: Pla Out of range PB L Pad Plan L-113 (N -B) Plan L-113 V5 Plan: PI 10936.95 4350.00 5303.52 875.02 4428.49 Pass: Major Risk PB L Pad Plan L-123 (S -U) Plan L-123 V3 Plan: PI Out of range PB L Pad Plan L-124 (N -C) Plan L-124PB1 V2 Plan: 8700.00 8700.00 0.15 0.00 0.15 Pass: NOERRORS PB L Pad Plan L-202 (N -N) Plan L-202 V1 Plan: PI Out of range PB L Pad Plan L-202 (N -N) Plan L-2021-1 OBb V3 PI Out of range PB L Pad Plan L-202 (N -N) Plan L-2021-2 OBa V3 PI Out of range PB L Pad Plan L-202 (N -N) Plan L-2021-3 OA V3 Pla Out of range PB L Pad Plan L-203 (N -Q) Plan L-203 V4 Plan: PI Out of range PB L Pad Plan L-212 (N -O) Plan L-212 V8 Plan: PI Out of range PB L Pad Plan L-212 (N -O) Plan L-212PB1 V4 Plan: 8715.00 9250.00 3747.97 122.55 3625.42 Pass: Major Risk PB L Pad Plan L-214 (S -W) Plan L-214 V1 Plan: PI Out of range Site: PB L Pad Drilling Target Conf.: 95% Description: Map Northing: 5983200.00 ft Map Easting : 581870.00 ft Latitude: 70021150.799N X ft -367.46 -2211.84 -2215.17 -370.79 0 0 0 0 0 0 LD c� CO M I m i c� i Target: L-124 Poly Well: Plan L-124 (N -C) Based on: Planned Program Vertical Depth: 6440.00 ft below Mean Sea Level Local +N/ -S: 4972.46 ft Local +E/ -W: -1100.88 ft Longitude: 149'20'05.486W Y ft Map E ft Map N ft 234.11 581500.00 5983430.00 -135.52 579660.00 5983040.00 -435.53 579660.00 5982740.00 -65.90 581500.00 5983130.00 5600 5200 - x-800 4-x-00 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. 0 TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME p� /- /Z y PTD# Z�70'5 -- O Development Exploration IF Service Stratigraphic CHECK WHAT ADD-ONS " APPLIES OPTIONS MULTI The permit is for a new wellbore segment of LATERAL existing well Permit No, API No. (If API number Production. should continue to be reported as last two. (2) digits a function•of the original API number stated are between 60-69) above. PILOT DOLE In accordance witb ' 20 AAC 25.005(f), all (PH) records, data and logs acquired. for the pilot bole must be clearly differentiated 'in both name (name on permit plus PH) and API number (50_= 70/80) from records., data and logs acquired for well (name on permit). SPACING The permit is approved subject -to full EXCEPTION compliance with 20 AAC 25.955. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing " exception. (Company Name) assumes the liability of any protest to the spacing .exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 0 Field & Pool PRUDHOE BAY, BOREALIS OIL - 640130 Well Name: PRUDHOE BAY UN BORE L-124 Program DEV Well bore seg ❑ PTD#: 2050430 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / 1 -OIL GeoArea Unit On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached_ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - Yes - _ - _ _ _ ------- - ------------------------------------------------------------- 2 Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - - - - _ _ _ - _ _ ------------------------------------------------------------ 3 Unique well-nameandnumber--------------------------- Yes 4 Well -located i n - a _defined _ p o o I - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes ------------------------ 5 Well located proper distance from drilling unit_boundary------------ - - - - - - - - - Yes _ _ _ _ _ _ - - - - - _ _ - _ _ _ _ _ - - _ ------------------------------------ 6 Well located proper distance from other wells_ Yes ------------------------------------------------------------- 7 Sufficient acreage available in -drilling unit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ - - - - - _ - _ _ _ _ _ - _ - - - - - - _ - _ - - - _ _ - - 8 -If-deviated, is -wellbore plat_included - - - - - - - - - - - - - Yes 9 Operator only affected party ____________-------------------- Yes --------__ 10 Operator has -appropriate_ bond in -force .---------------------------------- es-------------- - --------------------------------------------------------- 11 Permit can be issued without conservation order_ _ _ Yes ---------------------------------------------- Appr Date 12 Permit_can be issued without administrative approval - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - _ - - - - - - _ _ . RPC 3/22/2005 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and -strata authorized by Injection Order # (put lO# in -comments) -(For- NA- - - - - - - - - - - - - - - - 15 All wells -within 1/4 -mile area_of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ - - _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ - - ------------------------------------- 16 Pre -produced injector: duration -of pre production Less than 3 months_ (For -service well only) _ _ NA- - - - - - - - - - - - - - - - - - - - - ------------------------------------------------------- 17 ACMP_Finding of Consistency has been issued_ for this project- - - - - - - - - - - - - - - - - - - - NA_ _ _ - - _ _ Engineering 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ - - - 29'x 34"_@ 109'._ - - ------------------------------------------------------ 19 Surface casing_protectsall_knownUSDWs- - _ _ _ .. - - - - - - - - - - - - -- - - - - - -- - - Yes - - - - - - _ - -- - -- - _ 20 CMT_vol_ adequate -to circul_ate_on -conductor & surf_csg - - - - - - - - - - - - - - - - - - - Yes - _ _ _ _ _ _ Adequate excess, _ _ _ - - - - - - - _ _ _ _ _ 21 CMT_v_ol adequate -to tie-in long string to surf csg- - - - - - - - - - - - - - - - - - - - - - - - - - - No_ - _ . 22 CMT will coverall known -productive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ ---------------------------------------------------------------- 23 Casing designs adequate for C, T, B &_ permafrost- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate -tan _kage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - _ Nabors_9_ES- - - - - - _ - _ _ _ _ _ --------------- 25 If_a_re-drill, has_a 1.0-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - - New well, _ - - - - - - _ - - _ - _ - _ - - - - - - - - _ _ - - - - _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation -proposed- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ ------------------------------------- 27 If_diverterrequired,does---- r - ---ions ------------------- -------------Yes ------------------------------------------------------------------- Appr Date 28 Drilling fluid program schematic_& equip -list -adequate - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ _ Max MW_11.0_ppg._ _ _ _ _ _ _ _ - - - - - - _ _ _ _ _ _ _ _ - - _ WGA 3/22/2005 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - - - _ - - _ _ _ _ _ _ 30 BOPE_press rating appropriate; test to -(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ - Test to 3500 psi. _MSP 2697 psi._ ------------------------------------------- 31 Choke_manifoldcompliesw/API_RP-53(M_ay84)_______________________ Yes______________________ -------------------------------------------------- 32 Work will occur without operation shutdown_ - - - - _ - _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - 33 Is presence_ ofH2Sgas. probable---------------------------------- No NotanH2Spad.---------------------------------------------------------- 34 Mechanical -condition of wells within AOR verified (For service well only) - - - - - - - _ NA_ - - - - - - - Geology 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - --------- - - Yes - - - _ _ _ _ _ 36 Data_p_resented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ Appr Date 37 SeismiC_analysls of shallow gas -zones_ _ _ _ _ _ _ . - - - - - - - - - - - - - - - - - - - - NA_ - _ _ _ _ _ _ - - - - - - _ _ - - - - - - - RPC 3/22/2005 38 Seabed conditionsurvey_(ifoff_-shore)___________________________________N_A____ _ _ _ _ - _ _ _ - - - - _ - - - - - - - - - - - - --------------------- ----------------------- 39 - Contact name/phone-for-weekly weekly progress_reports [exploratory only]_ _ NA_ Geologic Engineering i Commissioner: Date: Commissioner: Date m is ' r i�t 0