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Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/01/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231101 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 10/10/2023 AK E-LINE Perf BRU 241-23 50283201910000 223061 10/21/2023 AK E-LINE Plug/Perf BRU 242-04 50283201640000 212041 10/13/2023 AK E-LINE Perf/PL KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/Perf MPU L-62 50029236850000 220059 10/18/2023 HALLIBURTON MFC24 PBU 06-20B 50029207990200 223075 10/19/2023 HALLIBURTON RBT PBU W-26A 50029219640100 199081 12/16/2022 AK E-LINE CBL Please include current contact information if different from above. T38113 T38113 T38114 T38115 T38116 T38117 T38118 11/1/2023 PBU W-26A 50029219640100 199081 12/16/2022 AK E-LINE CBL Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.01 14:36:12 -08'00' By James Brooks at 4:05 pm, Jan 04, 2023 Abandoned 12/15/2022 JSB RBDMS JSB 011123 xG DSR-1/30/23MGR28JULY2023 1.4.2023 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: 2023.01.04 14:35:48 -09'00' Monty M Myers WELL NAME: W-26A / AL1 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 10333' 29 Bbls Cement 10264' - 10269' Tubing Punch 4700' 276 Bbls Cement 4526' Cut & Pull Tubing 2871' Cut 9-5/8" Casing 1410' Cut & Pull 9-5/8" Casing 1170' Set CICR 1140' Set Whipstock ACTIVITYDATE SUMMARY 11/29/2022 T/I/O = 280/600/Vac. Temp SI. T & IA FL (OE request). AL & Flowline disconected, WH removed. T FL @ 964'. IA FL @ 1610'. SC, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 12/1/2022 ***WELL S/I UPON ARRIVAL*** (pre- SET 4 1/2" X-CATCHER IN X-NIPPLE @ 10,604' MD PULLED RK-LGLV'S FROM STA #5 @ 6,774' MD & STA #6 @ 3,843' MD SET RK-DGLV IN STA #6 @ 3,843' MD ATTEMPTED TO SET RK-DGLV IN STA #5 @ 6,774' MD (tray hitting pocket) ***CONT WSR ON 12/2/22*** 12/2/2022 ***CONT WSR FROM 12/1/22*** (sidetrack) SET RK-DGLV IN STA #5 @ 6,774' MD PULLED BK-S/O FROM STA #1 @ 10,527' MD PULLED BK-LGLV FROM STA #2 @ 9,619' MD ***LAYED DOWN DUE TO WINDS, CONT WSR ON 12/3/22*** 12/3/2022 Assist S/L (SIDETRACK) Pumped 84.8 bbls 40* crude down IA to take IA to 1502 psi. IA lost 32 psi in 10 mins PT pass. ***Job Cont to 12-04-2022 WSR*** 12/3/2022 ***CONT WSR FROM 12/2/22*** (sidetrack) PULLED BK-LGLV FROM STA #3 @ 8,674' MD SET BK-DGLV'S IN STA #3 @ 8,674' MD, STA #2 @ 9,619' MD, STA #1 @ 10,527' MD LRS PERFORMED PASSING PRESSURE TEST ON IA TO 1500psi (see lrs log) ***CONT WSR ON 12/4/22*** 12/3/2022 Assist S/L (SIDETRACK) T/I/O= 12/4/2022 ***Job Cont from 12-03-2022 WSR*** (SIDETRACK) Pumped 2 bbls 60/40 meth and 290 bbls 140* 1% KCL down Tbg for injectivity test. Got ~640 psi @ 1 bpm, ~850 psi @ 2 bpm, ~1150 psi @ 3 bpm, ~1400 psi @ 4 bpm and ~1740 psi @ 5 bpm for step rate. Freeze protected Tbg w/ 20 bbls crude and 18 bbls DSL. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 12/4/2022 ***CONT WSR FROM 12/3/22*** (sidetrack) PULLED EMPTY 4 1/2" X-CATCHER FROM 10,604' MD ***WELL LEFT S/I UPON DEPARTURE, LRS IN CONTROL OF WELL UPON DEPARTURE*** 12/5/2022 T/I/O=Vac/0/0. Pre CDR2. RD4" CIW upper tree, RU SV to MV, Torqued to API specs. Pressure tested to 5000 psi. (Pass) ***Job Complete*** Final WHP's Vac/0/0. RDMO 12/6/2022 Heat DSL transport to 90* T/I/O=100/317/0 (Assist Cement Crew) PT 3500, Final T/I/O=935/311/0 Objective: Reservoir P&A pre side track Pump 29 bbls of cement and displace with 157bbl of warm diesel. Est TOC 10658'. Foam ball depth 10329'. RDMO. ***Complete*** 12/7/2022 T/I/O= 287/342/0. LRS 72 Assist Slckline (SIDETRACK). MIT-T to 2250 psi PASSED at 2385 psi (2500 psi max applied pressure). TBG lost 87 psi during the first 15 minutes and 30 psi during the second 15 minutes. TBG lost 117 psi during the 30 minute test, Pumped 2.04 bbls of 22*F diesel. Bled back 3 bbls to final T/I/O= 257/339/0. AOGCC (Austin McCloud) MIT-T to 2500 psi PASSED at 2532 psi. (2650 psi max applied pressure). TBG lost 90 psi during the first 15 minutes and 28 psi during the second 15 minutes. TBG lost 118 psi during the 30 minute test. Pumped 2.9 bbls of 22*F diesel to achieve test pressure. Bled back 2.8 bbls to Final T/I/O= 276/340/0. Daily Report of Well Operations PBU W-26A / AL1 Daily Report of Well Operations PBU W-26A / AL1 12/7/2022 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(tubing punch) PRESSURE TEST 300L/2500H. TAG TOC AT 10,333' MD. PUNCH TUBING FROM 10264'-10269'. 2' BELOW COLLAR AT 10262'. CCL TO TOP SHOT OFFSET: 4.6'. CCL STOP DEPTH: 10259.4'. PRE PUNCH T/IA/OA: 250/260/0. POST PUNCH T/IA/OA: 500/250/0. CORRELATED TO TUBING TALLY RECORD DATED 4-NOV-2014. ...CONT ON 8-DEC-2022 WSR... 12/7/2022 T/I/O= 700/250/0 Temp= SI TFS unit 4 Assist Eline (Sidetrack) Rig up SB for E-Line ***Job continued on 12/08/2022*** 12/7/2022 ***WELL S/I ON ARRIVAL*** (Sidetrack) TAG TOC AT 10,312' SLM W/ 3.00" SAMPLE BAILER (Bailer packed full of cement). RE-TAG TOC AT 10,314' SLM W/ 3.00" SAMPLE BAILER (Bailer packed full of cement). LRS PERFORMED SUCCESSFUL MIT-T TO 2532 PSI (State witnessed by Austin Mcleod). RE-TAG TOC AT 10,311' SLM W/ 3.00" S-BLR (Full of cement - State witnessed by Austin Mcleod). ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** 12/8/2022 ...CONT FROM 7-DEC-2022...(tubing punch) RDMO ELINE. ***JOB COMPLETE, READY FOR FULLBORE*** 12/8/2022 T/I/O= 282/0/0. LRS 72 Assist Cement Job (SIDETRACK). Circulate the well. Pumped 585 bbls of 114*F SW & 10 bbls 60/40 into the TBG with IA returns to OTT's. Pump 150 bbls diesel, 125 bbls 9.8# brine & 2 bbls 60/40 down tbg returns up IA. Halliburton pumped 10 bbls FW, 276 bbls 14ppg cement, & 3 bbls FW down tbg up IA. Launched ball with 35 bbls 9.8# brine & 38 bbls diesel. EST TOC in TBG/IA=5000' FWHPs=90/90/0 **Complete** 12/8/2022 ***Job continued from 12/07/2022*** TFS unit 4 Assist Eline (Sidetrack) Pumped 25 bbls 60/40 down TBG @ 5bpm Taking Returns up IA to inside OTT. Pumped 25 bbls 60/40 down IA @ 5 bpm taking returns up TBG to inside OTT. Total of 50 bbls 60/40. Eline in control of well Upon Departure. FWHP= 300/75/0 12/9/2022 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(jet cut) PRESSURE TEST PCE 300L/3000. CORRELATE TO TUBING TALLY RECORD DATED 14-NOV-2014. JET CUT TUBING AT 4526', 2' ABOVE THE COLLAR AT 4528'. CCL TO CUTTER OFFSET: 6.3', CCL STOP DEPTH: 4519.7' ***JOB COMPLETE*** Daily Report of Well Operations PBU W-26A / AL1 12/9/2022 T/I/O= AOGCC CMIT TxIA FAILED to 2500 psi ( Austin McLeod ) Pumped 5.5 bbls 60/40 down tbg & IA to test. CMIT failed in 1st 15 mins. Repressured with 0.25 bbls to 2610/2623 psi. CMIT failed losing 107/116 psi, 47/86 psi, & 30/71 psi in 45 min test Repressured with 0.4 bbls to 2731/2758 psi. CMIT failed losing 66/92 psi, 34/72 psi, & 28/63 psi in 45 min test. State Rep left. E-line rigged off wellhead. Pumped 0.45 bbls 60/40 to 2739/2752 CMIT failed losing 49/81 psi, 28/61 psi, & 19/55 psi. Bleed Tbg & IA down to 0/4 psi. Repressured TxIA to 2703/2715 with 4 bbls 60/40TxIA lost 122/134 1st 15 and 70/70 in 2nd 15 min for a total loss of 177/204 in 30 min test bled TxIA to 300/300 ~ 3 bbls Final WHP's 295/302/0 E-line on well at departure 12/9/2022 ***WELL S/I ON ARRIVAL*** (Sidetrack) TAG TOC AT 4,693' SLM W/ 3.00" SAMPLE BAILER (Sample of soupy cement). RE-TAG TOC AT 4,700' SLM W/ 3.00" S-BLR (Full of cement - Witnessed by Austin Mcleod). DRIFT TO 4,600' SLM (Target for tbg cut ~4,500') W/ 3.75" CENTRALIZER (No issues). ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** 12/10/2022 T/I/O=50/0/0 CMIT TxIA ( Post Cement ) 1st test failed. Pumped 3.7 bbls 60/40 down IA to test. T/IA lost 116/110 psi 1st 15 min & 67/67 psi 2nd 15 min Bled back 3.5 bbls. 2nd CMIT - TxIA Failed. Pumped 3.47 bbls 60/40 to Achieve Max applied pressure of TBG/IA 2757/2721 psi. 1st 15 min, TBG/IA lost 102/103 psi. 2nd 15 min, TBG/IA lost 68/70 psi. 3rd 15 min, TBG/IA lost 52/52 psi. 3rd CMIT -TxIA FAILED. Pumped .2 bbls 60/40 to acieve max applied pressure of TBG/IA 2776/2738. 1st 15 min, TBG/IA lost 60/60 psi. 2nd 15 min, TBG/IA lost 44/47 psi. 3rd 15 min, TBG/IA lost 40/40 psi. 4th 15 min, TBG/IA lost 35/37 psi. 5th 15 min, TBG/IA lost 33/33 psi. Bled back to starting pressure. Bled back 3 bbls. SB to start 4th test. *** Job continued to 12-11-2022 *** 12/11/2022 *** Job continued from 12-10-2022 *** CMIT - TxIA to 2500 psi Attempted multiple tests ( See Log ) Final test TBG/IA lost 89/88 psi 1st 15 min, 43/43 psi 2nd 15 min (PASS), & 31/31 psi 3rd 15 min. Bled back Turned well over to I-RIG FWHPs=67/0/0 Activity Date Ops Summary 12/10/2022 Cont. moving rig to W-Pad pulling on location @ 08:30 hrs. Set herculite over W-26 and lay rig mats. Remove #1 shaker bed from pits. Cellar uneven pulled rig mats and herculite. Fill in edges of cellar with gravel for rig mats, relay herculite and rig mats. Spot and level Sub over W-26. Spot catwalk while removing #2 shaker bed and all shaker motors. Crane in 2 new beds and 4 new shaker motors. Spot pipe shed, pit mod. Lower shaker beds into position while spotting in Gen mod. Rig up inter-connects. 12/11/2022 Complete spotting in Gen mod and released trucks @ 01:00 hrs. Rig up steam, water and air and turn on throughout rig. Plug in power and swap to Gen power @ 03:30 hrs. Spot in enviro-vac and break shake. Start dressing shakers. Spot and berm cuttings box. LRS is still rigged up and attempting to getCont. dressing shakers and install motors. Scope up derrick and bridle down. Cont. working on rig acceptance check list. Sim-ops weld cutting box, pit support brace and pipe lift column in shed. Rig accepted at 12:00 hrs. Work on wiring shakers, chink up and secure cellar due to no cellar box. Rig up gauges to I/A and TBG and observing 50 PSI on TBG- I/A= 0 PSI. Rig up bleed back tank and bleed off TBG. Total of 2 BBLS bled back. Sim-ops replace pilot valve on Koomey. Install BPV and N/D tree, make up CTS and test sub. PT hanger threads and CTS to 5000 PSI for 10 min= good test. Function and measure each lock down screws as per well head rep. Install spacer spool and N/U BOP's. Install choke and kill lines. Rig up hole fill, drip pan and drain lines. Install koomey lines and charge koomey system. With MP #1 pump through bleeder for 5 min testing new oil seal on worm shaft. Clean and seal upper drip pan above stack, and cont. with shaker installation. M/U TIW and dart valves to 5" test joint RIH seat both 5" and 4.5" test joints on rams and mark. R/U top drive for testing. Troubleshoot test pump finding Y-strainer plugged. Fill lines and purge air from system. Perform shell test. Close lower rams and start testing BOP's. Daily disposal to PB G&I: 0 bbls, total 0 bbls. Daily disposal to MP G&I: 0 bbls, total 0 bbls. Daily water from Lake 2: 700 bbls, total 700 bbls. Daily Metal 0# total 0#. Daily downhole losses: 0 bbls, total 0 bbls. 12/12/2022 Pressure test BOP's 250/3000 PSI for 5 min each, Test with 4.5" & 5" test Jts. F/P with Blinds-CMV's 1/2/3/14-LWR IBOP on low test- bleed air and re-test. Accumulator PSI- Int= 2925 PSI, Final=1450 PSI, Manifold PSI- Int=1600 PSI, Final=1400 PSI. Annular PSI- Int=1050 PSI, Final= 1100 PSI. 200 PSI re-charge= 27 Sec, Full Recovery=93 Sec. Closing times- Bag=12 sec, Upper 4.5x7" VBR's= 8, LWR 5" solid body= 8 sec, HCR Choke/Kill= 1 sec each. Test all Gas alarms lights/audible, PVT's and Flow paddle. Rig down testing equipment. Assist Vault well head rep pulling CTS and BPV. Reverse circulate 360 BBLS of 90 deg water with Bara-clean taking returns to blow back tank through I/A. Initial rate 6 BPM, 355 PSI, Final rate 4 BPM, 115 PSI. Rig up to perform MIT-T/IA combo to 2500 PSI for 30 charted min. Initial Pressures= TBG- 2752 PSI, I/A-2724 PSI, O/A-5 PSI, First 15 min= TBG-2729 PSI (-23), I/A-2700 PSI (-24), O/A-5 PSI, Second 15 min= TBG-2710 PSI (-19), I/A-2681 PSI (-19), O/A-5 PSI,. Third 15 min= TBG-2693 PSI (-15), I/A-2664 PSI (-15), O/A-5 PSI. Total Pressure loss= TBG- 59 PSI, I/A- 60 PSI, O/A- 0 PSI. Pumped 3.75 BBLS bled back 3.4 BBLS. Good test- test witnessed by AOGCC Rep- Kam St.John. Rig up PWB pipe handling equipment and power tongs. M/U landing JT with TC-II crossoveer. M/U to hanger, BOLDS and un-seat hanger. P/U 75K. Monitor well- static. Pull and L/D 4.5", 12.6#, L-80 TC-II TBG F/4526' T/Surface. L/D a total of 109 full Jts, 1 X-nipple, 1 GLM, 2 pups 2.08'/2.42' and 1 cut jt-39.31'. Observed calculated displacement for trip. R/D PWB tbg equipment and power tongs. Pick up jt and install wear ring ( ID-9", OD-13.45", Length 1.05' ). P/U and M/U baker stab (8.5" OD), XO and MS Cutter assembly. Baker rep installed cutters. Pick up Jt M/U top drive pumping through tool @ 5 BPM verifying cutters functioned properly. Distance from btm of BHA to cutters is 2.87'. Single in the hole with 5" DP F/Surface T/2871' observing calculated displacement. Displace well over to 9.5 PPG spud mud @ 450 GPM, 1380 PSI no rotation taking returns back to cuttings box. Pick up F/2871' T/2824' and turn on pump @ 2.5 BPM, 200 PSI. Slowly RIH F/2824' T/2879' attempting to locate collar with no success. Shut off pump and POOH T/2828'. Pump @ 3.5 BPM, 400 PSI- slowly RIH F/2828' T/2895' attempting to locate with no success. Observed a 3-4K bobble @ 2877'. P/U to cutter depth of 2871'. Established Rot TQ @ 100 RPM's= 4.2K TQ. Turn on pumps to 7 BPM, 996 PSI, 6-8K TQ cutting 9-5/8" CSG. Observed pressure drop to 525 PSI and slowly increase and stabilize @ 624 PSI. Close the Bag and attempt to Circulate through the. the cut and clean/displace 9- 5/8" x 11-3/8" annulus @ 1 BPM pressuring up to 2000 PSI with no returns. Set cutters at cut depth of 2871' turn on pumps to 7 BPM, 800 PSI, 100 RPM's, 4-7K TQ attempting to open up cut. Shut down, close bag and attempt to circulate through 9-5/8 x 11-3/8" annulus pressuring up to 1600 PSI with no returns stalling out pumps. Shut down and blow down surface equipment, monitor well and prep to POOH. Daily disposal to PB G&I: 419 bbls, total 419 bbls. Daily disposal to MP G&I: 0 bbls, total 0 bbls. Daily water from Lake 2: 420 bbls, total 1,120 bbls. Daily Metal 0# total 0#. Daily downhole losses: 0 bbls, total 0 bbls. 12/13/2022 Grease spinners, blocks, roughneck and link tilt assembly, Check oil in TD and rotary table. POOH with stds of 5" DP F/2871' T/surface. P/U= 89K, SO=80K at 2871'. Observed calculated displacement. Inspect cutters observing good indication with wear CSG was cut. Break down Stab, XO and MS cutter assembly. Wait on orders from town due to new information that BP performed a CMT squeeze job in 2004 with estimated TOC @ 1450'. Sim-ops remove dry hole tree from cellar and ship with wells group. Get AKE-Line on the hook for CBL log to locate top of CMT on back side of 9 -5/8 CSG. P/U 9-58" grappling spear. Make up to a joint of 5" DP and 5 ft pup, 5' in hole and engage spear in 4.5' below hanger. Attempt to BOLDS. While BOLDS last couple of LDS became tight and hard to pull indicating CSG was growing. Stopped and ran LDS back in. Disengaged spear and L/D. Call out Ak-Eline for CCL. Clean and clear rig floor, grease top drive, overhead spinners, FH-80 and tongs. Clean and inspect air slips. Spot in Ak E-line and rig up. M/U CBL, GR and CCL. RIH and log up from 2100'. Estimated TOC at 1476'. POOH and R/D E-line. M/U MSC casing cutter BHA. RIH to 1431'. Pressure up to 450 psi and attempt to locate collar at 1427' ELM, staging pressure up to 600 psi, and slowly reciprocating pipe. Slight bobble at 1426'. Shut down pumps. Set cutters at 1410'. Establish rotary at 60rpms, 1650 ft-lbs. stage pumps up to. 7.5 bpm, 1000 psi. Observe torque increase to 5-6Kft-lbs as cutters open. After ~1 min Tq stalled out at 10Kft-lbs. Shut down pumps rotary. Pick up 5', slack back off to cut depth 1410', and repeat with 60 rpms, 7.5 bpm until torque stalled. Pick up with 60K overpull to free cutters. Continue to observe up to 60K overpull as we pull the bottom of the MSC above the cut, indicating casing is cut and off-center. L/D working single. Rig up hose to flowback tank and blow air through to ensure clear. R/U head pin. Establish circulation at 1 bpm, ICP 650 psi. Pump 100 bbl 9.5 ppg heated soap pill and spot in OA, staging pumps up to 3 bpm, FCP 215 psi. Let soap pill soak 1hr, Displace out soap pill W/9.5 PPG spud mud to flowback tank. 4 BPM, 350 PSI. Shut down and monitor well=static. Blow down and R/D surface lines. POOH racking back stds of 5" DP F/1410' T/Surface. L/D MS cutter assembly. PU =61K, SO=60K @ 1400'. Observed calculated displacement during trip. P/U working single and pull wearing. P/U test plug and RIH. RILDS pull and L/D working single. Close blinds, bleed off koomey and open upper ram doors and change rams from 4.5 x7" VBR's to 9-5/8" solid bodies. Close and tighten ram doors. Daily disposal to PB G&I: 228 bbls, total 647 bbls. Daily disposal to MP G&I: 0 bbls, total 0 bbls. Daily water from Lake 2: 140 bbls, total 1,260 bbls. Daily Metal 0# total 0#. Daily downhole losses: 0 bbls, total 0 bbls. 50-029-21964-02-00API #: Well Name: Field: County/State: PBW W-26B Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 12/16/2022Spud Date: 12/14/2022 R/U test equipment. P/T 9-5/8" upper rams 250/3000 PSI for 5 min each. Witness waived by AOGCC rep Kam St.John. B/D test equipment. BOLDS and pull test plug. L/D test jt. Swap out split bushings for masters. P/U PWB CSG. power tongs, 150T side door elevators, slips and dog collar. M/U pack-off running tool and RIH on top of hanger setting 25K down on hanger and BOLDS with no issues. L/D running tool. M/U baker 9-5/8" grappling spear and 5 ft in hole 30' ( 4.5' inside hanger ). Pull hanger breaking free at 107K, 86K free travel. Release spear and Lay down. R/D 5" hydraulic elevators and install 150T side doors elevators. Swap heads in power tong. Attempt to break hanger with power tongs. Collar broke from Jt below. Rigged up rig tongs- swapped heads and broke connection L/D hanger. POOH L/D 9-5/8" CSG T/1200'. Cont. POOH laying down 9-5/8" 47#, L-80 NSCC CSG. F/1200' T/Surface. L/D 35 Jts and 1 cut jt ( 24.06' ). 11 Centralizers recovered. R/D PWB CSG equipment. P/U and M/U bit sub, 13-3/8 72# scrapper and 12-1/4" junk mill. TQ 6-5/8 connections to 52K. RIH out of derrick F/11' T/1251', encountered hard spot @ 1251'. PU 59K SO 59K. M/U TD and attempt to wash and ream through @ 10 BPM, 135 PSI, 60 RPM, 2.2K TQ. Worked pipe up and down multiple times down to 1253' tagging hard with TQ spikes to 10K. CBU at 500 GPM, 185 PSI. Blow down surface equipment. Monitor well for 10 min- static. POOH racking back DP F/1253' T/11' observing calculated displacement. PU 59K, SO 59K @ 1253'. Break down junk mill, CSG scrapper and bit sub. Observed junk mill with slight wear on outside edge of BTM, Clear and clean rig floor. R/U AKE-line and RIH W/CCL T/1200', POOH and R/D E-line. P/U CICR and inspect as per baker rep. Make up to first std of 5" DP and RIH. RIH on DP 60 FPM to 1170' observing calculated displacement. PU 58K, SO 58K. ROT 15 turns to the right. P/U to 80K, S/O to set weight observing plug sliding down hole. Cycled up and down 3 more times pulling 90K, 100K, then to 110K setting CICR with good indication felt at surface. S/O setting 23K down on CICR, Verify release and confirm top of CICR @ 1170' by tagging with 10K down. Top of CICR 1170', BTM 1172', Collar depth. POOH racking 5" DP in the derrick F/1170' pulling CICR quick latch running tool. Inspect as per backer rep. L/D. Close blinds and line up to PT 13-3/8" CSG. P/T CSG to 2500 PSI for 30 charted min- good test. Pumped 2 BBLS bled back 2 BBLS. Bled off koomey. R/D MPD lines and drip pan. Install MPD lift cap. Install bridge cranes. Remove Choke/Kill lines. Pull hole fill lines and remove MPD head from stack. N/D BOPs and rack back. Pull TBG spool and sF22:F23tage in cellar. Using loader sting Diverter-T and knife valve in cellar assisted with tuggers. Daily disposal to PB G&I: 290 bbls, total 937 bbls. Daily disposal to MP G&I: 0 bbls, total 0 bbls. Daily water from Lake 2: 140 bbls, total 1,400 bbls. Daily Metal 0# total 0#. Daily downhole losses: 0 bbls, total 0 bbls. 12/15/2022 N/U Diverter system. Install diverter T, install stack, and knife valve. Torque up all flanges. Cross chain and center stack. Install diverter vent line. Install flow riser, inflate airboots. Hook up accumulator lines to annular and Knife valve. Test diverter system. Witnessed by AOGCC Bob Noble. Annular close in 12 seconds, Knife valve open in 9 seconds. Accumutator drawdown test: Int Acc-3000 PSI, Final-1900 PSI, 200 Pre-charge- 16 sec, Full Recovery-48 sec. 2250 PSI N2 bottle average (6 bottles) Test PVT/Flow alarms. Mobilize AK E-line and gyro data. Load Baker whipstock components in shed. Bring tools to rig floor. P/U and M/U 12-1/4" window mill, watermelon mill and upper mill. Make up Gen2 whipstock W/45K shear bolt. Orient UBHO as per Sperry DD/GYRO reps. M/U 2 string magnets and RIH with 2 5" flex Jts and 20 Jts of 5" HWDP T/738'. Sim-ops spot in AKE-line. RIH with whipstock assembly F/738' T/1147'. PU 75K, SO 72K. Fill pipe pumping 2x drill pipe volume. L/D top single of std #7, B/D topdrive. R/U AKE-line hanging sheave on derrick board fingers, P/U Gyro tools and RIH taking 3 shots at 280 deg. M/U top drive-rotate and move pipe. RIH with gyro taking 3 shots @ 244 Deg. POOH L/D AKE-line. PU= 78K, SO= 76K. P/U top single of std #7. RIH and set down 6K to set anchor. P/U with 13K overpull verifying anchor set. S/O to 26K Shearing from whipstock. Pick up 10' noticing a 7K drop in up/dwn. TOW- 1140' BOW-1165'. Start pumps @ 420 gpm, 325 psi, 65 rpm, 2K tq, Rot 73K and begin milling window F/1140' T/1144' as per baker rep 3-5 ft/min, 1-2K wob. Daily disposal to PB G&I: 168 bbls, total 1105 bbls. Daily disposal to MP G&I: 0 bbls, total 0 bbls. Daily water from Lake 2: 140 bbls, total 1,540 bbls. Daily Metal 0# total 0#. Daily downhole losses: 0 bbls, total 0 bbls. 12/16/2022 Cont. milling 12.25" window F/1144' T/1149', 420 GPM, 350 PSI, 65 RPM, 10-12K TQ, 4-5K WOB, 41% R/F, ROT=73K, PU=72K, S/O= 72K, Total Metal in 6 hrs= 473#'s. Cont. milling 12.25" window F/1149' T/1155', 420 GPM, 350 PSI, 65 RPM, 3-8K TQ, 4-5K WOB, 40% R/F, ROT=73K, PU=72K, S/O= 72K, Total Metal in 6 hrs= 150#'s. Cont. milling 12.25" window F/1155' T/1165' plus 6' of new formation, 420 GPM, 430 PSI, 65 RPM, 7-9K TQ, 18-20K WOB, 53% R/F, ROT=73K, PU=72K, S/O= 72K, Total Metal in 6 hrsl= 150#'s. Cont. milling 12.25" of new formations F/1171' T/1189', 420 GPM, 505 PSI, 65 RPM, 5-7K TQ, 20-25K WOB, 42% R/F, ROT=73K, PU=72K, S/O= 72K, Total Metal in 6 hrs= 33#'s. Daily disposal to PB G&I: 168 bbls, total 1105 bbls. Daily disposal to MP G&I: 0 bbls, total 0 bbls. Daily water from Lake 2: 0 bbls, total 1,540 bbls. Daily Metal 773# total 773#. Daily downhole losses: 0 bbls, total 0 bbls. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Joseph Lastufka To:Brooks, James S (OGC) Subject:RE: [EXTERNAL] FW: PBU W-26A (PTD #199-081) 10-407 Completion Report Date:Wednesday, January 11, 2023 10:04:21 AM Attachments:image001.png James, The well initially was producing from Zone 4A (11318’ MD) X - 607296, Y - 5963686. It was later perforated in Zone 4B (11144’ MD) X - 607332, Y - 5963577. Which changed the coordinates and offsets of the Top of Productive Interval. Please let me know if you have any questions. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Wednesday, January 11, 2023 8:40 AM To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: [EXTERNAL] FW: PBU W-26A (PTD #199-081) 10-407 Completion Report Hi, Can you check the coordinates for this well ? X (given from 407) = 607332 - Calculated X = 607417 = diff of 85 Y (given from 407) = 5963577 - Calc Y = 5964945 = diff of 1368 thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Wednesday, January 4, 2023 3:42 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: PBU W-26A (PTD #199-081) 10-407 Completion Report From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Wednesday, January 4, 2023 3:39 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Subject: PBU W-26A (PTD #199-081) 10-407 Completion Report CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, Please see attached electronic distribution for PBU W-26A (PTD #199-081). Please let me know if you have any questions. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 21 Township: 11N Range: 12E Meridian: Umiat Drilling Rig: Innovation Rig Elevation: Total Depth: 14210 ft MD Lease No.: ADL028263 Operator Rep: Suspend: X P&A: Conductor: 20" O.D. Shoe@ 111 Feet Csg Cut@ Feet Surface: 13-3/8" O.D. Shoe@ 3012 Feet Csg Cut@ Feet Intermediate: 9-5/8" O.D. Shoe@ 7984 Feet Csg Cut@ Feet Liner1: 7" O.D. Shoe@ 10963 Liner2: 4-1/2" O.D. Shoe@ 12229 Feet Csg Cut@ Feet Liner3: 3-1/2"x2-7/8" O.D. Shoe@ 14210 Tubing: 3-1/2" O.D. Tail@ 10788 Feet Tbg Cut@ 4526 Feet Plugging Data (depths are MD) - previous witness by AOGCC Inspector Austin McLeod 12/7/2022: Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bottom 14,175 ft MD 10,311 ft MD 6.9ppg Wireline tag Fullbore Bottom 10,311 ft MD 4,700 ft MD 9.8/6.9ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2752 2729 2710 2693 IA 2724 2700 2681 2664 OA 0 5 5 5 Remarks: Attachments: December 12,2022 Kam StJohn Well Bore Plug & Abandonment PBU W-26A Hilcorp North Slope PTD #1990810, Sundry# 322-665 Jaycen Sala Casing/Tubing Data (depths are MD): Previous MIT's failed from what they thought was uncured cement. Today's test (CMIT TxIA) was conducted after Innovation Rig was moved onto the well. Test lost 24 psi in first 15 min, 19 psi in the second 15 min. They ran it out another 15 min and lost 15 psi. Last 30 min test interval pressure loss was 34 psi - 1.3% of test pressure (= 34 / 2700) for a passing result. none Test Data: P Casing Removal: rev. 11-28-18 2022-1212_Plug_Verification_PBU_W-26A_ksj 9 9 9 9 9 999 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 9 9pp y Last 30 min test interval pressure loss was 34 psi - 1.3% of test pressure (= 34 / 2700) for a passing result. James B. Regg Digitally signed by James B. Regg Date: 2023.04.19 15:28:41 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 21 Township: 11N Range: 12E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 14,210 ft MD Lease No.: ADL 028263 Operator Rep: Suspend: X P&A: NA Conductor: 20" O.D. Shoe@ 111 Feet Csg Cut@ NA Feet Surface: 13-3/8" O.D. Shoe@ 3,012 Feet Csg Cut@ NA Feet Intermediate: 9-5/8" O.D. Shoe@ 7,984 Feet Csg Cut@ NA Feet Liner1: 7" O.D. Shoe@ 10,963 Feet Csg Cut@ NA Feet Liner2: 4-1/2" O.D. Shoe@ 12,229 Feet Csg Cut@ NA Feet Liner3: 3-1/2"x2-7/8" O.D. Shoe@ 14,210 Feet Csg Cut@ NA Feet Tubing: 4-1/2" O.D. Tail@ 10,788 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bottom 14,175 ft MD 10,311 ft MD 6.9ppg Wireline tag Fullbore Bottom 10,311 ft MD 4,700 ft MD 9.8/6.9ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2650 2560 2532 IA 361 362 361 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing 2575 2314 IA 2600 2425 OA 0 0 Initial 15 min 30 min 45 min Result Tubing 2610 2503 2456 2426 IA 2623 2507 2421 2350 OA 0 0 0 0 Initial 15 min 30 min 45 min Result Tubing 2713 2665 2631 2603 IA 2758 2666 2594 2531 OA 0 0 0 0 Remarks: Attachments: On 12/7/22 I traveled to location to witness the mechanical integrity test of the tubing (MIT-T) and slickline tag of the top of cement (TOC) to abandon the wellbore to prep for a sidetrack. Slickline string consisted of your generic 3-inch bailer. Proposed TOC inside the 4-1/2 inch tubing was ~ 10,635'. We tagged at 10,311' with multiple setdowns (~ 5 barrels high). . MIT-T passed. Inclination at TOC is 28 °. I returned to location 12/9 to witness the tag/combo MIT-TxIA of the top cement plug. The tubing was punch so cement could be pumped in both the inner annulus (IA) and tubing. Proposed TOC was ~ 5,000'. We tagged the TOC 4.5 barrels high at 4,700'. No cured cement observed on either tag. Three attempts were made at a combo MIT-TxIA, all failing. Possible channeling suspect. I found no need to re-tag with the thousands of feet of cement in place. Mel Rixse of AOGCC approved Hilcorp to continue on with pre-rig abandonment and attempt the CMIT TxIA after the rig is over the well. Letting the test pressure fall below 2500 was also approved as long as stabilization and allowable total loss criteria was met. Above casing/tubular data taken from W-26AL1 Sundry. PBU W-26A; PTD 1990810; Sundry 322-665. PBU W-26AL1; PTD 2140530; Sundry 322-666. December 7, 2022 Austin McLeod Well Bore Plug & Abandonment Prudhoe Bay Unit W-26A/AL1 Hilcorp North Slope LLC PTD 1990810; Sundry 322-665 none Test Data: P Casing Removal: Chad Kenyon F Casing/Tubing Data: Plugging Data: F F rev. 11-28-18 2022-1207_Plug_Verification_PBU_W-26A_am 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Aboveg casing/tubular data taken from W-26AL1 Sundry. PBU W-26A; PTD 1990810; Sundry 322-665. PBU W-26AL1; PTD 2140530;g Sundry 322-666. James B. Regg Digitally signed by James B. Regg Date: 2023.04.19 14:49:10 -08'00' By Anne Prysunka at 11:54 am, Nov 21, 2022 RBDMS JSB 120222 Changes to Approved Work Over Sundry Procedure David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/27/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220927 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3 31 500292283800 197227 12/13/2021 Baker CH RPM PBU 01-14A 500292028101 209129 7/29/2022 Baker CH SPN PBU 01-15B 500292028702 213190 8/2/2022 Baker CH SPN PBU 01-31 500292162600 186132 7/6/2022 Baker CH SPN PBU 06-04B 500292017902 216092 5/5/2021 Baker CH RPM PBU 06-16A 500292046001 212139 5/3/2021 Baker CH RPM PBU 06-21C 500292080203 221088 6/28/2022 Baker CH MRPM PBU 15-49C 500292265103 215129 8/13/2022 Baker CH MRPM PBU H-05B 500292010602 209100 6/29/2022 Baker CH SPN PBU H-26A 500292148701 214205 7/10/2022 Baker CH SPN PBU H-35A 500292260001 214045 7/4/2022 Baker CH SPN PBU H-38 500292340200 208167 7/19/2022 Baker CH SPN PBU P1-06A 500292269502 222009 7/17/2022 Baker CH MRPM PBU P2-43 500292325000 205024 8/5/2022 Baker CH SPN PBU U-09B 500292114402 214063 8/12/2022 Baker CH SPN PBU W-26A 500292196401 199081 7/23/2022 Baker CH SPN Please include current contact information if different from above. T37052 T37053 T37054 T37055 T37056 T37057 T37058 T37059 T37060 T37061 T37062 T37063 T37064 T37065 T37066 T37067PBU W-26A 500292196401 199081 7/23/2022 Baker CH SPN Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.29 16:24:46 -08'00' STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIONS • 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate p Other Stimulate I3 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: kvt vG'(4Cld Sfon, 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 199-081 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21964-01-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU W-26A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: (/�- Total Depth: measured 12620 feet Plugs measured 12229 feet RECEIVED true vertical 8863 feet Junk measured feet MAR 2 2 2016 Effective Depth: measured 12229 feet Packer measured See Attachment feet I true vertical 8902 feet Packer true vertical See Attachment feet AOGCC +CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 33-113 33-113 Surface 2979 13-3/8"68#L-80 32-3011 32-2691 5020 2260 Intermediate 7955 9-5/8"47#NT8OS 30-7985 30-6213 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet hpR % 1 L01b True vertical depth: See Attachment feet . Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 27-10792 27-8501 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11150'-11293'. Treatment descriptions including volumes used and final pressure: 625 Bbls 3%NH4CI,110 Bbls Diesel,155 Bbls 12%HCI(titration 12.8%HCI,0 mg/I iron),23 Bbls Wax Beads,62 Bbls 9:1 Mud Acid(titration 9%HCI,1%HF,0 mg/I iron),19 Bbls 60/40 Methanol/Water,795 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 340 909 288 883 263 Subsequent to operation: 375 564 359 1328 340 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil p Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I 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 Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature , R 9_ ) Phone +1 907 564 4424 Date 3/21/16 V FL-- 4j/2//,4 Form 10-404 Revised 5/2015 I ' ifAX6 RBDMS \,\JMAR 2 3 2016 Submit Original Only • • Packers and SSV's Attachment PBU W-26A SW Name Type MD TVD Depscription W-26A PACKER 7801.51 6078.46 7" Baker ZXP Mech Top Packer W-26A TBG PACKER 10639.25 8360.66 4-1/2" HES TNT Perm Packer W-26A TBG PACKER 10685.11 8402.71 7" Baker S-3 Packer W-26A TBG PACKER 10801.7 8510.32 5" Baker HMC Packer . • • W M M C0 Cl) m N (Y) CI) CO N N- N- C'') N CCS V N r Cs r CI) N C) N O r CO C) CC) M Cf) c to CO CO N- 00 C) r CO CC) a N m cro 4 m O C)) 6 N Cf) crm O O m r LO N O O O V '' m CO O) O) O cp r 00 CO C) 00 0D CO CO 00 OO CO r- O 00 0D 00 00 CK) 00 OD C) CO CD O) C) C) C3) C ) OD OD 00 OO CO CO a 00 CO 00 00 OD CO 00 00 OD CO 00 CO OD 00 00 00 0D 00 OD 00 I- 0. 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ISAlitYLS:34.6°e 12770'.CHROME LNR AcTUATOR= BAKER c Ll OKB.[LEV= 91.11' REF ELEV= 81.85 BF.ELEV= 54.61' Zi 1 1 li l_ 21947 -4-1/2"FES X N13,13=3.813" .. KOP= 1267 20"COICUCTOR H 110' Max Angle= 108°©12290' GAS LET MAMJILS Datum MD= NA kST IC TVD CEV TYPE VLV LATCH PORT DATE Datum TVD= 8800 SS 6 3843 3246 48 WAG DOME RK 16 07/11/15 13-3/8"CSG,68#,L-80 BTRS,0=12.415" 3021 I 5 6774 5315 40 MC DOE FE 16 07/11/15 4 7765 6052 43 WAG SO IRK 22 07/11/15 9-518'X r BKR ZXP LIP,1)=6.31r - 7801' L. 3 8674 6743 36 KBG2 DMY BK 0 07/11/15 9-5/&X 7' BKR HMC HGR,D=6250' - 7815' F 2 9619 7492 37 KBG2 DMV BK 0 11/04/14 7 WHPSTOCK(09/20/99) - 7984' 9-5/8"CSG,47#,L-80 NSCC,ID=8.681- -I -8000 @ ' —is-10 .0' 1 10527 8258 25 KBG2 DW BK 0 07/11/15 hiLOUT WINIDOW(W-26A)7984'-8000 Minimum ID =2.377" 11399 ' 3-1/2" X 2-7/8" LNR X0 1 10604' H4-1/2'I ES X NP,D=3.813" I E 10635' .-{r X 4-112"IES TNT PKR,ID=3.875" I- 10787' -17 X 5BKR ZXP LTP,ID=4.375 10672' 1-4-1/2"IIES X NI3,13=3.813" TOP OF 4-1/2"Lf* -1 10787' _, " " 4-1/2"TBG, 12.6#,L-80 TC11..0152 bpf,13=3.958" 1-, 10788• - 10788' -4-1/2"WLEG,13=3.958" -ELM)TT NOT LOGGED 10801' -17"X 5"BKR FOAC L/R HGR,ID=4.438" r LW,26#,L-80 BTC-M,.0383 bpf,t)=6,276' 1- 10963' i-Al 10808' -5"X 4-1/7 XO,13=3.938" • • w TOP OF LIVER -I 11346* • s 3-1/2"LNR 9,3#,13CR STL,.0087 bpf,D=2.992" 1- 11399' m 11346' -3.70"BKR DEFLOY SLV,ID=100" P 4 i t 11367' -13-1/2"FES X NP,0=2.817 PERFORATION SUMMARY REF LOG:RES/GR SPERRY ON 09/19-10/02/1999 -Pi 14 r ti ANGLE AT TOP FEW:NA _ 11399' -3-1/2"X 2-7/8-XO,ID=2.377 IP to — Note:Refer to Roduction DB for historical pert dataii 10 P i t 1146T -4-1/7 MARKER JOINT SIZE .._ SW 1 WTERVAL Opn/Sqz SI-OT I SQZ P III I W-26A 1r. r 11753' --4-1/2"MARKER JOINT : 6 SEE PAGE 2 FOR FERE SUMMARY P to MLLOUT WINDOW(W-26A L1)12229'-12239' 1 : 1 '4,......., . W-26A L1 $ Willeit.... 13203' -RA R./3.)MT SEE PAGE 2 FOR FERE SLAW*FT/ 1:;?Are 0 I I I I ..'16'.:14.1.4.......... ''.. ' •,,, . -91111111Mmi •. 4-1/2"BKR KB FKR WHI3STOCK(11/26/14) H 12229' 1. •-•-,..,.. • -... _ _ 4-1/7 LNR,12.6#, L-80 BT-M,.0152 bpf,ID=3.953" -1 -12229' ,N A A. PBTD - 14175' 2-7/8"LNR,6.5#,13-CR 611,.0058 bpi,ID=2.441' -1 14212' DA IL REV BY COOAENTS DATE REV BY COMM34TS PRUDHOE BAY UlIT 08/26/89 AUDI 3 IMTIAL COMPLETION 01/21/15 JLS/JMD GLV C/0(01/20/15) MIL: W-26A LI 10/06199 PES SIDETRACK(W-26A) 04/29/15 IJUOJMDGLV CJO(04/21/15) PERMIT No: 1990810/2140530 11/05114 D-16 MO 07/31/15 TBDUAC GLV CIO(07/11/15) Ail No: 50-029-21964-01 (60) 12/06/14'NORE1C1 CTI)MULTI LATERAL(W-26A L1) 02/17/16 I I ROM)ADPERFS(02/09-10/16) SEC 21,T11N,R12E,945'FTC 8 1446'REL 12/09/14 JM) ERLG HO CORRECTIONS 03/09/16 GC/JM) ADDED REF ELEV 12/12/14 NS/JkC FINAL ODE APPROVAL BP Exploration(Alaska)k a) • W-26A • i . . , Ll i L I 1, 7 I ,.• PERFORATION SUMMARY I REF LOG:Ra./GR SFERRY ON 09/19-10/02/1999 ANGLE AT TOP FEW NA Note:Refer to Production DB for historical perf data Z e SIZE SPF INITERVAL Opn/Sqz SHOT SQZ VW-26A I 2" 6 11150-11175 0 07/26/09 3-3/8 6 11150-11200 0 02/10/16 2-7/8" 6 11178- 11198 0 04/11/02 )1? I I 2-7/6 6 11222- 11242 0 04/11/02 3-3/8 6 11230- 11260 0 02/09/16 2-7/8 4 11250- 11264 0 02/11/00 2-7/3 4 11276- 11293 0 02/11/00 2-3/4" 4 11370- 11420 S 10/09/99 12/04/14 A I\ 2-314" 4 11470- 11490 S 10/09/99 12/04/14 • 2-3/4" 4 11546- 11576 S 10/09/99 12/04/14 • W-26A L1 • • 7 6 12390- 12610 0 12/05/14 • 7 6 12670- 12720 0 12/05/14 N ✓ 6 12790- 12870 0 12/05/14 7 6 12930- 13050 0 12/05/14 1 1 7 6 13430- 13520 0 12/05/14 i 4 ✓ 6 13710- 13760 0 12/05/14 0. ✓ 6 13850- 13910 0 12/05/14 .0 4 P ° 2" 6 13930- 13970 0 12/05/14 'I C 2" 6 13990- 14040 0 12/05/14 $ Id $ 16 1 P 11. o I iz'r ?....0.--4,1,111111111111111111, — ---___, x, IIIIIIIIIImlr- ,.. I1 n v.264-4Aft2....,„„ 4111111ft .. -_,..„ ,.. n "It-dr 11111111111N-.. gelli'"4rItr .,PAPE ..tricalb 4, DATE REV BY COMENTS DATE REV BY COMMENTS PRLOHOE BAY UNT 08/26(89 AU 3 IMTIAL COMPLETION 01/21/15 JLS/JI4A) GLV 00(01/20/15) WELL W-26A L1 10/06/99 NSES SIDETRACK(W-26A) 04/29/15 MJCIAO GLV 00(04/21/15) PERMT No. 1990810/2140530 '11/05/14 0-16 RWO 07/31/15.TBD/JM=5 GLV 00(07/11/15) AR No 50-029-21964-01 (60) 12/06/14 NORDIC1 CID MULTI LATERAL(W-26A L1) 02/17/16 TTRIJM)ADFERFS(02/09-10/16) SEC 21,T11N,R12E 945FN L&1446'FEL 12/09/14 JP/t) CRLG HO CORRECTIONS 03/09/16 GCJJPAD A DOED REF E3...EV 12/12/14 NS/JPA) FINAL ODE AFFROVAL BP Exploration(Alaska) XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN !-1 Color items- Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Odginal- Pages: Other - Pages: DIGITAL DATA X Diskettes, No. [3 Other, No/Type 'OVERSIZED .Logs of vadous kinds Other COMMENI~: D Scanned by~'~~-~m~ Nalhan Lowell TO RE-SCAN Notes: ~-.qr'.nnnp. t'J 13V: i~veriv Mildred Daretha Nathan Lowell Date: /s/ STATE OF ALASKA P I- C I Y E D ALASK.WLAND GAS CONSERVATION COMMISSIS FEB 7. 7012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate El Other f '' ,.v113• Commission Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver Time Extension ❑ 'is:;'il?ir0g8 Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ *- 199 -0810 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 .0 50- 029 - 21964 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028262 • PBU W -26A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12620 feet Plugs (measured) None feet true vertical 8863.4 feet Junk (measured) None feet Effective Depth measured 12537 feet Packer (measured) SEE BELOW feet true vertical 8878 feet (true vertical) SEE BELOW feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20 "91.5# H -40 28 - 108 28 - 108 1490 470 Surface 2994 13 -3/8" 68# L -80 27 - 3021 27 - 2698 5020 2270 Production 7958 9 -5/8" 47# L -80 26 - 7984 26 - 6213 6870 4760 Liner 3162 7" 26# L -80 7801 - 10963 6078 - 8661 7240 5410 Liner 1890 4 -1/2" 12.6# L -80 10787 - 12620 8497 - 8863 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - - _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25 - 10730 25 - 10730 3 -1/2" 9.3# L -80 10462 - 10504 8200 - 8238 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 7801 6078 3.7" BAKER KB LINER TOP PACKER 10462 8200 3.7" BAKER KB LINER TOP PACKER 10501 8235 4 -1/2" Baker S -3 Perm Packer 10685 8403 7" Baker ZXP Packer 10787 8497 7" Baker HMC Packer 10801 8510 12. Stimulation or cement squeeze summary: Intervals treated (measured): A Treatment descriptions including volumes used and final pressure: ac `t aa3.:� kt FEB 1 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 211 953 477 270 Subsequent to operation: 210 950 535 278 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 , Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Nita Summerhays Printed Name Nita Summerha s Title Data Manager Signatur- �,_ /��w"�� Phone 564 -4035 Date 2/21/2012 �l n S FEB2 20124 � ,z3 /i - -2/.,? / / W -26A 199 -081 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W -26A 10/9/99 PER 11,370. 11,420. 8,972.97 8,986.45 W -26A 10/9/99 PER 11,470. 11,490. 8,990.87 8,990.84 W -26A 10/9/99 PER 11,546. 11,576. 8,987.12 8,980.72 W -26A 10/9/99 PER 12,470. 12,530. 8,887.47 8,877.57 W -26A 2/11/00 APF 11,250. 11,264. 8,905.47 8,915.53 W -26A 2/11/00 APF 11,276. 11,293. 8,923.78 8,934.82 W -26A 4/11/02 APF 11,178. 11,198. 8,848.62 8,864.93 W -26A 4/11/02 APF 11,222. 11,242. 8,884.12 8,899.52 W -26A 5/6/02 APF 12,445. 12,470. 8,890.21 8,887.47 W -26A 7/26/09 APF 11,150. 11,175. 8,825.47 8,846.16 W -26A 6/15/11 BPS 10,696. 12,530. 8,412.72 8,877.57 • W -26A 6/27/11 BPP 10,696. 12,530. 8,412.72 8,877.57 W -26A 7/2/11 BPS 10,695. 12,530. 8,411.8 8,877.57 W -26A 7/30/11 BPP 10,695. 12,530. 8,411.8 8,877.57 W -26A 2/14/12 APF 12,450. 12,480. 8,889.81 8,885.91 W -26A 2/14/12 APF 12,480. 12,510. 8,885.91 8,880.82 W -26A 2/15/12 APF 12,502. 12,512. 8,882.15 8,880.49 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN • OH OPEN HOLE • W -26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ti 2/13/2012' CTU #9 w/ 1.75" CT. Job Scope: Re -Perf MIRU. Drift coil w/ 1.25" ball. RIH w/ PDS 2.20" memory GR/CCL and 2.25 "JSN for logging /drift run. Tag TD at 12,512'CTM. PU 40' and paint coil flag at 12,464'CTM. Log PDS memory GR/CCL up through jewelry to 10,600'CTM at fpm. Counter failure POOH to repair. « <Job in Progress »> 2/14/2012; CTU #9 w/ 1.75" CT. Job Scope: Re -Perf «< Continue WSR from 2/13/12 »> RIH w/ PDS 2.20" memory GR/CCL and 2.25 "JSN for logging /drift run. Tagged TD @ 12521'CTM logged up to 10400'CTM. At surface confirmed good DATA. Made +16' feet correction to be on depth w/ Tie In Log SWS PPROF dated 9- Dec -99. RIH w/ 30'x 2" PJ2006 HMX 6SPF 60 DEG Perf Gun. Stop at blue coil flag. !12,505' (E) 12,527' (M). Correct electronic depth to 12492.7' ELM (tie in log SWS :PPROF 9- Dec -99). Perforate 12,482 - 12,512'ELM (12,480 - 12,510' per Ref Log ;MWD TN dated 19- Sept -99). POOH. Confirm guns fired. Recover 1/2" aluminum ball. RIH w/ second 30'x 2" PJ2006 HMX 6SPF 60 DEG Perf Gun.Perforate 12,452 - 12,482'ELM (12,450 - 12,480' per Ref Log MWD TN dated 19- Sept -99). POOH. « <Job in Progress »> 2/15/2012' CTU #9 w/ 1.75" CT. Job Scope: Re-Perf «< Continue WSR from 2/14/12 »> At surface confirmed guns fired. RIH w/ 10'x 2" PJ2006 HMX 6SPF 60 DEG Perf Gun. Unable to get any deeper than 12502' top shot. called town engineer and it is ok to shoot @ 12502' CTM. Perforate 12502' to 12512' POOH. At surface confirmed guns fired. Ball has been recovered. Cut 25' of coil perform weekly BOP test. «< Job complete »> FLUIDS PUMPED BBLS 290 1% KCI 284 60/40 METH 574 TOTAL TREE= 4-1/16" CAMERON WELLHEA0 = 13-5/8" FMC • IN-26A S TES: WELL ANGLE > 70° @ ATUATOR= BAKER C 11366'. KB. ELEV = 83.07' E3Tb_E\7; .4.6 ..-----), 1262' i 120" CON:11CTOR —1 110' 1 1 1 ' I 2141' H4-1/2" HES X NIP, ID = 3.813" Max Angle = 105" @,11613', Datum MD = 11219' [turn ND =8800 SS GAS LIFT MANDRELS . k , ST MD TVD DEV TYPE, VLV LATCH PORT DATE 1 13-3/8" CSG, 68#, L-80 BTRS, ID = 12.415" I—r 3021' —A ■ 6 3522 3031 48 CA DOME RK 16 12/19/11 5 6404 5031 40 CA DOME RK 16 12/19/11 I TOP OF 7" LNR H 7801' 1 – 4 T752 6042 43 CA DM( RK 0 08/26/06 3 8693 6758 36 CA SO INT 22 12/19/11 2 9547 7435 37 CA SMY NT 0 03/28/11 1* 10481 8217 25 CA DiVIY NT 0 06/18/05 17" WHIPSTOCK (09/20/99) H 7984' 1...., 'BEHIND PATCHED ......... 7801' HT X4-112" ZXP LTP & 1-PC FIGR, ID = 6.250" 1 9-5/8 CSG, 47#, L-80 NSCC, ID = 8.681" --I –8000 I I MILLOUT WNDOW (W 28A) 7984' - 8000' 1 Minimum ID = 2.37" @ 10462' 3.70" BAKER KB PATCH 10462'-10504" --13.70" BKR KB PATCH, ID = 2.37" (6/25/05) • • 10674' H4-1/2" HES X NIP, ID = 3.813" 1 Z X 1 10685' —IT X 4-1/7 BKR SB-3 PKR, ID = 3.875" 1 • r ......-- -- I 10708' H4-1/2' HES XN NIP, ID = 3.725' I 1 4-1/2" TBG, 12.6#, L-80 BTC-M, .0152 bpf, ID = 3.958" - 10730' – ,, 1 10730' H4-1/2" WLEG, ID = 3.958" 1 1TOP OF 4-1/7 LNR 1--I 10787' I s 1 10731' H ELMO TT LOGGED 02/11/00 I 1 7" LNR, 26#, L-80 BTC-M, .0383 bpf, ID = 6.2757-1 10963' r i ill 10787' —17" X 5" BKR ZXP LNR TOP PKR, ID = 4.375" I PERFORATION SUMMARY 10801' HT X5" BKR HN'C LNR HGR, ID = 4.438" 1 REF LOG: RES/GR SPERRY ON 09/19-10/02/1999 10808' H5- X 4-1/2" X0, ID = 3.938" 1 ANGLE AT TOP PERF: 33 4 11150' Note: Refer to Production 08 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1 2" 6 11150 - 11175 0 07/26/09 1 2-7/8" 6 11178 - 11198 0 04/10/02 1 2-7/8" 6 11222 - 11242 0 04/10/02 1 2-7/8" 4 11250 - 11264 0 02/11/00 1 2-7/8" 4 11276 - 11293 0 02/11/00 1 2-3/4" 4 11370 - 11420 0 10/09/99 I 2-3/4" 4 11470 - 11490 0 10/09/99 1 2-3/4" 4 11546 - 11576 0 10/09/99 / 2-7/8" 6 12445 - 12470 0 05/06/02 1 2" 6 12450 - 12510 0 02/14/12" 2-3/4" 4 12470 - 12530 0 10/09/99 ••• 1 PBTD 1-1 12537' I ■••• ... 2" 6 12502 - 12512 0 02/15/12 a. [4-1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.953" — 12820' - DATE REV BY CXAMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08126/99 AUDI 3 ORIGINAL COMPLETION 12/17/11 DOK/PJC TREE C./0 (12/11/11) WELL: W-26A 10106/99 N9ES SIDETRACK 9-ES 01/06/12 MSS/JMD GLV C/0 (12/18/11) PERMIT No: Y 1990810 03/31/11 GJB/PJC GLV C/0 (03/28/11) 01/06/12 MSS/JMD GLV C/0 (12/19/11) AR No: 50-029-21964-01 06/28/11 PJC REBUILD DRAWING 02/16/12 TTW/JM0 ADFERFS (02/14-15/12) SEC 21, T11N, R1 2E 945' FNL & 1446' FEL 11/29/11 VVE-C/JMO GLV 0/0(11/24/11) 12/09/11 VVEC/JMO GLV C/0 (12/04/11) BP Exploration (Alaska) I _ P' &( W- 76A 1.790 3ra Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] �c�? (Zt zi'h Sent: Tuesday, December 20, 2011 6:01 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J; King, Whitney Subject: OPERABLE: Producer W -26A (PTD #1990810) Tubing Integrity Confirmed All, Producer W -26A (PTD #1990810) passed a MIT -IA to 2500 psi on 12/18/2011 after installing dummy gas lift valves. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. The next step will be to reinstall live gas lift valves prior to returning the well to production. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, November 14, 2011 4:03 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS Gqlield 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations T .m Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: Walker, Greg (D &C); Olson, Andrew Subject: UNDER EVALUATION: Producer W -26A (PTD #1990810) Sustained Casing Pressure • the IA Above MOASP All, Producer W -26A (PTD #1990810) was confirmed to have su ' -fined casing pressure on the IA above MOASP. The wellhead pressure were tubing /IA/OA = SSV /2300/0 on 11 1/2011. The well is reclassified as Under Evaluation and can remain online while further diagnostics are performed. The plan forward is: 1. Downhole Diagnostics: TIFL 2. Slickline: Change out gas lift valves, pend g TIFL results A wellbore schematic and TIO pl• are attached for reference. Thank you, 1 UNDER EVALUATION: Producer W -26A (P1 #1990810) Sustained Casing Pressure. the I... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Monday, November 14, 2011 4:03 PM c<eo 1 1( 15(11 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: Walker, Greg (D &C); Olson, Andrew Subject: UNDER EVALUATION: Producer W -26A (PTD #1990810) Sustained Casing Pressure on the IA Above MOASP Attachments: W- 26A.pdf; W -26A TIO 11- 14- 11.doc All, Producer W -26A (PTD #1990810) was confirmed to have sustained casing pressure on the IA above MOASP. The wellhead pressure were tubing /IA/OA = SSV /2306/0 on 11/11/2011. The well is reclassified as Under Evaluation and can remain online while further diagnostics are performed. The plan forward is: 1. Downhole Diagnostics: TIFL 2. Slickline: Change out gas lift valves, pending TIFL results SCP A wellbore schematic and TIO plot are attached for reference. ; - C t «W- 26A.pdf» «W -26A TIO 11- 14- 11.doc» SC[' - 1 . 33= o r. Thank you, 1t1 `e L k- tc r Mehreen Vazir �` ANN: I i ! 1 t, 2 (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 11/15/2011 PBU W -26A PTD #1990810 11/14/2011 TIO Pressures Plot Well: W -28 4,O00 3,000 • —♦ Th9 OA 2.000 --A- OOA • 000A ,••••• On 1.000 00120/11 08/27/1 00103 /11 08nOn1 08/17111 06124/11 10101/1 10/641111 10/14/11 161//19 1 /29/11 11108111 1 1 / 1 / 1 1 • TREE = 4- 1/16" CAMERON °IV 2 "��' SAFETY NOTES: W ENGLE > 7 0 ° @ 11366' WELLHEAD = 13 -5/8" FMC -26A . ACTUATOR = BAKER KB. ELEV = _ ~83.07' I 1 TiF. = 54.61' KO = P = 12262' 20" CONDUCTOR H 110' I I 1 2141' } I4 - 1/2" HES X NIP, ID = 3.813" I KO Max Angle = 105 @ 11613' D MD = 11219' GAS LIFT MANDRELS Datum TV D = 8800' SS i ST MD TV D DEV TYPE VLV LATCH PORT DATE 113 -3/8" CSG, 68 #, L -80 BTRS, ID = 12.415" I--I 3021' HA a 6 3522 3031 48 CA DOME RK 16 03/28/11 5 6404 5031 40 CA DOME RK 16 03/28/11 4 7752 6042 43 CA DMY RK 0 08/26/06 3 8693 6758 36 CA SO INT 22 03/28/11 TOP OF 7" LNR H 7801' 1 2 9547 7435 37 CA SMY INT 0 03/28/11 1* 10481 8217 25� CA DMY INT _ 0 06/28/05 I7 " WHIPSTOCK (09/20/99) 1 7984' BEHIND PATCHED "' H -8000 �- --� ,�` 7801' H7" X 4-1/2" ZXP LTP & HMC HGR, ID = 6.250" , 19 -5/8" CSG, 47 #, L -80 NSCC, ID = 8.681" M5t((' . 6470 P si "..- MILLOUT WINDOW (W - 26A) 7984' - 8000' Minimum ID = 2.37" @ 10462' 3.70" BAKER KB PATCH 10462'- 10504" H 3.70" BKR KB PATCH, ID = 2.37" (6/25/05)1 I..' r ir -�- -1 10674' 1-14-1/2" HES X NIP, ID = 3.813" I .2 ■ X . 1 10685' HT X 4-1/2" BKR SB -3 PKR, ID = 3.875" 1 10708' I --I4 -1 /2" HES XN NIP, ID = 3.725" I 4 -1/2" TBG, 12.6 #, L -80 BTC-M, .0152 bpf, ID = 3.958" hi_ 10730' 10730',- 14 -1/2" WLEG, ID = 3.958" 1 TOP OF 4 -1 /2 "" LNR I—I 10787' 1— ( 10731' H ELMD TT LOGGED 02!11100 1 10787' H7" X 5" BKR ZXP LNR TOP PKR, ID = 4.375" I 17 "' LNR, 26 #, L -80 BTO-M, .0383 bpf, ID = 6.276" H 10963' 10801' H7" X 5" BKR HMC LNR HGR, ID = 4.438" I PERFORATION SUMMARY 10808' 1-1 5" X 4 -1/2" XO, ID = 3.938" I REF LOG: RES /GR SPERRY ON 09/19- 10/02/1999 7ZQ1 ANGLE AT TOP PERF: 33° @ 11150' p5; , Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11150 - 11175 0 07/26/09 2 -7/8" 6 11178 - 11198 0 04/10/02 2-7/8" 6 11222 - 11242 0 04/10/02 2 -7/8" 4 11250 - 11264 0 02/11/00 I 2 -7/8" 4 11276 - 11293 0 02/11/00 I 2 -3/4" 4 11370 - 11420 0 10/09/99 2 -3/4" 4 11470 - 11490 O 10/09/99 I 2 -3/4" 4 11546 -11576 0 10/09/99 2 -7/8" 6 12445 - 12470 0 05/06/02 I PBTD 1—1 12537' 2 -3/4" 4 12470 -12530 0 10/09/99 %' %* 4-1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.953" F-I 12620' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/26/89 AUDI 3 ORIGINAL COMPLETION 07/25/11 JCM/ PJC SET IBP (07/02/11) WELL: W -26A 10/06/99 N9ES SIDETRACK 9 - 08/15/11 TAR/ PJC PULL IBP (7/30/11) PERMIT No: 1990810 03/31/11 GJB /PJC GLV C/O (03/28/11) API No: 50- 029 - 21964 -01 06/16/11 KJB/ PJC SET IBP (06/15/11) SEC 21, T11 N, R12E 06/28/11 CJN/ PJC PULL IPB 06/28/11 PJC REBUILD DRAWING BP Exploration (Alaska) WELL LOG TRANSMITTAL PRoAcrivE DIAEINOSTic SERVICES, INC. To: DNR Division of Oil & Gas Corazon Manaois 550 West 7th Avenue, Suite 800 , a ° °,�, ;ad " '' SD , D 1 201 Anchorage, Alaska 99501 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 f ( 17 (. 1G 1) Leak Detection - WLD 19- Jun -11 W -26A •--BL/ CD 50- 029 - 21964-01 2) Signed : ILL OdW N Date : 3 t 111 It Print Name: Ww .Nv -S- C.Ikk a PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E-MAIL : PDSANCHORAGE(O7MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\Dist ibution \TransmittalSheets\BP Transmit.docx OPERABLE: Producer W -26A (PTD4990810) Tubing Integrity Restored • Page 1 of 3 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Thursday, July 07, 2011 9:21 AM 1 To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: OPERABLE: Producer W - 26A (PTD #1990810) Tubing Integrity Restored All, Producer W -26A (PTD #1990810) passed an MIT - on 07/06/11 after the orifice gas lift valve was changed out. The passing test verifies that tubing integrity has been restored. The well has been reclassified as Operable; however, slickline needs to pull the IBP prior to placing the well on production. Thank you, Torin Roschinger (filling in for Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 A r t✓ , G t 4 °/ 0e', Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Sunday, March 13, 2011 6:27 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney Subject: NOT OPERABLE: W -26A (PTD #1990810) Tubing Secured With Kill Weight Fluid All, Producer W -26A (PTD #1990810) has been secured with kill weight fluid. The well has failed 2 TIFLs and is scheduled for slickline work to dummy the valves prior to an MIT -IA. Due to other ancillary work on the well pad, the well has been secured until such time that the slickline work can proceed. The well has been reclassified as Not Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Torin Roschinger) 7/12/2011 OPERABLE: Producer W -26A (PTD.990810) Tubing Integrity Restored • Page 2 of 3 Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, February 19, 2011 9:59 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney Subject: UNDER EVALUATION: W -26A (PTD #1990810) TIFL Failed All, Producer W -26A (PTD #1990810) failed a TIFL on 2/19/2011 after having broken MOASP on the IA during the proration January 9th. The wellhead pressures were tubing /IA /OA equal to 2300/2300/0 psi on 01/09/11. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. Plan forward: 1. Slickline: Changeout screened orifice valve 2. DHD: Re -TIFL 3. Slickline: Dummy gas lift valves (pending TIFL results) 4. Fullbore: MIT -IA (pending TIFL results) A TIO plot and wellbore schematic have been included for reference. « File: W - 26A (PTD #1990810) TIO Plot.doc » Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator 7/12/2011 OPERABLE: Producer W -26A (PTD.990810) Tubing Integrity Restored Page 3 of 3 • Sent: Tuesday, January 11, 2011 6:58 AM To: 'Maunder, Thomas E (MAY; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)' Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Quy, Tiffany; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Subject: Producers with sustained casing pressure on IA and OA clue to proration Jim/Tom /Guy, The following wells were found to have sustained casing pressure on the IA during the proration January 8 -9. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 14 -24 (PTD #1830910) W -26A (PTD #1990810) The following wells was found to have sustained casing pressure on the OA during the proration January 10. The immediate action is to perform an OART and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. U -06B (PTD #2050640) U -12A (PTD #2041470) Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/12/2011 NOT OPERABLE: W -26A (PTD # 199f�10) Tubing Secured With Kill Weighteuid Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] 3 f i5f ,r Sent: Sunday, March 13, 2011 6:27 PM ! / To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney Subject: NOT OPERABLE: W -26A (PTD #1990810) Tubing Secured With Kill Weight Fluid Attachments: W -26A (PTD #1990810) TIO Plot.doc All, Producer W -26A (PTD #1990810) has been secured with kill weight fluid. The well has failed 2 TIFLs and is scheduled for slickline work to dummy the valves prior to an MIT -IA. Due to other ancillary work on the well pad, the well has been secured until such time that the slickline work can proceed. The well has been reclassified as Not Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator 1 MAh f l Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, February 19, 2011 9:59 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 0 ; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, ..ny R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; A • ES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney Subject: UNDER EVALUATION: W -26A (PTD #1990810) TIFL Failed All, Producer W -26A (PTD #1990810) failed a TIFL on 2/ 9/2011 after having broken MOASP on the IA during the proration January 9th. The wellhead pr= sures were tubing /IA/OA equal to 2300/2300/0 psi on 01/09/11. The well has been reclassified as Un• -r Evaluation and may be produced under a 28 -day clock. Plan forward: 1. Slickline: Changeout screened orific- alve 2. DHD: Re -TIFL 3. Slickline: Dummy gas lift valves sending TIFL results) 4. Fullbore: MIT -IA (pending TIF results) A TIO plot and welibore s . ematic have been included for reference. 3/15/2011 PBU W -26A PTD #1990810 3/13/2011 TIO Pressures Plot Well: W -26 4 • 3,000 --— Tbg N f- IA 2.000 —A— OA 00A On 1 : 000 12/25/10 01/01/11 01/08/11 01/15/11 01/22/11 11 01/29/11 02105/11 02/12/11 02/19/11 UNDER EVALUATION: W -26A (PT1990810) TIFL Failed . Page 1— Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Saturday, February 19, 2011 9:59 PM 'e T 4&3I To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney Subject: UNDER EVALUATION: W -26A (PTD #1990810) TIFL Failed Attachments: W -26A (PTD #1990810) TIO Plot.doc; W -26A (PTD #1990810) wellbore schematic.pdf All, z Producer W -26A (PTD #1990810) failed awl on 2/19/2011 after having broken MOASP on the IA during the proration January 9th. The wellhead pressures were tubing /IA/OA equal to 2300/2300/0 psi on 01/09/11. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. Plan forward: 1. Slickline: Changeout screened orifice valve 2. DHD: Re -TIFL 3. Slickline: Dummy gas lift valves (pending TIFL results) 4. Fullbore: MIT -IA (pending TIFL results) 0. FE'S 8 ZO1 A TIO plot and wellbore schematic have been included for reference. «W -26A (PTD #1990810) TIO Plot.doc» «W -26A (PTD #1990810) wellbore schematic.pdf» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, January 11, 2011 6:58 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)' Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Quy, Ti :ny; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Subject: Producers with sustained casing pressure on IA and OA d • o proration Jim/Tom /Guy, The following wells were found to have ustained casing pressure on the IA during the proration January 8 -9. The immediate action is to pe rm a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, 'How up email will be sent to the AOGCC for each individual well. 14 -24 (PTD #1830910) W -26A (PTD #1990:- 0) The following wells was found to have sustained casing pressure on the OA during the proration January 2/23/2011 PBU W -26A PTD #1990810 2/19/2011 TIO Pressures Plot Well: W -26 4,000 • 3.000 Tbg IA 2,00J0 — OA t OOOA ��� 0 n t000 • 12/25/10 01/01/11 01/08/11 01115/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 TREE= 4- 1/16" CAMERON WELLHEAD = 13 -5/8" FMC ACTUATOR = BAKER W -2 6Q {3T SAFETY NES: 70° @ 11366' AND 90° @ 11490' KB. ELEV = 83.07' ' BF. ELEV = 54.61' KOP - 1262 2141' I---I4-1/2" HES X NIP, ID = 3.813" Max Angle = @ 11613' Datum MD = 11666' Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3521 3034 49 CAM DOME RK 16 08/26/06 13 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3021' (--- -A 5 6403 5032 40 CAM DOME RK 16 08/26/06 4 7752 6045 45 CAM DMY RK 0 08/26/06 L 3 8693 6758 36 CAM DOME NT 16 08/26/06 2 9547 7435 38 CAM SO NT 22 02/01/10 1* 10481 8217 25 CAM DMY NT _ 0 06/28/05 * PATCHED Minimum ID = 2.37" @ 10462' 3.70" BAKER KB PATCH MILLOUT WINDOW 7984' - 8000' 7815' 1-17" X 4- 112" ZXP LTP &HMC HGR, ID = 6.250" I TOP OF 7" LNR I—I 7801' I 10462'- 10504" I- 13.70" BKR KB PATCH (06/25/05), ID = 2.37" I 10673' I-I4 -1 /2" HES X NIP, ID = 3.813" I 10685' I-17" X 4 -1/2" BKR SB -3 PKR, ID = 3.875" I 17, 10707' H4 -1/2" HES XN NIP, ID = 3.725" I lii' 10730' H4-1/2" W LEG, ID = 3.958" I 10731' H ELMD TT LOGGED 02/11/00 I 1 TOP OF WHIPSTOCK H 7984' 10787' I- 7" X 4 -1/2" BKR, ZXP, ; 1 r � PKR/TIEBACK SLV ,� ti 10801' I- 7" X 4 -1/2" HMC, LNR, I BRIDGE PLUG H 8024' I A, HGR, PKR, ID = 3.938" 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 1--1 11372' I ti PERFORATION SUMMARY 'TOP OF 4 -1/2" LNR I-I 10730' REF LOG: RES /GR SPERRY ON 09/19 - 10/02/1999 .s». ANGLE AT TOP PERF: 34° @ 11150' `y Note: Refer to Production DB for historical pert data 4 -1/2" TBG, 12.6 #, L -80, --I 10730' I SIZE SPF INTERVAL Opn /Sqz DATE BTC-M, .0152 bpf, ID= 3.958" 2" 6 11150 - 11175 0 07/26/09 2 -7/8" 6 11178 - 11198 0 04/10/02 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I 10963' 2 -7/8" 6 11222 - 11242 0 04/10/02 2 -7/8" 4 11250 - 11264 0 02/11/00 I PBTD ,—I 12537' I 2 -7/8" 4 11276 - 11293 0 02/11/00 2 -3/4" 4 11370 - 11420 0 10/09/99 14 -1/2" LNR, 12.6 #, BT MOD, L -80, .0152 bpf, ID = 3.953" I—{ 12620' I 2 -3/4" 4 11470 - 11490 0 10/09/99 2 -3/4" 4 11546 - 11576 0 10/09/99 2 -7/8" 6 12445 - 12470 0 05/06/02 2 -3/4" 4 12470 - 12530 0 10/09/99 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/26/89 QUIZ ORIGINAL COM PLETION 08/21/07 PJC PERF ANGLE CORRECTION WELL: W -26A 10/09/99 KSB SIDETRACK 9 -ES 04/15/08 TQ /PJC PERF LOG CORRECTION PERMIT No: 1990810 06/25/05 MDC /PJC BKR PATCH 09/30/09 JKC /SV ADPERF (07/26/09) API No: 50- 029 - 21964 -01 06/28/05 DTR/TLH GLV C/O 09/30/09 SEW /SV GLV C/O (08/05/09) SEC 21, T11 N, R12E 11/10/05 TWS /PJC GLV C/O 02/04/10 BSE/PJC GLV C/O (02/01/10) 08/26/06 MSS /PAG GLV C/O BP Exploration (Alaska) Producers with sustained casing presson IA and OA due to proration • Page 1 of 1 Regg, James B (DOA) R7 -06 i From: AK, D &C Well Integrity Coordinator [ AKDCWelIIntegrityCoordinator @bp.com]�� iI it 11 Sent: Tuesday, January 11, 2011 6:58 AM / I To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Quy, Tiffany; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Subject: Producers with sustained casing pressure on IA and OA due to proration Jim /Tom /Guy, The following wells were found to have sustained casing pressure on the IA during the proration January 8 -9. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. -24 PTD • : 0910) W -26A (PTD #1990811 The following wells was found to have sustained casing pressure on the OA during the proration January 10. The immediate action is to perform an OART and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. U -06B (PTD #2050640) U -12A (PTD #2041470) Please call with any questions or concerns. Thank you, -11 ' JAN £ 0 2011 Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1/11/2011 OPERABLE: W-26A (PTD #19910) Tubing Integrity Restored • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] 't~~'~~ ~~ z~~i3 Sent: Thursday, February 11, 2010 4:55 PM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: Williams, Carrie; Kirchner, Carolyn J; NSU, ADW Well Integrity Engineer Subject: OPERABLE: W-26A (PTD #1990810) Tubing Integrity Restored All, ~Y Well W-26A (PTD #1990810) passed a TIFL after changing out the orifice gas lift valve. The well has been reclassified as Operable. and may be returned to production. -~---~ Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1154 ~~~~~~ ~E>3 ~ ~ 201 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, January 27, 2010 5:15 AM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; 'Regg, James B (DOA)'; Tom_Maunder@admin.state.ak.u5'; 'Schwartr, Guy (DOA) <guy.schwartz@alaska.gov>' Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Kirchner, Carolyn J Subject: UNDER EVALUATION: W-26A (PTD #1990810) Sustained casing pressure All, Well W-26A (PTD #1990810) has confirmed sustained casing pressure due to TxIA communication with a failing TIFL. On 01/24/10 the wellhead pressures were tubing/IA/OA equal to 420/2080/0. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. Slickline: C/O OGLV 3. DHD: Re-TIFL A TIO Plot and wellbore schematic have been included for reference. « File: W-26A TIO Plot 01-27-10.doc» « File: W-26A.pdf» Please call with any questions or concerns. Thank you, 2/12/2010 OPERABLE: W-26A (PTD #199010) Tubing Integrity Restored ~ Page 2 of 2 Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 2/12/2010 UNDER EVALUATION: W-26~TD #1990810) Sustained casing press}~e Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, January 27, 2010 5:15 AM ~~ j~ '128 is To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Kirchner, Carolyn J Subject: UNDER EVALUATION: W-26A (PTD #1990810) Sustained casing pressure Attachments: W-26A TIO Plot 01-27-10.doc; W-26A.pdf All, Well W-26A (PTD #1990810) has confirmed sustained casing pressure due to TxIA communication with a failing TIFL. On 01/24/10 the. wellhead pressures were tubing/IA/OA equal to 420/2080/0. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. Slickline: C/O OGLV ,~ 3. DHD: Re-TIFL A TIO Plot and wellbore schematic have been included for reference. «W-26A TIO Plot 01-27-10.doc» «W-26A.pdf» f Please call with any questions or concerns. M Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 1/2$/2010 PBU W-26A PTD #1990810 1/27/2010 TIO Pressures x,000 3,000 '',000 1,000 -~ Tbg ~- IA -~- OA OOA OOOA On u 11 }28}09 12}05,'09 12}1 Z}09 12}7 9}09 12}26}09 01 }02}10 01 }09}10 01 }7 6}10 01 }23}10 TREE= 4-1116" CAMERON WELLHEAD = 13-5/8" FMC ACTUATOR =BAKER KB. ELEV = 83.07 BF. ELEV = 54.61' KOP = 1262' Max Angle = 105 @ 11613' Datum MD = 11666' Datum ND = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" S TES: 70° @ 11366' AND 90° @ 11490' W~2~~ Minimum ID = 2.37" @ 14462' 3.70'" BAKER KB PATCH TOP OF 7" LNR ITOPOFWHIPSTOCK I ~~ ~ , BRIDGE PLUG 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: RES/GR SPERRY ON 09119-10102/1999 ANGLE AT TOP PERF: 35° @ 11178' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 6 11178 - 11198 O 04/10/02 2-7/8" 6 11222 - 11242 O 04/10/02 2-7/8" 4 11250 - 11264 O 42/11/00 2-718" 4 11276 - 11293 O 02/11/00 2-314" 4 11370 - 11420 O 10/09/99 2-3/4" 4 11470 - 11490 O 10!09/99 2-3/4" 4 11546 - 11576 O 10/09/99 2-7(8" 6 12445 - 12470 O 05!06!02 2-3/4" 4 12470 - 12530 O 10!09!99 2141' ~--~4-1/2" HES X NIP, ID = 3.813" ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3521 3034 49 CAM DOME RK 16 08126/06 5 6403 5032 40 CAM DOME RK 16 08126106 4 7752 6045 45 CAM DMY RK 0 08/26106 3 8693 6758 36 CAM DOME INT 16 08/26106 2 9547 7435 38 CAM SO INT 22 11/10/05 1* 10481 8217 25 CAM DMY INT 0 06/28!05 ` PA f L t1tU MILLOUT WINDOW 7984' - 8000 7815' ~- 7" X 4-112" ZXP LTP &HMC HGR, ID = 6.250" '-10504" L3.70" BKR KB PATCH (06/25/05), ID = 2.37" 10673" 4-112" HES X NIP, ID = 3.813" 10685' 7" X 4-112" SKR SB-3 PKR, ID = 3.875" 10707' 4-1/2" HES XN NIP, ID = 3.725" 10730' 4-112" WLEG, ID = 3.958' 10731' --{EI-MD TT LOGGED 02!11!00 10787' 7" X 4-1/2" BKR, ZXP, PKR/TIEBACK SLV ~`- 10801' 7" X 4-1/2" HMC, LNR, HGR, PKR, ID - 3.938" 4-112" TBG, 12.6#, L-80, -~ 10730• BTC-M, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" PBTD --~ 1L537 4-112" LNR, 12.6#, IBT MOD, L-80, .0152 bpf, ID = 3.953" DATE REV BY COMMENTS DATE REV BY COMMENTS 08/26!89 QUIZ ORIGINAL COMPLETION 08121/07 PJC PERF ANGLE CORRECTION 10/09/99 KSB SIDETRACK 9-ES 04115!08 TO/PJC PERF lOG CORRECTION 06/25/05 MDGPJC BKR PATCH 06128!05 DTR/TLH GLV GO 11/10/05 TWSIPJC GLV GO 08/26/06 MSS/PAG GLV GO PRUDHOE BAY UNIT WELL: W-26A PERMIT No: 1990810 API No: 50-029-21964-01 SEC 21, T11 N, R12E BP Exploration {Alaska) TOP OF 4-1/2" LNR C;A S I_ IFf MA NQRF1_S Schl~nherger Alaska Data & Consulting Services 2525 Gambell Sireel, Suite 400 Mchorage, AK 99503-2838 ATTN: Beth We11 Joh x t~~~~~1~~~ ~~ Vvy Log Description Date BL NO. 5353 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 Color CD osii vos „ ~: .. ' t.i ; r ~ ~:; V-02 B2WV-00018 MEM PHODUCTION PROFILE ' 07l27/09 1 1 ~ W-26A B1JJ,00033 MEM PRODUCTION PROFILE ~ 07/26/09 1 1 H-32 ANHV-00102 PRODUCTION PROFILE ~ L- 07/25/09 7 ~ P2-29 L2-11 L2-O6 AYTU-00052 ANHY-00106 869K-00007 INJECTION PROfILE ~ O~~ lDl ~ CROSS FL W CHECK - OB/02/09 08/02/09 07/31/09 1 1 1 ~ ~ ~ P2-28 L-213 V-22/ AYTU-00051 82WY-00019 AXBD-OD037 INJECTION PROFILE G-~ MEM INJECTION PROFI E' MEM INJECTION PROFILE ° 08/01/09 07/29/09 07/28/09 1 7 1 ~ 7 ~ ~ L-220 07-22 04-02A 81JJ•00035 AZCM-00036 AYS4-00097 MEM INJECTION PROFILE PRODUCTION PROFILE ~ - f USIT ~ 07/30/09 08/09/09 08/11/09 1 1 1 1 ~ 1 J41A Lt-09 X-28 AWLB-00029 AYS4-OOOB9 AXBD-00026 USiT PRODU TION PROFILE _p(~ MEM INJECTION PROFILE V" 08/OSl09 OB/08/09 05/17/09 1 1 1 1 ~ 1 L2-O6 3-29(J-32 06-04A 83SQ-00020 AP3Q-00055 85JN-00009 PRODUCTION PROFILE IBP SET RECORD W/CROSSGLOW ~ RST 08/14/09 08/08/08 08/23/09 1 7 1- ~ ~ ~ 75-498 82NJ-00013 MCNL - 07f15/08 1 ~ 03-328 09AKA0030 OH MWD/LWD EDIT 02/28/09 2 ~ G-14B AWJI-00043 MCNL - 07/24/09 1 ~ L2-13A AWJI•00036 MCNL OW17/09 ~ 18-028 AWJI-00045 MCNL - $~ OB/17/09 1 ~ P1-OS AWLB-00032 RST OB/09/09 1 1 8-16A B2WY-00020 MCNL '~ O - 08/03/09 1 7 J-20B AX00.00020 MCNL (REVISED) .~ ,'-L ' 04/72/09 ~ o~ cecc errunwi cnr_c ocr o~or nv c~c.~~.~ .. ..~..'.~~~~.,.~..~......~ ........ _._.. _- BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Dala & Consulting Services 2525 Gambell Sireel, Suila 400 Anchorage,AK 99503-2838 u u ~x\2-- ~ ~ ~~tiErl~~. ~~~ OPERABLE: W-26A (PTD #1990~10) Sustained casing pressure mitigated• Page 1 of 2 ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, August 28, 2009 2:40 PM ~~'l ~I ~~~~ To: NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Weiis Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA) Cc: Quy, Tiffany; Holt, Ryan P(ASRC); NSU, ADW Well Integrity Engineer Subject: OPERABLE: W-26A (PTD #1990810) Sustained casing pressure mitigated All, / Well W-26A (PTD #1990810) has well passed a TIFL on 08/27/09 after popping the well confirming tubing integrity. The well has been re-classified as Operable. Please contact me with any questions. Thank you, Taylor Taylor Wellman filling in for Anna Dube/Torin Roschinger Office: 659-5102 Pager: 659-5100 x 1154 ,,~ ;~~ ~, r~,`_ ~~ ft(j~~j ~ . "~; u: 4~»:» ~ _ From: NSU, ADW Well Integrity Engineer Sent: Sunday, August 23, 2009 2:07 PM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; 'Regg, James B(DOA)'; Tom_Maunder@admin.state.ak.us; 'Schwartz, Guy (DOA) <guy.schwar~@alaska.gov>' Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: W-26A (PTD #1990810) Sustained casing pressure All, Well W-26A (PTD #1990810) has confirmed sustained casing pressure due to TxIA communication with a failing TIFL. On 08/20/09 the wellhead pressures were tubing/IA/OA equal to SSV/2060/0. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. DHD: Re-TIFL 2. S: C/O OGLV 3. DHD: Re-TIFL A TIO Plot and weilbore schematic have been included for reference. « File: W-26A TIO Plot.doc »« File: W-26A.pdf» ~. 9/16/2009 OPERABLE: W-26A (PTD #1990~10) Sustained casing pressure mitigated• Page 2 of 2 ~ Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 9/16/2009 PBU W-26A PTD #1990810 8-23-09 TIO Pressures I a,ooo ~ ~,a~o 2,000 1.~OfJ -~- T bg ^ IA -~- OA OOA -~-- OOOA -~- 0 n ~ 051?3Jt79 05J30J09 06l06f09 C16113/D9 05J20fU9 Ci6/2?1~J9 Oil04,'09 C17111I05 07I18109 07125lC1~ OS,'01I09 O~i109rt79 08115/09 TREE= 4-1116" CAMERON WELLHEAD = „~..m...,.,, . ... . 13-5/8" FMC ~_~, ~ ~ , mm„_,w ACTUATOR= ~u BAKER KB. ELEV = 83.07' BF. ELEV = 54.61' KOP = . 1262' Max Angie = 105 @ 11613' Datum MD = 11666' Datum ND = 8800' SS 13-3/8" GSG, 68#, 1-80, ID = 12.415" ~ SAFETY ES: 70° @ 11366' AND 90° @ 11490' ~~ ~~ 41' E-~4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS Minimum ID = 2.37" @ 10462' 3.70" BAKER KB PATCH TOP OF 7" LNR ~ TOP OF WHIPSTdCK I BRIDGE PL.UG 9-5l8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF ~OG: RES/GR SPERRY ON 09/19-10/02l1999 ANGLE AT TOP PERF: 35° @ 11178' Note: ReFer to Production DB for historical parf data SIZE SPF INTERVAL OpnlSqz DATE 2-7/$" 6 11178 - 11198 O 04/10/02 2-7/$" 6 11222 - 11242 d 04/10/02 2-7(8" 4 11250 - 11264 O 02111/00 2-7/8" 4 11276 - 11293 O 02/11/00 2-3/4" 4 11370 - 11420 O 1 Q/Q9/99 2-3/4" 4 11470 - 11490 O 10/p9199 2-3(4" 4 11548 - 11576 O 10l09l99 2-718" 6 12445 - 12470 O 05106/Q2 2-3/4" 4 12470 - 12530 O 10109199 ST MD ND DEV 7YPE VLV LATCH PORT DATE 6 3521 3034 49 CAM DOME RK 16 08/26/06 5 6403 5Q32 40 CAM DOME RK 16 08/26106 4 7752 6045 45 GAM DMY RK 0 08/26/06 3 8693 6758 36 CAM DOME INT 16 08i26/06 2 9547 7435 38 CAM SO INT 22 11/10/05 1* 10481 8217 25 CAM DMY INT 0 06l28l05 " PATGHED MILLOUT WINDOW 7984` - 8000' ~ 7815~ 7" X 4-1 /2" ZXP ~TP & HN1C HGR, ID = 6.250" 10462"-10504" ~-~ 3.70" BKR KB PATCH (06/25/05), ID = 2.37" ( ") Q~,7$" 4-112" NES X NIP, ID = 3.813'~ ~Q~$$' 7" X 4-1/2" BKR SB-3 PKR, iD = 3.875" 10707' 4-1l2" HES XN NIP, ID = 3.725" 10730~ 4-1/2" WLEG, ID = 3.958" '{ fl731' ELMD TT~ ~OGGm 02/11(QO 107$7~ 7" X 4-1/2" BKR, ZXP, PKWTIEBRCK SLV ~ 10801' ~X 4-1/2" HMC, LNR, HGR, PKR, ID = 3.938" TOP OF 4-1i2" LNR ( 4-1(2" 1BG, 12.6#, L-80, ~ BTC-M, .0152 bpf, ID = 3.958" ~ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ PESTD -~-~ 1 Z537 4-1/2" LNR, 12.6#, IBT MOQ, L-80, .0152 bpf, ID = 3.953" DATE REV BY COMMEPITS DATE REV BY COMMENTS O8l26/$9 QUIZ ORIGINA~ COM PLETION 08/21/07 PJC PERF ANGLE CORRECTION 10l09/99 KSB 51DETRAGK 9-ES O4115lO8 TQ/PJC PERF LOG CORRECTION O6l2blQ5 MDC/PJC BKR PATCH OB/28/05 DTR(TLH GLV C/O 11/10/05 1lNS/PJC GLV C/O _„~ _.,,,,,,,,,,,,,, ~ 08126/06 MSSiPAG G~V C!O PRUDHOE BAY UN~I" WELL: W-26A PERMR No: ~1980810 APl Nn: 50-029-21964-01 SEC21, T11N, R12E BP Exploration (Alaska} STATE OF ALASKA ALASKA ~AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS ~E~~1~~~9~ ~~~ ~ ~ ~~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ ~ a~ p~~, ~~m Performed: AlterCasing ~ Pull Tubing~ Pertorate New Pool ~ Waiver~ Time Extension~ Q~~~~~~~~ Change Approved Program ~ Operat. Shutdown~ Perforate Q- Re-enter Suspended Well~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Dev~elopment ~ - Exploratory ~ 199-0810, 3. Address: P.O. Box 196612 StP'BtlgfBphlC M`~ Service ~~ 6. API Number: Anchorage,AK 99519-6612 50-029-21964-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 81.85 KB PBU W-26A ~ 8. Property Designation: 10. Field/Pool(s): ADLO-028262 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12620 - feet Plugs (measured) None true vertical 8863.4 - feet Junk (measured) None Effective Depth measured 12537 feet true vertical 8876 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28 - 108 1490 470 Surface 2994 13-3/8"68# L-80 27 - 3021 27 - 2698 5020 2270 Production 7958 9-5/8" 47# L-80 26 - 7984 26 - 6213 6870 4760 Liner 3162 7" 2fi# L-8Q 7801 - 10963 6078 - 8661 7240 5410 Liner 1890 4-1/2" 12.6# L-80 10730 - 12620 8440 - 8863 8430 7500 Perforation depth: Measured depth: see attached - _ _ _ _ True Ve~tical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 25 - 10730 3-1/2" 9.3# L-80 10462 - 10504 Packers and SSSV (type and measured depth) 7" Baker ZXP Top Packer 7801 3.7" BAKER KB LINER TOP PACKER 10462 3.7" BAKER KB LINER TOP PACKER 10501 4-1/2" Baker S-3 Perm Packer 10685 7" Baker ZXP Packer 10787 7" Baker HMC Packer 10801 12. Stimulation or cement squeeze summary: Intervalstreated(measured): !~ ~. , ;~,F)~~~+ 1 E.~ ~ ~ ?~ a 1 ,~ ~ :`~o:~~~ ~t r . . . ~. , . 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: 219 526 1044 267 Subsequent to operation: 266 591 680 277 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Expioratory ~ De~elopment ~- Service I^` Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~~ Gas ~~ WAG C~ GINJ ~ WINJ ~ WDSPL #`` 17. I 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 Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/28/2009 S~IQtI Form 10-404 Revised 04/2006 ;_ y~-~ `~„J(;: ~~?~~~ Submit Original Only ~r~ ~~~'~-~"~~-`~~~ W-26A 199-081 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-26A 10/9/99 PER 11,370. 11,420. 8,972.97 8,986.45 W-26A 10/9/99 PER 11,470. 11,490. 8,990.87 8,990.84 W-26A 10/9/99 PER 11,546. 11,576. 8,987.12 8,980.72 W-26A 10/9/99 PER 12,470. 12,530. 8,887.47 8,877.57 W-26A 2/11/00 APF 11,250. 11,264. 8,905.47 8,915.53 W-26A 2/11/00 APF 11,276. 11,293. 8,923.78 8,934.82 W-26A 4/11/02 APF 11,178. 11,198. 8,848.62 8,864.93 W-26A 4/11/02 APF 11,222. 11,242. 8,884.12 8,899.52 W-26A 5/6/02 APF 12,445. 12,470. 8,890.21 8,887.47 W-26A 7/26/09 APF 11,150. 11,175. 8,825.47 8,846.16 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ 1~ •~ , • W-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/25/2009~CTU #6 1.75" CT Job Scope: PPRORF/ADPERF MIRU RIH for drift with 2.20" ~SDN "**** continued on WSR 7/26/09 *'`*''""" E ~__~__ _ _ _ .__.__ __ ~_______.._.... ... . __. ._...._______~. ~ _____ ~ ..__. 7/26/2009~CTU #6, 1.75" CT ( Interact Publishing ), Job Scope:PPROF/ADPERF, :Continued from 7/25/09 WSR ... RIH w/ 2.20" SDN for drift & tag. Taaged at ~ 12529' ctmd. PUH to 12500' paint white flag. POOH. At surface pop off well MU ;logging tools. RIH make GL survey while running in hole. Continue RIH making £stop counts between perf intervals per program. Log up and down passes at 40 and 80 fpm from 12518' ctmd to 11050' ctmd. Log depth control pass from ~ 11400' ctmd up to 10900' ctmd stopping to flag pipe at 11149' ctmd. POOH. ~Data good (+15' corr). MU and RIH with SLB 25' - 2.0" PJ gun loaded 6 spf. Tie ; in at flag and perforate interval 11150' to 11175'. POOH. At surface guns fired ; holes confirmed. Ball recovered. RDMO *""""Job Complete**""** FLUIDS PUMPED BBLS 90 2% KCL 90 Total Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job# Log Description Date BL 1-31/M-21 \ ~)- C"l 10980540 RST (REVISED)* 04/14/05 07 -34A ) Ú c ~ ð~ J 11001051 RST (REVISED)* 04/26/05 15-14A 5û'-I - .:ÀJ. J.- 10913003 PEX-DSI-AIT 01/16/05 1 Y -238 ' ().3 -. llø "'¡ 10913024 PDC-GR 06/09/05 N-08A ,. \; ~ .. ~ crt 10919802 LDL 09/24/04 1 K-08A ^ \:¡-~ ... I L( ~ 10942219 MEM PPROF 06/24/05 1 W-26A ,q c, - C:1 \ 11051066 LDL 06/23/05 1 L5-09 , q ~.. i).. '-f 11051037 RST 04/27/05 1 OWDW-NW, ~C '. ).. '1 \:;, 10980537 RST 03/26/05 1 C-34 ! -98, CI Y 10831309 RST 07/09/04 1 01-12A ;). ~ ).. .... ì C'q 10928620 MCNL 04/03/05 1 OS 05-41A)..{j ~.- I r/~ 10715377 MCNL 01/21/04 1 02-26C ). G ç - t: \ C\ 10928619 MCNL 03/20/05 1 *REVISED TO CORRECT API# ON DIGITAL DATA PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ªC/-'\NNEC SEP Date Delivered: :, \ I~t / (J-;,J'" n /-V~~ \ o ? 2005 07/14/05 NO. 3433 ~ qq-ög Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD 1 1 1 1 -/ I ~ 1.5 3 ;J)'~Y i 1 Å) (~ /3 J..J ~l 1 I 3 lJ 7 1 /3 118 1 iJ J..JC/ 1 ).3 )."Il\ 1 j 3 J..."'¡ f 1 i) J..·4 l -~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anch~rage, AK 9ì1~5032838 I,' ATTN. Beth ; {; . .J U ReceIved by: \ Ii \~,.. J ~ /' ()itvJ, ) STATE OF ALASKA) RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION AUG 0 3 2005 REPORT OF SUNDRY WELL OPERATIONSskaoU&GasCons C . . omrn,(!S 1. Operations Performed: AnC~ge . Abandon 0 Repair Well 00 Pluç¡ PerforationsD Stimulate ŒJ OtherIT Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 81.85 8. Property Designation: ADL-028262 11. Present Well Condition Summary: Total Depth measured 12620 feet true vertical 8863.4 feet Effective Depth measured 12537 feet true vertical 8876.4 feet Casing Length Size CONDUCTOR 80 20" 91.5# H-40 SURFACE 2994 13-3/8" 68# L-80 PRODUCTION 7958 9-518" 47# L-80 LINER 3162 7" 26# L-80 LINER 1890 4-1/2" 12.6# L-80 Perforation depth: 4. Current Well Class: Development [&] ExploratoryD 5. Permit to Drill Number: 199-0810 6. API Number 50-029-21964-01-00 Stratigraphic 0 ServiceD 9. Well Name and Number: W-26A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 28 108 28.0 108.0 1490 470 27 - 3021 27.0 - 2697.6 5020 2270 26 - 7984 26.0 - 6212.6 6870 4760 7801 - 10963 6078.1 - 8660.5 7240 5410 10730 - 12620 8444.0 - 8863.4 8430 7500 Measured depth: 11178 -11198,11222 -11242,11250 -11264,11276 -11293,11370 -11420,11470 -11490,11546 -11576 11546 -11576,12445 -12470,12470 -12530 True vertical depth: 8848.62 - 8864.93, 8884.12 - 8899.52, 8905.47 - 8915.53, 8923.78 - 8934.82, 8972.97 - 8986.45, 8990.87 - 8990.84 8937.12 - 8980.72, 8890.21 - 8887.45, 8887.47 - 8877.57 Tubinç¡ ( size, ç¡rade, and measured depth): 4-1/2" 12.6# L-80 @ 25 PATCH 2-7/8" 6.5# L-80 @ 10462 10730 10504 7" Baker ZXP Top Packer 7" Baker ZXP Packer 7" Baker HMC Packer 4-1/2" Baker S-3 Perm Packer 3.70" BKR KB Packer 3.70" BKR KB Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature A~r---' ~ J~ Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl SHUT-IN 1402 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ ! Form 10-404 Revised 4/2004 @ 7801 @ 10787 @ 10801 @ 10685 @ 10462 @ 10501 RBDMS BFl AUG 0 4 ¿UllS SC'!~NNEr~: :~UG 0 B 2005 Representative Dailv Averaqe Production or Iniection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 8883 328 279 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD Development ŒI Service D WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A Title Petroleum Engineer Phone 564-5174 Date 8/2/05 RDDMG UrL AUG 0 4 2005 UR,IGINAL ) ) W-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/24/05 CTU #5, TBG. PATCH; MIRU DS CTU #5. RIH WITH BAKER HYD. IGS' BHA TO FISH PATCH. LATCH TOP PACKER AT 104581 CTMD. PULLED FREE WITH NO EFFORT (AS IF PACKER WAS NOT FULLY SET). PUH, FISH IS DRAGGING. ATTEMPT TO RBIH WITH NO SUCCESS. CONTINUE TO PUH WITH OVER PULLS. FISH LODGED, TWO JAR LICKS AND FISH PULLED FREELY (AS IF FULLY RELEASED). FISH LODGED AGAIN AT 97001 CTMD. FISH STUCK, COULD NOT MOVE UP OR DOWN. JARRED 52 TIMES WITH NO SUCCESS. PUMPED OFF FISH AND POOH WITH BHA #1. MU AND RIH WITH BHA #2, SAME AS BHA #1 PLUS WEIGHT BARS AND ACCELERATOR. LATCH FISH AT 97181 CTMD. NINE JAR LICKS AND FISH PULLED FREELY. PULL TO SURFACE, TAG UP TO STRIPPER. RBIH TO 201 CTMD. CLOSE MASTER ON FISH, PUMP OFF FISH AND POOH WITH BHA #2. MU AND RIH WITH FISHING BHA #3. LATCH FISH AND POOH. DID NOT RECOVER 2 ELEMENTS AND 1 SLIP FROM PACKER. DISCUSS OPTIONS WITH WOS. JOB IN PROGRESS. WSR CONTINUED ON 06/25/05 ... 06/25/05 CTU #5, FISH PATCH/PKR ASSY.; WSR CONTINUED FROM 06/24/05... RECOVER PATCH/PACKER ASSY. TOOL STRING, DID NOT RECOVER 2 ELEMENTS AND 1 SLIP FROM KB PACKER. MU AND RIH WITH BAKER 3.5" VENTURI JUNK BASKET. START WORKING VENTURI AT 9000' CTMD, SAT DOWN AT 10491' CTMD. PARK COIL, WORK VENTURI. POOH. NO SIGNIFICANT DEBRIS RECOVERED IN VENTURI. RIH WITH 3.13" MHA, 2" X 101 STINGER, AND 2.0" DJN. JETTED THROUGH LOWER PACKER SEVERAL TIMES W/NOZZLE-STINGER. SAW NO RESTRICTIONS. POOH. MU AND RIH WITH 3RD BAKER UPPER PATCH ASSEMBLY (5.01 LONGER THAN PREVIOUSLY RUN); CONSISTING OF A 3.70" KB PACKER WITH 2 7/8" SPACER PIPE (29.181) AND SEAL ASSY. STAB INTO LOWER PACKER AND SPACE OUT SEAL ASSEMBLY IN TIE BACK SLEEVE. SET CENTER ELEMENT OF UPPER PACKER AT 104551 CTMD. PUMP AND SHEAR OFF GH RUNNING TOOL. POOH. PATCH IS 42 FT. LONG FROM CENTER ELEMENT TO CENTER ELEMENT (104621-10504' ELM). MITIA TO 2000 PSIG PASSED. RDMO. . . **JOB COMPLETE** READY FOR SLlCKLlNE TO SET GENERIC GAS LIFT DESIGN. 07/09/05 MIRU CTU #8 - I COIL 13,951' 45K RUNNING FOOTAGE. ***JOB SCOPE - MUD ACID STIMULATION**** WEEKLY BOP TEST.... PASSED.... MU PRES. TEMP. CCL SENSOR MODUAL TO 1- COIL. TEST AND CIRCUIT BOARD NOT WORKING PROPERLY. BREAK DOWN I-COIL TOOLS. MU BHA WI 2" JSN. RIH. PUMP ACID STIMULATION PER PROCEDURE. 30 PSI PRESSURE INCREASE SEEN DURING DIVERTER STAGE. DISPLACED MUD ACID WITH 200 BBL NH4CL OVERFLUSH. DISPLACED COIL WITH MEOH. CHECK I-COIL FIBER CONTINUTITY (GOOD) RD CTU TURN WELL OVER TO DSO & ASRC. *** JOB COMPLETE*** FLUIDS PUMPED BBLS 50 METHANOL 226 50/50 METHANOL WATER 125 2% KCL WATER 50 DIESEL 635 NH4CL 1 086 TOTAL Page 1 J TREE= 4-1/16"CAMERON WELLHEAD = 13-5/8" FMC ACTuÄTÓR; .... .... ·····SÄÏ<ËR KB.· ELEV· ;-~"~---~-gj~Q'7" BI, 6 S BF:·EL8ï·;;"·· 54.61' KÓÞ::": 1262' . "....,..". ' , . , , . , . . , . . , ,.. , , , . ~~~~nQI~~ 105 @11613' Datum MD = 11666' ....,...,.."....,,,,,,,..,....,,.,..,....,..,,,..,..,,.,, Datum rvD = 8800' SS ) W-26A ~ ~ -) SAFETY NOTES: 70° @ 11366' AND 90° @ 11490' l 2141' 1-(4-1/2" HES X NIP, ID = 3.813" 1 GAS LIFT MANDRELS ST MD rvD DEV TYPE VLV LA TCH PORT DATE ~ 6 3521 3034 49 CAM DOME RK 16 06/28/05 5 6403 5032 40 CAM SO RK 20 06/28/05 4 7752 6045 45 CAM DMY RK 0 06/28/05 3 8693 6758 36 CAM DMY INT 0 06/28/05 2 9547 7435 38 CAM DMY INT 0 06/28/05 1 1 0481 8217 25 CAM DMY INT 0 06/28/05 13-3/8" CSG, 68#, L-80, ID = 12.415" l-i 3021' r--J Minimum ID = 3.725" @ 10707' 4-1/2" HES XN NIPPLE I TOP OF 7" ZXP, LNR, TOP PKR l-i 7801' TOP OF WHIPSTOCK l-i 7984' I BRIDGE PLUG l-i 8024' 9-5/8" CSG, 47#, L-80, ID = 8.681" l-r 11372' PERFORA TION SUMMARY REF LOG: BHCS ON 02/11/00 ANGLE AT TOP PERF: 41 @ 11250' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 11178 - 11198 0 04/10/02 2-7/8" 6 11222 - 11242 0 04/10/02 2-7/8" 4 11250-11264 0 02/11/00 2-7/8" 4 11276 - 11293 0 02/11/00 2-3/4" 4 11370 - 11420 0 10/09/99 2-3/4" 4 11470-11490 0 10/09/99 2-3/4" 4 11546 - 11576 0 10/09/99 2-7/8" 6 12445 - 12470 0 05/06/02 2-3/4" 4 12470 - 12530 0 10/09/99 MILLOUT WINDOW 7984' - 8000' ~ I It< I 7815' = / 1-17" X 4-1/2" HMC, LNR, HGR, PKR, ID = 6.250" x 10462'·10504" 1-13.70" BKR KB PATCH (06/25/05), ID = 2.37" 10673' 1-14-1/2" HES X NIP, ID = 3.813" 1 10685' 1-17" X 4-1/2" BKR SB-3 PKR, ID = 3.875" 1 10707' 1-14-1/2" HES XN NIP, ID = 3.725" I 10730' 1-14-1/2" WLEG, ID = 3.958" I I 10731' l-i ELMD TT LOGGED 02/11/00 1 10787' J- 7" X 4-1/2" BKR, ZXP, PKR/TIEBA CK SL V & 10801' 1_ 7" X 4-1/2" HMC, LNR, HGR, PKR, ID = 3.938" I TOP OF 4-1/2" LNR l-i 10730' I 4-1/2" TBG, 12.6#, L-80, -i 10730' BTC-M, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 12537' 4-1/2" LNR, 12.6#, IBT MOD, L-80, .0152 bpf, ID = 3.953" l-i 12620' DA TE REV BY COMMENTS 06/25/05 MDC/PJC BKR PATCH 06/28/05 DTR/TLH GLV C/O DATE 08/26/89 10/09/99 03/05/02 04/11/02 05/06/02 01/01/05 REV BY COMMENTS QUIZ ORIGINAL COM PLETION KSB SIDETRACK 9·ES RNlTP CORRECTIONS JRCITlH A DD PERFS JP/KAK ADD PERFS RWL/TLP GL V C/O PRUDHOE BA Y UNIT WELL: W-26A PERMIT No: 1990810 API No: 50-029-21964-01 SEC 21, T11 N, R12E BP Exploration (Alaska) --) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION'Š ~-~\!ED 2 , lO05 ~ ~ì!!\m¡ssion 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Repair Well 00 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D J\~Sk2l Stimulate 0 WaiverD 81.85 8. Property Designation: ADL-0028262 11. Present Well Condition Summary: 4. Current Well Class: Development ŒI Stratigraphic D 9. Well Name ançJ Number: W-26A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool ExploratoryD Service D Mcn~r.rD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 199-0810 6. API Number 50-029-21964-01-00 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 12620 feet true vertical 8863.4 feet Effective Depth measured 12537 feet true vertical 8876.4 feet Plugs (measured) Junk (measured) None None Casing Conductor Production Surface Length 80 7958 2985 Size 20" 91.5# H-40 9-5/8" 47# L-80 13-3/8" 68# L-80 MD TVD 28 108 28.0 - 108.0 26 - 7984 26.0 - 6212.6 27 - 3012 27.0 - 2691.6 Burst 1490 6870 4930 Collapse 470 4760 2270 Perforation deDth: Measured depth: 11178 -11198,11222 -11242,11250 -11264,11276 -11293,11470 -11490,11546 -11576,12445 -12470,12470 -12530 True vertical depth: 8848.62 - 8864.93,8884.12 - 8899.52,8905.47 - 8915.53,8923.78 - 8934.82,8990.87 - 8990.84,8987.12 - 8980.72 8890.21 - 8887.47,12530 - 8887.47 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 25 Sr~J~NNED t: Lr' B 0 2 2005 -' '<"1Ö7~0. ..- . Packers & SSSV (type & measured depth): 7" Baker ZXP Top Packer 4-1/2" Baker S-3 Perm Packer 7" Baker ZXP Packer 7" Baker HMC Packer @ 7801 @ 10685 @ 10787 @ 10801 RBDMS 8FL. JAN 3 1 2D05 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1450' - 3225' Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl 217 95 Bbls Arctic Set 15.7 ppg Cement wI 1/4 #/Bbl Cello Flake in first 10 Bbls @ 970 psig ReDresentative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0.6 232 960 Well Shut-in 960 Tubing Pressure 304 475 13 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations - ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] ServiceD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ~~, Form 1 0-404 Revised 4/2004 WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Title Production Technical Assistant Signature UR\G\Nt\r 564-4657 Date 1/18/05 <oJ ) ) W-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/24/04 T/I/O=1000/940/250 (lNJECTIVITYTEST) PUMPED 6 BBlS METH, FOllOWED BY 190 BBlS CRUDE DOWN OA. ESTABLISHED INJECTIVITY RATE OF 5 BPM@ 1250 PSI. FWP=11 00/11 00/700 11/30/04 OA cement squeeze. Pumped 220 bbls of flush with 20 bbls with CW1 01, 95 bbls Arctic Set 15.7 ppg cement (1/4# per bbl celloflake in first 10 bbls) and displaced with 85 bbls of crude. Est TOC @ 14501. Wait till 12/3/04 to MITOA. FLUIDS PUMPED BBLS 10 135 200 20 95 460 Methonal Crude Fresh Water CW101 Cement TOTAL Page 1 TREE= 4~/16"CAMERON ~"'" A ,. " 'WELLHEAD = 13-5/8" FMC Ä CTUÄTÖR~"""'"'" -SAKER KB. ELEV = 83.07' 'i3F~'ELï3ï ;''''''''54~61' kop;' ... .' ..... "'1262; "Mäx"'Angíe';;""'1'05"'@'11"6'1'á; N6âiUiTï'Nîo;;'''''''' . ..'"W"1'1"66'6; ,-.~"«-...,,..a'_,..~.<~~<w.....~...... ..« "-"u'"._.un_............ Datum TVD = 8800' SS ) 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 3021' Minimum ID = 3.725" @ 10707' 4-1/2" HES XN NIPPLE I TOP OF 7" ZXP, LNR, TOP PKR 1-1 7801' I TOP OF WHIPSTOCK l-i 7984' I BRIDGE PLUG 1-1 8024' 1 9-5/8" .CSG, 47#, L-80, ID = 8.681" 1-1 11372' 1 PERFORA TION SUMMARY REF LOG: BHCS ON 02/11/00 ANGLE AT TOP PERF: 41 @ 11250' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11178 -11198 0 04/10/02 2-7/8" 6 11222 - 11242 0 04/10/02 2-7/8" 4 11250 - 11264 0 02/11/00 2-7/8" 4 11276-11293 0 02/11/00 2-3/4" 4 11370 - 11420 0 10/09/99 2-3/4" 4 11470 - 11490 0 10/09/99 2-3/4" 4 11546 - 11576 0 10/09/99 2-7/8" 6 12445 - 12470 0 05/06/02 2-3/4" 4 12470 - 12530 0 10/09/99 DATE 08/26/89 1 0109/99 03/05/02 04/11/02 05/06/02 11/14/02 REV BY COMMENTS QUIZ ORIGINAL COM PLETION KSB SIDETRACK9-ES RN/TP CORRECTIONS JRCltlh A DD PERFS JP/KAK ADD ÆRFS MHlKAK GL V C/O W-26A ~ ~ SAt~), NOTES: 70° @ 11366' AND 90° @ 11490' 2141' H4-1/2" HES X NIP, ID = 3.813" 1 ~ ~ , GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH 3034 49 CAM DMY RK 5032 40 CAM DMY RK 6045 45 CAM DMY RK 6758 36 CAM DMY INT 7435 38 CAM DMY INT 8217 25 CAM DMY INT ST MD 6 3521 5 6403 4 7752 3 8693 2 9547 1 10481 PORT DATE 0 01/01/05 0 01/01/05 0 0 01/01/05 0 0 01/01/05 l MILLOUT WINDOW 7984' - 8000' i I 7815 ~17" X 4-1/2" HMC, LNR, HGR, PKR, ID = 6,250" 1 10673' H4-1/2" HES X NIP, ID = 3.813" 1 ¡ I I' 10685' H 7" X 4-1/2" BKR SB-3 PKR, ID = 3.875" I I 10707' H4-1/2" HES XN NIP, ID = 3.725" 1 I 10730' 1-14-1/2" WLEG, ID = 3.958" 1 I 10731' l-i ELMD TT LOGGED 02/11/00 1 I 10787' I- 7" X 4-1/2" BKR, ZXP, PKR/TIEBACK SL V 10801' 1- 7" X 4-1/2" HMC, LNR, HGR, PKR, ID = 3.938" ~ ~ I TOP OF 4-1/2" LNR l-i 10730' 1 4-1/2" TBG, 12.6#, L-80, -i 10730' 1 BTC-M, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 1 I PBTD 1-1 12537' 1 I 4-1/2" LNR, 12.6#, IBT MOD, L-80, .0152 bpf, ID = 3.953" l-i 12620' 1 DATE REV BY COMMENTS 04/13/04 JLJ/KA K GL V C/O 01/01/05 RWLfTLP GLV C/O PRUDHOE BA Y UNIT WELL: W-26A PERMIT No: 1990810 API No: 50-029-21964-01 SEC21, T11N, R12E BPExploration (Alaska) 1. Operations performed: ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 945' FNL, 1446' FEL, Sec. 21, T11N, R12E, UM At top of productive interval 1888' FNL, 558' FEL, Sec. 17, T11N, R12E, UM At effective depth 609' FNL, 465' FEL, Sec. 17, T11N, R12E, UM At total depth 525' FNL, 440' FEL, Sec. 17, T11 N, R12E, UM 12. Present well condition summary Total depth: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown_ Plugging _ Perforate _X Pull tubing _ Repair well _ Other _ 6. Datum elevation (DF or KB feet) RKB 82 feet 7. Unit or Property name Stimulate Alter casing _ 5. Type of Well: Development X Exploratow__ Stratigraphic Service (asp's 611789, 5959308) (asp's 607323, 5963579) (asp°s 607394, 5964859) (asp's 607417, 5964944) measured 12620 feet Plugs (measured) true vertical 8863 feet Prudhoe Bay Unit 8. Well number W-26A 9. Permit number / approval number 199-081 10. APl number 50-029-21964-01 11. Field / Pool Prudhoe Bay Oil Pool Effective depth- measured 12531 feet Junk (measured) true vertical 8877 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 138' 138' Surface 2993' 13-3/8" 4399 cf CS II 3021' 2698' Intermediate 7956' 9-5/8" 2398 cf Class 'G' 7984' 6213' Liner 3162' 7" 662 cf Class 'G' 7801'- 10963' 6078' - 8660' Sidetrack Liner 1833' 4-1/2" 280 cf Class 'G' 10787' - 12620' 8497' - 8863' Perforation depth: measured Open Perfs 11182'-11202', 11222'-11242', 11370'-11420', 11470'-11490', 11546'-11576', Open Perfs (continued) 12445'-12470', 12470'-12530' true vertical Open Perfs 8852'-8868', 8884'-8900', 8973'-8986', 8991 '-8991', 8987'-8981', Open Perfs (continued) 8890'-8887', 8887'-8878' 4-1/2", 12.6#, L-80, TBG @ 10685'. 4-1/2", 12.6# Tubing Tail @ 10731'. Top of 7" ZXP, LNR Top PKR @ 7801; 7" x 4-1/2" BKR SB-3 PKR @~6 '~' E!V E 7"x 4-1/2" HMC LNR HGR PKR @ 10801'; 4-1/2" HES X Nipple @ 2141'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 14. Representative Daily Average Production or Injection Data ~' Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 05/04/2002 1288 7961 143 264 Subsequent to operation 05/08/2002 452 15. Attachments Copies of Logs and Surveys run~ Daily Report of Well Operations ~ Oil ~X Gas _ 17. I hereby certify that the foregoing is tr~ue and correct to the best of my knowledge. ,~~~ _~~~ Tit,e: T echica, Assistant R. Schnorr 3524 47 291 16. Status of well classification as: Form 10-404 Rev 06/15/88 · Suspended ~ Service Date May 09, 2002 Prepared b ,ne R. Schnorr 564.5174 , CANNED JUN g 4: 2002 SUBMIT IN DUPLICATE '~'% W-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/05/2002 PERFORATING' PERFORATING 05/06/2002 PERFORATING' PERFORATING EVENT SUMMARY 05/05/2002 MIRU DS CTU #3. WELL ON PRODUCTION UPON ARRIVAL. RIH W/SWS MEMORY GR/CCL & DEPTHLOG TOOLS. LOG INTERVAL 12200'-12500', FLAG PIPE AT 12,300'. 05/06/2002 OOH W/MEMORY LOGS - GOOD DATA ON GR/CCL. RIH W/25' SWS GUN, 2- 7/8" HSD PJ, 6 SPF. SHOOT INTERVAL 12445'-12470'. RDMO. **NOTIFY PAD OPERATOR, LEFT WELL FLOWING.** FLUIDS PUMPED BBLS , 40 60/40 METHANOL WATER 133 DIESEL 173 TOTAL ADD PERFS 05/06/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2-7/8" PJ 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 12445' - 12470' Page 1 JUN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ ADD PERFS Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchoraqe, AK 99519-6612 4. Location of well at surface 945' FNL, 1446' FEL, Sec. 21, T11N, R12E, UM At top of productive interval 1888' FNL, 558' FEL, Sec. 17, T11N, R12E, UM At effective depth 609' FNL, 465' FEL, Sec. 17, T11N, R12E, UM At total depth 525' FNL, 440' FEL, Sec. 17, T11N, R12E, UM Perforate _ Other _ 5. Type of Well: Development __X Exploratow__ Stratigraphic__ Service__ (asp's 611789, 5959308) (asp's 607323, 5963579) (asp's 607394, 5964859) (asp's 607417, 5964944) 6. Datum elevation (DF or KB feet) RKB 82 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-26A 9. Permit number / approval number 199-081 10. APl number 50-029-21964-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2993' Intermediate 7956' Liner 3162' Sidetrack Liner 1833' 12620 feet Plugs (measured) 8863 feet 12531 feet Junk (measured) 8877 feet Size Cemented Measured Depth True Vertical Depth 20" 138' 138' 13-3/8" 4399 cf CS II 3021' 2698' 9-5/8" 2398 cf Class 'G' 7984' 6213' 7" 662 cf Class 'G' 7801' - 10963' 6078' - 8660' 4-1/2" 280 cf Class 'G' 10787' - 12620' 8497' - 8863' Perforation depth: measured Open Perfs 11182'-11202', 11222'-11242', 11370'-11420', 11470'-11490', 11546'-11576', Open Perfs (continued) 12470'-12530' true vertical Open Perfs 8852'-8868', 8884'-8900', 8973'-8986', 8991'-8991', 8987'-8981', 8887'-8878' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80, TBG @ 10685'. 4-1/2", 12.6#Tubing Tail @ 10731'. Top of 7" ZXP, LNR Top PKR @ 7801; 7" x 4-1/2" BKR SB-3 PKR @ 10685'; 7"x 4-1/2" HMC LNR HeR PKR @ 10801'; 4-1/2" HES ~i~1i~i~1,¢'"@ii'2~. &l!i?,.~ i:~ ~.. ~_~. :~ '.~, ~!'"~ ? 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 04/04/2002 Subsequent to operation 04/20/2002 OiI-Bbl 3O3 Representative Daily Averaqe Production or Iniection Data Gas-Mcr "~¢¢ate¥;Bblh (: ~isi n.~'P l'6¢"J~t] re''' Tubing Pressure Anch0ra~e 720 84 · - ,~ 916 1305 8958 150 261 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing ~ tru,e and correct to the best of my knowledge. ,~--~~~~J~l~ Title: Techical Assistant DeWayne R. Schnorr Date May 021 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 02/08/2002 02/10/2002 02/08/02 02/10/02 W-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERFOR.&TING: DRIFT/TAG PERFORATING: PERFORATING EVENT SUMMARY RAN 2 7/8" DUMMY GUN TO 11,384, TOOLS STOPPED DUE TO HAW. LEFT WELL SHUT IN & NOTIFY DSO OF WELL STATUS. PERFORATED: 11182'-11202' & 11222'-11242' (REF JEWELRY LOG 2/11/00) 2- 7/8" POWERJET, 6SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. FLUIDS PUMPED BBLS 0 NO FLUIDS PUMPED 0 TOTAL ADD PERFS 02/1 O/2OO2 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2-7/8" PJ 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 11182' - 11202' 11222' - 11242' Page 1 Date of Generation ....... 02/04/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLiB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/04/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/04/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File Scientific Technical Services Scientific Technical Services STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ ACID TREATMENT Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 82 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 945' FNL, 1446' FEL, Sec. 21, T11 N, R12E, UM (asp's 611789, 5959308) W-26A At top of productive interval 9. Permit number / approval number 1888' FNL, 558' FEL, Sec. 17, T11N, R12E, UM (asp's 607323, 5963579) 199-081 At effective depth 10. APl number 609' FNL, 465' FEL, Sec. 17, T11 N, R12E, UM (asp's 607394, 5964859) 50-029-21964-01 At total depth 11. Field / Pool 525' FNL, 440' FEL, Sec. 17, T11 N, R12E, UM (asp's 607417, 5964944) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12620 feet Plugs (measured) true vertical 8863 feet Effective depth: measured 12531 feet Junk (measured) true vertical 8877 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 138' 138' Surface 2993' 13-3/8" 4399 cf CS II 3021' 2698' Intermediate 7956' 9-5/8" 2398 cf Class 'G' 7984' 6213' Liner 3162' 7" 662 cf Class 'G' 7801'- 10963' 6078'- 8660' Sidetrack Liner 1833' 4-1/2" 280 cf Class 'G' 10787' - 12620' 8497'- 8863' Perforation depth: measured Open Peris 11370'- 11420', 11470'- 11490', 11546'- 11576',~~CFL~YE[~ true vertical Open Peris 8973'- 8986', 8991'- 8991', 8987'- 8981', 8887'- 88-~AR Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 10685'. 4-1/2", 12.6# Tubing Ta~~3~l~~ Packers & SSSV (type & measured depth) Top of 7" ZXP, LNR Top PKR @ 7801; 7" x 4-1/2" BKR SB-3 PKR @ 10685'; 7" x 4-1/2" HMC LNR HGR PKR @ 10801'; 4-1/2" HES X Nipple @ 2141'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/07/2002 209 455 46 249 Subsequent to operation 02/13/2002 394 678 328 265 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~.~"/~~~~ Title: Techical Assistant Date March 08, 2002 DeWayne R Schn~rr~. Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE W-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/09/2002 ACID: ACID TREATMENT 02/10/2002 ACID: ACID TREATMENT EVENT SUMMARY 02/09/02 MIRU DOCT #3. PUMP WELL KILL W/KCL. TAG 12531' CTM. 02/1 O/O2 FP BACKSIDE. JET 20 BBLS 12% HCL/10% XYLENE (HCL ACID; TITRATION 12.2%, FE > 50 PPM) INTO PERFS. SOAK F/30-MIN. JET REMAINING 55 BBLS 12% DAD OVER PERFS 11250'-11521' CTM. OVER-DISPLACE ACID INTO FORMATION W/FILTERED 1% KCL. POOH. *** TURN WELL OVER TO PAD OPERATOR AND PCC TO POP ASAP *** FLUIDS PUMPED BBLS 65 60/40 METHANOL WATER 190 1% KCL WATER (FILTERED) 75 12% HCL / 10% XYLENE 23O TOTAL Page 1 DATA SUBMITTAL COMPLIANCE REPORT 2/$/2O02 Permit to Drill No. 1990810 Well Name/No. PRUDHOE BAY UNIT W-26A Operator BP EXPLORATION (ALASKA) [NC APl No. 50-029-21964-01-00 MD 12620 TVD 8863 Completion Date 10/6/1999 ~ Completion Status I-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No -- DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name Interval Log Log Run O!t / Dataset Scale Media No Start Stop CH Received Number Comments ................ O"'USiT ............... ,~ ............. ~i-~1~[ ...... ,~9~74 .......~z734- ....C'H ' 9/3o/i'999 BEiC) Dii8/99 ............. ~5 ~.. SRVY RPT 25 12620 OH 10,25,1999 SPERRY 7955.. Cl~ MEMPROD-SPIN/ 5 FINAL 10500 12530 CH 12/29/1999 TEM/PRES 12/9/99089 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chigs-l?~ei-vod2~ Y / N Daily History Received? Formation Tops Receuived? Compliance Reviewed By: ............................. Date: ....................... 4~6~00 GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 All'N: Sherrie NO. 121350 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints G-21 PSP PRODUCTION PROFILE 000319 1 1 W-26A t=~ ~.~ ~ H 20016 USIT/PDC/GR 990918 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP. Exploration (Alaska)inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED APB 10 2000 Alaska Oil 8, Gas Co~S. commission Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99~.503-5711 Al-tN: Sherrie /' ) ~ - ---/', Received b .~~'~~ GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121039 Company: Field: Alaska OII & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 12/22/99 Well Job # Log Description Date Blueline Sepia Color CD Prints W-26A MEMORY PRODUCTION PROFILE 991209 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED L.~-('.' ~9 F)99 ,a&mmk~ ~ & ~ C, mls. Com~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al-tN: Sherri~) Received b .'y~t ~ STATE OF ALASKA OCT' 2 $ t~9 ~ ALASKA OIL AND GAS CONSERVATION COMMISSION '~/as&~0il4 ~SCon ~' WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~Choraq~ C°~f~lO- 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned I--I Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 99-081 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21964-01 4. Location of well at surface 9. Unit or Lease Name 945' SNL, 1446' WEL, SEC. 21 T11N, R12E, UM --. ................... Prudhoe Bay Unit , ~;!:~,~:.:'i.,:-i'~ ~,.:~,: . 10. Well Number At top of productive interval ',~__~', ~'?~; J t 3391' NSL, 558' WEL, SEC. 17, T11N, R12E, UM :i.~,2'~'~_ W-26A Attotal depth~/-~~ r'..;i~ir:~-?~ ~ 11. Field and Pool 4756' NSL, 452' WEL, SEC. 17, T11N, R12E, UM -:-~-'"~'~-~ . ! Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease'Designatiomand Serial No. Pool KBE: 81.85'I ADL 028262 12. Date Spudded9/20/99 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 116' N°' °f C°mpleti°nsl 0/1/99 10/6/99 N/A MSL One 17. Total Depth (MD+TVD) 118. P~ug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set121. Thickness of Permafrost 12620 8863 FTI 12537 8876 FT []Yes []No! (Nipple) 2141' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run USIT, MWD, GR, DIP, 4-PhaseRES, PWD, LWD, CNL 0RI G,~! ~' 23. CASING, LINER AND CEMENTING RECORD i I ~ /~ l .... CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Insulated Conductor Surface 110' 13-3/8" 68# L-80 Surface 3021' 17-1/2" 4399 cu ft Coldset II 9-5/8" 47# NT-80S Surface 7984' 12-1/4" 2398 cu ft Class 'G' 7" 26# L-80 7801' 10963' 8-1/2" 662 cu ft Class 'G' 4-1/2" 12.6# L-80 10787' 12620' 6" 280 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10730' 10685' MD TVD MD TVD 11370' - 11420' 8973' - 8986' 11470' - 11490' 8991' - 8991' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11546' - 11576' 8987' - 8981' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12470' - 12530' 8887 - 8878' Freeze Protect with 155 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) October 19, 1999 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CEPH) Press. D 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers : 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Sag River 10954' 8652' Shublik 'A' 10991' 8686' Shublik 'B' 11055' 8744' Shublik 'C' 11078' 8764' Sadlerochit / Zone 4B 11144' 8820' Zone 4A 11318' 8949' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify thatsigned the~r~,~foregoing is~true and correct to the best of my knowledge Terrie Nubble .... Title Technical Assistant Ill Date W-26A 99-081 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility PB W Pad Date/Time Duration 07 Scp 99 11:30-06:00 18-1/2 hr 11:30-06:00 18-1/2 hr 08 Sep 99 Progress Report 09 Sep 99 Well W-26A Page 1 Rig Nabors 9ES Date 06 October 99 11:30-06:00 18-1/2 hr 06:00-06:00 24 hr 06:00-19:00 13 hr 19:00 19:00-00:30 5-1/2 hr 00:30 00:30-06:00 5-1/2 hr 00:30-06:00 5-1/2 hr 00:30-06:00 5-1/2 hr 00:30-06:00 5-1/2 hr Activity Move rig Rig moved 50.00 % Move satellite camp, tool shed and pit module from S to W pad w/o incident. Move rig sub in stages to S pad access - Spine Road intersection. No problems. Rig moved 50.00 % Moving rig sub base. Staged rig sub at S pad access - Spine Road intersection. Moved mats/plywood around rig on Spine Road. Begin moving west down Spine Rd (1900 hrs). Move rig (cont...) Rig moved 50.00 % (cont...) Moving rig sub base. Staged rig sub at S pad access - Spine Road intersection. Moved mats/plywood around rig on Spine Road. Begin moving west down Spine Rd (1900 hrs). Operation stopped due to Incident Rig broke through road. Rig waited: Other delays Cut timber & crib up rig. Drive rig out of 4' hole/trench in Spine Road w/assistance of 2 trucks and 1 CAT. Resumed operations Rig moved 65.00 % Leapfrogging rig on mats towards W-pad access road. Rig moved 65.00 % Continue leapfrogging rig on mats toward W-pad access road. Have made about 1,000' progress - about 2,000' remaining to W-Pad access road. Rig moved 65.00 % Pulled rig backwards onto rig mats out of deep soft spot. Lay plywood and mats behind rig to allow startup of leap frogging procedure again. Arrived at Expl. Pad at 0200 hrs. Let trucks through to service camps (water, sewage, etc). Rig moved 65.00 % Continue moving down W-Pad Access Rd. Rig broke through road twice. 5 hrs each time working out of holes. Third breakthrough next to water now has all four sets of tires buried. Will pull backwards onto mats and begin leap frogging. 00:30-06:00 5-1/2 hr 00:30-06:00 5-1/2 hr Rig moved 65.00 % Continue moving rig via leap frogging. Soft road conditions (rain) resulting in mats sinking through road. PU mats, lay plywood and relay mats above. Rig arrived at W-Pad Access Road at 0400 hrs. Currently moving mats/plywood around rig. Rig moved 65.00 % · ig · ..~UIILIIILI~, lllOt311../l.y WUUU O..l UIAIILI F . OtO. l L Facility Date/Time lOSep99 11 Sep 99 12 Sep 99 13 Sep 99 14 Sep 99 15 Sep 99 16 Sep 99 Progress Report PB W Pad Well W-26A Page 2 Rig Nabors 9ES Date 06 October 99 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-03:00 03:00 Duration 24 hr 24 hr 24 hr 24 hr 24 hr 24 hr 24 hr 24 hr 24 hr 24 hr 24 hr 24 hr 24 hr 21 hr Activity move up W-Pad access road at 1500 hrs. Make Move rig (cont...) Rig moved 80.00 % (cont...) Continue moving mats/plywood around rig. Start move up W-Pad access road at 1500 hrs. Make 500' before breaking through access road. Crib up while laying mats ahead of rig. Test 300' on plywood. OK. Now LD 3 rows plywood to Expl. Pad turnout. Move rig (cont...) Rig moved 82.00 % (cont...) Continue moving mats/plywood around rig. Start move up W-Pad access road at 1500 hrs. Make 500' before breaking through access road. Crib up while laying mats ahead of rig. Test 300' on plywood. OK. Now LD 3 rows plywood to Expl. Pad turnout. Move rig (cont...) Rig moved 85.00 % (cont...) Continue moving mats/plywood around rig. Start move up W-Pad access road at 1500 hrs. Make 500' before breaking through access road. Crib up while laying mats ahead of rig. Test 300' on plywood. OK. Now LD 3 rows plywood to Expl. Pad turnout. Move rig (cont...) Rig moved 87.00 % (cont...) Continue moving mats/plywood around rig. Start move up W-Pad access road at 1500 hrs. Make 500' before breaking through access road. Crib up while laying mats ahead of rig. Test 300' on plywood. OK. Now LD 3 rows plywood to Expl. Pad turnout. Move rig (cont...) Rig moved 90.00 % (cont...) Continue moving mats/plywood around rig. Start move up W-Pad access road at 1500 hrs. Make 500' before breaking through access road. Crib up while laying mats ahead of rig. Test 300' on plywood. OK. Now LD 3 rows plywood to Expl. Pad turnout. Move rig (cont...) Rig moved 90.00 % Transfer plywood and mats in front of rig from exploration pad towards culvert area. @ 1800 hrs Roads and pads hauled in gravel and compactors to raise road over culverts to 6 ft. Completed @ 0300 hrs. Currently matting remainder of road. Move rig (cont...) Rig moved 95.00 % Stage plywood and mats from behind rig to in front of rig. Move rig towards culvert. Leap frog more mats. Move across culvert @ 2300 hrs. Leapfrog mats. Move onto W-pad @ 0300 hrs At well location - Cellar Facility Date/Time 17 Sep 99 Progress Report PB W Pad Well W-26A Page 3 Rig Nabors 9ES Date 06 October 99 03:00-06:00 06:00-18:00 06:00-11:30 11:30 11:30-12:30 12:30 12:30-18:00 18:00 18:00-20:00 18:00-20:00 20:00 Duration 3hr 12hr 5-1/2 hr lhr 5-1/2 hr 2hr 2hr Activity Installed Drillfloor / Derrick With rig in front of well inspect and raise derrick. ( Very little room for manoevre). Commence laying herculite and matting boards in preparation for spotting rig. Simultaneausly rig up drillfloor equipment. Move rig (cont...) Rig moved 100.00 % At well location - Cellar Prepare well location, lay herculite and matting boards. Spot rig over W-26A. Lower blocks and hook up Top drive Held safety meeting Completed operations Hold Safety stand down with both crews. Conduct prespud meeting. Installed Fluid system Equipment work completed Spot pit module, camp, cuttings tank and workshop. Continue to bern and make ready to take on fluid. Fluid system Fill pits with Seawater Completed operations Take on seawater and pressure test lines. Continue to rig up and clear rigfloor. 20:00-06:00 20:00-21:30 21:30 21:30-00:30 00:30 00:30-01:00 01:00 01:00-02:00 02:00 02:00-03:30 03:30 03:30-06:00 06:00-12:30 06:00-09:00 09:00 09:00-12:30 12:30 10hr 1-1/2 hr 3hr 1/2 hr lhr 1-1/2 hr 2-1/2 hr 6-1/2 hr 3hr 3-1/2 hr Rig Accepted @ 1800 hrs on 16th September. Wellhead work Removed Hanger plug Equipment work completed Hook up DSM Lubricator and remove BPV. 100 psi under BPV.. R/D DSM. Circulated at 9990.0 ft Obtained bottoms up (100% annulus volume) Circulate well thru choke @ 85 SPM/725 psi. Flow check Began precautionary measures Flowcheck well- still out of balance. Circulated at 9990.0 ft Began precautionary measures Reverse circulated. Installed Hanger plug Equipment work completed Flowcheck- OK. Install TWC and pressure test from below to 1000 psi- good. Rigged down Xmas tree N/D X-mas tree. BOP/riser operations - BOP stack Rigged up BOP stack Equipment work completed Tested BOP stack Pressure test completed successfully - 3500.000 psi R/U and test BOPE to 250/3500 psi. AOGCC waived witness of test. R/D test joint. Facility Date/Time 18 Sep 99 19 Sep 99 PB W Pad Progress Report Well W-26A Page 4 Rig Nabors 9ES Date 06 October 99 12:30-13:30 12:30-13:30 13:30 13:30-01:30 13:30-15:00 15:00 15:00-01:30 01:30 01:30-03:30 01:30-03:30 03:30 03:30-06:00 03:30-06:00 06:00 06:00-02:30 06:00-09:30 09:30 09:30-13:00 13:00 13:00-13:30 13:30 13:30-19:00 19:00 19:00-20:30 20:30 20:30-21:30 21:30 21:30-23:45 23:45 23:45-02:30 02:30 02:30-06:00 02:30-06:00 Duration lhr lhr 12hr 1-1/2 hr 10-1/2 hr 2hr 2hr 2-1/2 hr 2-1/2 hr 20-1/2 hr 3-1/2 hr 3-1/2 hr 112 hr 5-1/2 hr 1-1/2 hr lhr 2-1/4 hr 2-3/4 hr 3-1/2 hr 3-1/2 hr Activity Wellhead work Retrieved Hanger plug Equipment work completed Check for pressure and recover TWC with dry rod. Pull Gas lift completion, 3-1/2in O.D. Retrieved Tubing hanger Equipment work completed Ensure LDS out. R/U and screw in to tubing hanger. Pull free- 15 klbs o/pull. String weight 115 klbs including block weight. Montor well. Laid down 9990.0 ft of Tubing Completed operations Lay down 313 joints 3.1/2" tubing, 4 x GLM and SSSV. 33 clamps and x 2 SS bands recovered. Tubing in OK condition. Wellhead work Installed Seal assembly Equipment work completed Pull 9.5/8" pack-off and replace same- test to 5000 psi- good. Electric wireline work Conducted electric cable operations Observed 400.00 klb resistance R/U Schlumberger USIT tool and RIH. Observe resistance @ 1000 ft- 300-400 lb. Ensure OK coming up. RIH with weightloss to 2050 ft- unable to progress further. Attempt to run past 10-12 times. No go. OD tool is 6.6 ". POOH. Tools OK. BHA run no. 1 Made up BHA no. 1 BHA no. 1 made up Make up Whipstock milling assembly for cleanout run. Singled in drill pipe to 3200.0 ft Began precautionary measures No problems at 2050 ft. Circulated at 3200.0 ft Obtained bottoms up (100% annulus volume) Some gas breakout at surface. Singled in drill pipe to 9871.0 ft 280 joints picked up Circulated at 9871.0 ft Obtained bottoms up (100% annulus volume) Serviced Block line Line slipped Slip line and service top drive. Pulled out of hole to 1000.0 ft At BHA Pulled BHA BHA Stood back Electric wireline work Conducted electric cable operations R/U and run USIT long. Logging at report time. Cement @ 8000 ft. Provisional top @ 6,250 ft. Facility Date/Time PB W Pad Duration 4-1/2 hr 1/2 hr 06:00-10:30 06:00-06:30 06:30 4hr 06:30-10:30 10:30 19-1/2 hr 3hr 10:30-06:00 10:30-13:30 13:30 13:30-18:30 18:30 5hr 1/2 hr 18:30-19:00 19:00 19:00-20:30 20:30 1-1/2 hr 7hr 20:30-03:30 20 Sep 99 03:30 03:30-05:00 05:00 1-1/2 hr lhr 5-1/2 hr 3hr 2hr 05:00-06:00 06:00 06:00-11:30 06:00-09:00 09:00 09:00-11:00 11:00 11:00-11:30 11:30 1/2 hr 18-1/2 hr 2-1/2 hr 11:30-06:00 11:30-14:00 14:00 Progress Report Well W-26A Page 5 Rig Nabors 9ES Date 06 October 99 Activity Electric wireline work (cont...) Conducted electric cable operations Completed run with Cement evaluation tool frorn~5000.0 ft to 9734.0 Complete run with USIT log. Cement @ 8000 ft. Evidence of cement top @ 6,250 ft with some channelling above this depth. Conducted electric cable operations Completed run with Bridge plug from 8024.0 ft to 8024.0 ft R/U and run Halliburton EZSV on wireline. Correlate and set plug 3 ft below collar @ 8,024'. POOH and R/D Schlumberger. BHA run no. 2 Made up BHA no. 2 BHA no. 2 made up M/U Whipstock BHA and check orientation. RIH to first joint drillpipe. Check MWD- OK. R.I.H. to 7950.0 ft Began precautionary measures RIH checking MWD every 3000 ft. Functioned downhole tools at 8015.0 ft Equipment work completed Orientate Whipstock. Tag Bridge plug @ 8,015' and set bottom anchor w/20 klbs. Shear bolt w/45 klbs. Whipstock orientation 35 degrees left high side. Circulated at 7984.0 ft Hole displaced with Water based mud - 100.00 % displaced Displace well to 10.6 ppg Milling Fluid @ 375 GPM/ 1400 psi. Pipe static. Milled Casing at 7984.0 ft Completed operations Mill window in 9.5/8" from 7,984 to 8,000. Formation to 8,022 ft. Cement and formation seen on bottoms up. 190 lb metal recovered. Circulated at 8022.0 ft Obtained bottoms up (100% annulus volume) Sweep hole clean. Wipe thru window- clean. Serviced Block line Line slipped and cut BHA run no. 2 (cont...) Pulled out of hole to 1000.0 ft At BHA Pulled BHA BHA Laid out Inspect mills. Top Mill in gauge. 40% wear on lower mill. Circulated at 40.0 ft Began precautionary measures Flush BOP Stack with jetting tool. BHA run no. 3 Made up BHA no. 3 BHA no. 3 made up M/U BHA # 3 with PDC directional assembly w/1 deg Bend. Surface tcst~v~ ........ ,, ~, ,~,,~,~' motor. Facility Date/Time 21 Sep 99 22 Sep 99 23 Sep 99 PB W Pad Progress Report Well W-26A Page 6 Rig Nabors 9ES Date 06 October 99 14:00-16:00 16:00 16:00-17:30 17:30 17:30-06:00 06:00-06:00 06:00-02:30 02:30 02:30-03:00 03:00 03:00-03:30 03:30 03:30-05:00 05:00 05:00-06:00 06:00-06:00 06:00-23:00 23:00 23:00-00:00 00:00 00:00-00:30 00:30 00:30-01:00 01:00 01:00-06:00 06:00-07:00 06:00-07:00 Duration 2hr 1-1/2 hr 12-1/2 hr 24 hr 20-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr 24 hr 17 hr lhr 1/2 hr 1/2 hr 5hr lhr lhr Activity R.I.H. to 6560.0 ft Stopped · To pick up/lay out tubulars Singled in drill pipe to 7900.0 ft 45 joints picked up RIH picking up required 4" drillpipe to drill to section TD. Drilled to 8156.0 ft Orientate and slide thru window. Slide ahead kicking off well. Problems making progress. Parameters suggest bit balling- pump nut plug and sap pills. Help periodically. BHA run no. 3 (cont...) Drilled to 8902.0 ft Started scheduled wiper trip: due to Footage drilled Directionally drill 8.1/2" hole f 8,156' to 8,902'. Periodically vary parameters to gain optimum performance. Hard stringers encountered. No drag on connections. No losses. BHA dropping about 1 deg / 100 in rotary. Circulated at 8902.0 ft Obtained bottoms up (100% annulus volume) Circulate hole clean. Pulled out of hole to 8004.0 ft At top of check trip interval POOH to window at 8,004. Some tugs of 15 klbs o/pull. Serviced Block line Line slipped and cut R.I.H. to 8902.0 ft RIH and prepare to drill ahead 8.1/2" hole. BHA run no. 3 (cont...) Drilled to 9738.0 ft Started scheduled wiper trip: due to Footage drilled Directionally drill 8.1/2" hole f/8,902 ft to 9,738 ft sweeping hole periodically. No drag on connections. Sliding 10% of time. No losses. Adding SAPP to pre-empt bit balling. Circulated at 9738.0 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 8902.0 ft At top of check trip interval Make wiper trip through Miluveach Shales. Hole OK. R.I.H. to 9738.0 ft On bottom Drilled to 9927.0 ft Drill Ahead through Kingak 8.1/2" hole. Pressures a little high for flowrate. May have nozzle plugged. BHA run no. 3 (cont...) Drilled to 10020.0 ft (cont...) Drill Ahead through Kingak 8.1/2" hole. Pressures a lll. l. lU 111~11 IUI IIUVVII:St[U, l¥10%y 11~1,¥~,, IIULLI~, Facility Date/Time 24 Sep 99 25 Sep 99 PB W Pad Progress Report Well W-26A Page 7 Rig Nabors 9ES Date 06 October 99 07:00 07:00-18:00 07:00-09:00 09:00 09:00-17:00 17:00 17:00-17:45 17:45 17:45-18:00 18:00 18:00-06:00 18:00-06:00 06:00-12:00 06:00-12:00 12:00 12:00-18:00 12:00-12:45 12:45 12:45-15:00 15:00 15:00-18:00 18:00 18:00-06:00 18:00-19:45 19:45 19:45-20:00 20:00 20:00-06:00 06:00-21:30 06:00-06:05 06:05 06:05-08:00 08:00 08:00-09:30 Duration llhr 2hr 8hr 314 hr 12hr 12hr 6hr 6hr 6hr 3/4 hr 2-1/4 hr 3hr 12hr 1-3/4 hr 1/4 hr lOhr 15-1/2 hr Ohr 1-3/4 hr 1-1/2 hr Activity plugged. Mud pump fluid end failed - Pull back to shoe Repair Pulled out of hole to 7950.0 ft POH to window. Hole in good shape. At Window · 7984.0 ft Repaired Mud pump fluid end Change out #1 cylinder on #1 mud pump. Serviced Top Drive. Work completed, Mud pump fluid end changed out R.I.H. to 9930.0 ft No problems RIH. Began precautionary measures Reamed to 10020.0 ft Precautionary ream last stand. On bottom BHA run no. 3 Drilled to 10415.0 ft Drlg Kingak. Sliding as necessary. BHA run no. 3 (cont...) Drilled to 10673.0 ft (cont...) Drlg Kingak. Sliding as necessary. Mud pump fluid end failed - Pull back to shoe Repair Circulated at 10673.0 ft CBU. Monitor well. Pump dry job. Obtained bottoms up (100% annulus volume) Pulled out of hole to 7984.0 ft At Window · 7984.0 ft Repaired Mud pump fluid end Change out #3 cylinder on #2 pump. Slipped 40' drlg line & serviced TD while working on pump (1 hr). Spill drill; OS: 1:30 min. Work completed, Mud pump fluid end changed out BHA run no. 3 R.I.H. to 10600.0 ft No problems RIH. Began precautionary measures Reamed to 10673.0 ft Ream down last stand. No problems. On bottom Drilled to 10962.0 ft Bit acted balled-up. Pumped nutplug & SAPP sweeps. Helped some, but PR never came back to previous rate. BHA run no. 3 (cont...) Drilled to 10965.0 ft (cont...) Bit acted balled-up. Pumped nutplug & SAPP sweeps. Helped some, but PR never came back to previous rate. Reached planned end of run - Section / well T.D. Circulated at 10965.0 ft Circ Hi-Vis & condition mud. Hole swept with slug - 150.00 % hole volume Pulled out of hole to 9700.0 ft Facility Date/Time PB W Pad 09:30 09:30-10:00 Duration 10:00 10:00-12:30 12:30 12:30-13:30 13:30 13:30-14:00 14:00 14:00-19:00 2-1/2 hr lhr 1/2 hr 5hr 19:00 19:00-21:30 2-1/2 hr 21:30 21:30-06:00 21:30-23:00 23:00 23:00-00:00 26 Sep 99 00:00 00:00-04:00 04:00 04:00-04:30 04:30 04:30-06:00 8-1/2 hr 1-1/2 hr lhr 4hr 06:00-14:00 06:00-07:30 1-1/2 hr 8hr 1-1/2 hr Progress Report 07:30 07:30-08:30 08:30 08:30-10:00 Well W-26A Page 8 Rig Nabors 9ES Date 06 October 99 lhr 1-1/2 hr Activity 10:00 10:00-14:00 14:00 14:00-21:30 14:00-16:30 4hr 7-1/2 hr 2~1/2 hr At top of check trip interval R.I.H. to 10965.0 ft 1' fill on bottom. Hole in good shape. On bottom Circulated at 10965.0 ft Circ & cond while rotating & reciprocating. Wt up to 10.9#. D2 Drill: OS-55 sec. Obtained req. fluid properties - 200.00 %, hole vol. Circulated at 10965.0 ft Spot liner running pill. Hi-Vis mud spotted downhole Dropped EMSS survey barrel Survey barrel on bottom at 10810.0 ft Pulled out of hole to 872.0 ft POH. SLM. Check f/flow @ window-OK. Pump dry job. Drop rabbit. POH. D1 Drill: OS-1:30 min. At BHA Pulled BHA Recovered rabbit & EMS. SLM-OK. BHA Laid out Run Liner, 7in O.D. Rigged up Casing handling equipment Clear floor. RU casing tools. Work completed - Casing handling equipment in position Held safety meeting PJSM-Running liner. Waited 45 min on float collar. Made-up collar on location was a landing collar. Completed operations Ran Liner to 3160.0 ft (7in OD) PU 77 its 7", 26g, L-80, BTC-Mod. MU Baker 'HMC' Hanger & 'ZXP' Liner Top Packer. Stopped: To circulate Circulated at 3160.0 ft Circ liner volume. Broke circulation Ran Liner on landing string to 5200.0 ft Filling pipe every 10 stds. Run Liner, 7in O.D. (cont...) Ran Liner on landing string to 7937.0 ft (cont...) Filling pipe every 10 stds. At Window: 7984.0 ft Circulated at 7937.0 ft Obtained bottoms up (100% annulus volume) Ran Liner on landing string to 9988.0 ft Started taking wt. Unable to work down. Observed loss of 50.00 klb string weight Washed to 10965.0 ft Washed to bottom w/45 spin. Attempted to RIH a couple of times with no success. Tag bottom and PU 2'. On bottom Cement: Liner cement Circulated at 10963.0 ft Gradually work rate up f/3 to 7 bpm. Facility Date/Time 27 Sep 99 PB W Pad Progress Report Well W-26A Page 9 Rig Nabors 9ES Date 06 October 99 16:30 16:30-17:00 17:00 17:00-18:15 18:15 18:15-18:45 18:45 18:45-19:00 19:00 19:00-21:00 21:00 21:00-21:30 21:30 21:30-00:00 21:30-00:00 00:00 00:00-00:15 00:00-00:15 00:15 00:15-01:45 00:15-01:45 01:45 01:45-02:00 01:45-02:00 02:00 02:00-06:00 02:00-05:30 05:30 05:30-06:00 06:00-13:30 06:00-07:00 Duration 1/2 hr 1-1/4 hr 1/4 hr 2hr 1/2 hr 2-1/2 hr 2-1/2 hr 1/4 hr 1/4 hr 1-1/2 hr l- 1/2 hr 1/4 hr 1/4 hr 4hr 3-1/2 hr 1/2 hr 7-1/2 hr lhr Activity Obtained clean returns - 200.00 % hole volume Held safety meeting Completed operations Mixed and pumped slurry - 118.000 bbl Precede cement w/30 bbls ARCO spacer @ 11.4 ppg. Cement w/100 bbls ( 200 sxs ) Premium 'G' @ 11.5 ppg; tail in w/18 bbls ( 84 sxs ) Premium 'G' @ 15.8 PPg. Cement pumped Displaced slurry - 195.000 bbl Displace slurry @ 7 bpm. Slowed down to observe wiper dart latch-up. Bumped plug w/calculated strokes ( 97% eft.). Plug bumped Functioned Liner hanger Set liner hanger w/3000 psi; increased to 4500 psi to set liner top packer. Release from liner w/20 rds to the right. Pressure DP to 1000 psi and sting out. Equipment work completed Reverse circulated at 7801.0 ft Reversed -20 bbls cement. Reversed till hole was clean. Set down on liner top-OK. Obtained clean returns - 200.00 % hole volume Rigged down Cement head LD cement hd & single. Work completed, equipment laid out Pull Drillpipe, 4in O.D. Pulled Drillpipe in stands to 0.0 ft POH. LD liner running tool. Retrieved 0.0 ft from Other sub-surface equipment Wellhead work Removed Wear bushing Pull wear ring & set test plug. Equipment work completed Test well control equipment Tested BOP stack Test all BOPE to 250 / 3500 psi (tested choke manifold on trip out). Witnessing waived by John Crisp-AOGCC Field Inspector. Pressure test completed successfully - 3500.000 psi Wellhead work Installed Wear bushing Pull test plug & set wear ring. Eqpt. work completed, running tool retrieved BHA run no. 4 Made up BHA no. 4 PJSM. PU Sperry BHA. Orient tools. Load source. Finish PU BHA. Surface test tools. BHA no. 4 made up R.I.H. to 1500.0 ft BHA run no. 4 (cont...) Serviced Block line Cut 80' & slip 40'. Facility Date/Time 28 Sep 99 ! PB W Pad 07:00 07:00-11:00 11:00 11:00-11:30 Progress Report Well W-26A Page 10 Rig Nabors 9ES Date 06 October 99 11:30 11:30-13:30 13:30 13:30-14:00 13:30-14:00 14:00 14:00-06:00 14:00-16:45 16:45 16:45-17:00 17:00 17:00-21:30 21:30 21:30-06:00 21:30-06:00 06:00-23:30 06:00-14:00 14:00 14:00-16:00 16:00 16:00-20:30 20:30 20:30-23:30 23:30 23:30-06:00 23:30-01:00 29Sep99 01:00 01:00-03:30 03:30 03:30-04:00 Duration 4hr 1/2 hr 2hr 1/2 hr 1/2 hr 16hr 2-3/4 hr 1/4 hr 4-1/2 hr 8-1/2 hr 8-1/2 hr 17-1/2 hr 8hr 2hr 4-1/2 hr 3hr 6-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr Activity Line slipped and cut R.I.H. to 10853.0 ft RIH. Saw liner top @ 7802'. Began precautionary measures Washed to 10879.0 ft Wash down to insert landing collar. On bottom Circulated at 10879.0 ft Obtained bottoms up (100% annulus volume) Perform integrity test Tested Liner Test casing, liner & top of liner f/30 rain-OK. Pressure test completed successfully - 3000.000 psi BHA run no. 4 Drilled installed equipment - Landing collar Drld LC, FC, cement, & FS. Completed operations Drilled to 10975.0 ft Drill 10' new hole. Stopped: To circulate Circulated at 10966.0 ft Monitor well-no losses. Pump 80 bbls water, 40 bbls spacer, & changeover to 8.4 ppg QuikDriln. No losses during swapover. Check f/flow-OK. Spill drill-OS- 1:30 min. Hole displaced with Water based mud - 100.00 % displaced Drilled to 11100.0 ft Drlg 6 1/8" hole. Started out slow until mud sheared & wanned up. Drilled to 11100.0 ft Drilled f/11,100' to 11,247'. AST= 4.0 hrs ART= 1.25 hrs BHA not builing angle at acceptable rate. BHA run no. 4 (cont...) Drilled to 11247.0 ft (cont...) Drilled f/11,100' to 11,247' AST= 4.0 hrs ART= 1.25 hrs BHA not builing angle at acceptable rate. Build rate unacceptable - BHA Circulated at 11247.0 ft Obtained clean returns - 150.00 % hole volume Pulled out of hole to 215.0 ft At BHA Pulled BHA POH. Download MWD/LWD data. Change MWD probe, motor. BHA Stood back BHA run no. 5 Made up BHA no. 5 P/U motor and bit #3. Adjusted motor to 2.12 deg. Orient and load source. BHA no. 5 made up R.I.H. to 7670.0 ft Tested MWD 10 stds in. Stopped: To service drilling equipment Serviced Top drive Facility Date/Time 30 Sep 99 01 Oct 99 02 Oct 99 PB W Pad Progress Report Well W-26A Page 11 Rig Nabors 9ES Date 06 October 99 04:00 04:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-16:00 16:00 16:00-18:30 18:30 18:30-19:30 19:30 19:30-20:45 20:45 20:45-21:00 21:00 21:00-21:30 21:30 21:30-22:30 22:30 22:30-02:30 02:30 02:30-06:00 06:00-12:00 06:00-09:00 09:00 09:00-12:00 12:00 Duration 1-1/2 hr 24 hr 24 hr 24 hr 24 hr 24 hr 10hr 2-1/2 hr lhr 1-1/4 hr 4hr 3-1/2 hr 6hr 3hr 3hr Activity Equipment work completed R.I.H. to 11247.0 ft No hole problems. On bottom Drilled to 11250.0 ft Orient and begin sliding ahead at report time. Drilled to 11250.0 ft Drilled ahead sliding for angle and direction from 11,250' to 11,731'. ART=2 hrs AST=17 hrs BHA run no. 5 (cont...) Drilled to 11731.0 ft (cont...) Drilled ahead sliding for angle and direction from 11,250' to 11,731 '. ART=2 hrs AST= 17 hrs BHA run no. 5 (cont...) Drilled to 12408.0 ft Drilled from 11,731' to 12,408' as per directional plan. ART= 16 hrs AST= 6 hrs BHA run no. 5 (cont...) Drilled to 12620.0 ft (cont...) Drilled from 11,731' to 12,408' as per directional plan. ART= 16 hrs AST= 6 hrs Reached planned end of run - Section / well T.D. Circulated at 12620.0 ft Pump high/low visc sweeps and circ hole clean. Obtained clean returns - 200.00 % hole volume Pulled out of hole to 11328.0 ft Stopped to MAD pass while POH for short trip. Stopped: To take survey Logged hole with LWD: Formation evaluation (FE) from 11328.0 ft to 11231.0 ft Correlation log to check resistivity tool as per Geology. Completed operations Pulled out of hole to 10952.0 ft At 7in casing shoe Serviced Block line Line slipped R.I.H. to 12620.0 ft Hole in good shape. On bottom Circulated at 12620.0 ft Pump hi/low visc sweeps. Circ hole clean. Spotted liner running pill. Obtained clean returns - 300.00 % hole volume Pulled out of hole to 7000.0 ft POH to shoe. Dropped 2.25" rabbit. POH SLM. BHA run no. 5 (cont...) Pulled out of hole to 217.0 ft (cont...) POH to shoe. Dropped 2.25" rabbit. POH SLM. At BHA Pulled BHA Pulled neutron source. Download MWD/LWD data. Clear floor. BHA Laid out Facility Date/Time 03 Oct 99 PB W Pad Progress Report Well W-26A Page 12 Rig Nabors 9ES Date 06 October 99 12:00-23:00 12:00-12:30 12:30 12:30-15:00 15:00 15:00-19:00 19:00 19:00-19:30 19:30 19:30-20:30 20:30 20:30-23:00 23:00 23:00-01:30 23:00-00:30 00:30 00:30-01:30 01:30 01:30-05:30 01:30-03:00 03:00 03:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00-13:30 06:00-07:30 07:30 07:30-09:00 09:00 09:00-13:00 13:00 13:00-13:30 13:30 Duration llhr 1/2 hr 2-1/2 hr 4hr 1/2 hr lhr 2-1/2 hr 2-1/2 hr 1-1/2 hr lhr 4hr 1-1/2 hr 2-1/2 hr 7-1/2 hr 1-1/2 hr 1-1/2 hr 4hr Activity Run Liner, 4-1/2in O.D. Rigged up Casing handling equipment Held PJSM. Finish R/U to run liner. Equipment work completed Ran Liner to 1843.0 ft (4-1/2in OD) Stopped: To change handling equipment Ran Drillpipe in stands to 10960.0 ft Stopped: To circulate Circulated at 10960.0 ft Break circulation at shoe. Broke circulation Ran Drillpipe in stands to 12620.0 ft Ran liner to bottom. Tight around kickoff doglegs. On bottom Circulated at 12620.0 ft Circ. Held PJSM. Batch mix cement while circulating. Obtained clean returns - 150.00 % hole volume Cement: Liner cement Mixed and pumped slurry - 50.000 bbl Pump 5 bbls ARCO preflush at 8.9 ppg. Press test lines to 4500 psi. Pmp 25 bbls spacer. Pump 50 bbls class G cmt at 15.8 ppg. Clean cmt line, displace with 34 bbls perf pill and 98 bbls mud. Bumped plug, reciprocated with full returns. Cement pumped Circulated at 10787.0 ft Pressure to 4200 psi to set liner hanger/packer. Rotate to release from hanger. Pressure to 1000 psi and unsting. Pump at 7 bbl/min, set down to check packer set. Circ while reciprocating pipe, recieved 10 bbls cmt returns. Obtained clean returns- 150.00 % hole volume Fluid system Fill pits with Seawater Offioad remaining mud, filled pits with seawater. Completed operations Circulated at 10787.0 ft Circulate well to clean seawater. Hole displaced with Seawater - 200.00 % displaced Pull Drillpipe, 4in O.D. Laid down 31.0 ft of 4in OD drill pipe L/D excess drill pipe at report time. Pull Drillpipe, 4in O.D. (cont...) Laid down 1674.0 ft of 4in OD drill pipe (cont...) L/D excess drill pipe at report time. 54 joints laid out Serviced Block line Line slipped and cut Pulled Drillpipe in stands to 0.0 ft POH and L/D liner running tool. At Surface: 0.0 ft Serviced Top drive Equipment work completed Facility Date/Time 04 Oct 99 Progress Report PB W Pad WeH W-26A Page 13 Rig Nabors 9ES Date 06 October 99 13:30-06:00 13:30-14:30 14:30 14:30-16:00 16:00 16:00-17:30 17:30 17:30-00:00 00:00 00:00-00:30 00:30 00:30-02:30 02:30 02:30-03:30 03:30 03:30-04:00 04:00 04:00-06:00 06:00-17:30 06:00-12:00 12:00 12:00-13:00 13:00 13:00-13:30 13:30 13:30-17:00 17:00 17:00-17:30 Duration 16-1/2 hr lhr 1-1/2 hr 1-1/2 hr 6-1/2 hr 1/2 hr 2hr lhr 1/2 hr 2hr 11-1/2 hr 6hr lhr 1/2 hr 3-1/2 hr 1/2 hr Activity 4in. Perforation assembly workstring run Rigged up Tubing handling equipment Held PJSM. R/U to run HOWCO 2.75" DPC perf guns. Equipment work completed Ran Tubing to 1160.0 ft (2-3/4in OD) PFLI guns and spacer to perf intervals 11,370'- 11,420', 11,470'- 11,490', 11,546'- 11,576', & 12,470'-12,530'. (4spf) Stopped: To change handling equipment Ran Tubing to 1837.0 ft (2-7/8in OD) PFL120 jts 2-7/8" fox tubing, safety jr, pkr, vent, ann press xo, jars, fas fill valve. Stopped: To change handling equipment Ran Drillpipe in stands to 12530.0 ft RIH w/4" drill pipe. Closed fas fill, checked. Finish RIH 103 stds dry pipe. Tagged bottom on depth, spaced out btm shot at 12,530'. At Setting depth: 12530.0 ft Tested High pressure lines RfU and tested surface lines to 3500 psi. Pressure test completed successfully - 3500.000 psi Perforated Set packer. Held PJSM. Pressure annulus to 2600 psi, no indication of guns firing. Pressured to 3500 psi and bled off twice, no go. Pressure to 3800 psi, while bleeding off got indication guns fired. Guns fired from 11370.0 ft to 12530.0 ft Reverse circulated at 10710.0 ft P/U and reverse circ 2 btms up at 5 BPM. No lossed to formation. Recovered some formation sand and gun debris. Obtained clean returns - 200.00 % hole volume Monitor wellbore pressures Released packer and monitored well. Stable. Pmp pill. Observed well static Laid down 2790.0 ft of 4in OD drill pipe POH LDDP at report time. 4in. Perforation assembly workstring run (cont...) Laid down 10694.0 ft of 4in OD drill pipe (cont...) POH LDDP at report time. 345 joints laid out Retrieved Perforating tools L/D FAS fill, jars, ann press assbly, packer, safety jt. Clear floor. Stopped: To change handling equipment Laid down 628.0 ft of Tubing L/D 20 jts 2-7/8" fox tubing. 20 joints laid out Retrieved Gun assembly L/D guns and spacer. All shots fired, OK. Completed operations Removed Tubing handling equipment Clear floor. Facility Date/Time 05 Oct 99 Progress Report PB W Pad Well W-26A Page 14 Rig Nabors 9ES Date 06 October 99 17:30 17:30-18:00 17:30-18:00 18:00 18:00-06:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-04:30 04:30 04:30-06:00 06:00-13:00 06:00-06:30 06:30 06:30-09:30 09:30 09:30-11:00 11:00 11:00-13:00 13:00 13:00-15:00 13:00-15:00 15:00 15:00-16:00 15:00-16:00 16:00 16:00-20:30 16:00-20:30 20:30 20:30-22:00 20:30-22:00 22:00 Duration 9-1/2 hr 1-1/2 hr 7hr 1/2 hr 3hr 1-1/2 hr 2hr 2hr 2hr lhr lhr 4-1/2 hr 4-1/2 hr 1-1/2 hr 1-1/2 hr Activity Equipment work completed Wellhead work Removed Wear bushing Equipment work completed Run Gas lift completion, 4-1/2in O.D. Rigged up Tubing handling equipment Equipment work completed Held safety meeting Held PJSM prior to run completion. Completed operations Ran Tubing to 10730.0 ft (4-1/2in OD) Ran 253 jts 4-1/2", L-80, BTC mod tubing, packer, 6 GLM's, and X nipple as per tubing detail. Stopped · To pick up/lay out tubulars Space out tubulars Run Gas lift completion, 4-1/2in O.D. (cont...) Space out tubulars (cont...) Completed operations Reverse circulated at 10730.0 ft Reverse circulate annulus to corrosion inhibitor, 3 bpm max as per Baker. Hole displaced with Inhibited brine - 100.00 % displaced Inhibited seawater. Rigged up Tubing hanger Dropped ball/rod assembly. Landed tubing hanger and RILDS. Work completed - Tubing hanger in position Set packer at 10685.0 ft with 3000.0 psi Set packer and tested tubing to 3000 psi for 30min. OK. Hold 2000 psi and tested packer and annulus to 3000 psi, OK. Bled tubing pressure and sheared RP. Packer set at 10685.0 ft Fluid system Freeze protect well - 155.000 bbl of Diesel Pumped 155 bbls diesel with HBR. U-tubed. Completed operations Wellhead work Installed Hanger plug L/D landing jt and installed TWC. Tested to 500 psi. Eqpt. work completed, running tool retrieved Planned maintenance Serviced All rams Pulled mouse hole and removed flow nipple. Opened doors on BOP's and removed rams. Clean cavities, prepare for cold stack. Close and tighten ram doors. Equipment work completed Removed swabs and liners, serviced mud pumps for cold stack. Nipple down BOP stack Rigged down BOP stack N/D and secured BOP stack. Equipment work completed Facility PB W Pad Progress Report Well W-26A Page Rig Nabors 9ES Date 15 06 October 99 Date/Time 06 Oct 99 22:00-02:30 22:00-00:00 00:00 00:00-01:00 01:00 01:00-01:30 01:30 01:30-02:30 02:30 02:30 02:30-03:00 03:00 Duration 4-1/2 hr 2hr lhr 1/2 hr lhr 1/2 hr Activity Wellhead work Installed Xmas tree N/U adapter and tree. Equipment work completed Tested Xmas tree Tested tree and adapter flange to 5000 psi. Pressure test completed successfully - 5000.000 psi Rigged down Hanger plug Pulled TWC w/lubricator. Equipment work completed Rigged up Hanger plug Installed BPV and tested to 500 psi. Removed secondary annular valve and secured well. Equipment work completed Fluid system Cleared Trip tank Finished cleaning pits, brine storage tanks. Equipment work completed Rig released for cold stack at end of W pad. Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_ WOA W Pad, Slot W-26 W-26A Job No. AKMM90153, Surveyed: I October, 1999 ORIGINAL SURVEY REPORT 18 October, 1999 Your Ref: AP1-50029216401 Surface Coordinates: 5959308.01 N, 611789.07 E (70° 17' 52.0241"N, 149° 05' 40.9357" W) Kelly Bushing: 81.85ft above Mean Sea Level Survey Ref: svy9362 Sperry-Sun Drilling Services Survey Report for W-26A Your Ref: API-50029216401 Job No. AKMM90153, Surveyed: I October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7955.25 42.580 330.875 6109.59 6191.44 7984.00 42.370 331.370 6130.80 6212.65 8010.10 42.970 329.240 6149.99 6231.84 8072.95 41.990 324.050 6196.36 6278.21 8101.78 41,950 321.640 6217.79 6299.64 8133.87 41.600 318.940 6241.73 6323.58 8164.40 40.960 316.370 6264.67 6346.52 8196.99 41.340 313.620 6289.21 6371.06 8228.48 41.380 310.970 6312.85 6394.70 8260.56 41.090 308.880 6336.98 6418.83 8290.58 40.750 306.740 6359.66 6441.51 8323.11 40.240 305.980 6384.40 6466.25 8385.34 39.480 307.900 6432.17 6514.02 8479.44 37.930 308.780 6505.60 6587.45 8572.58 36.940 308.910 6579.56 6661.41 8665.31 36.010 308.230 6654.12 6735.97 8757.03 37.160 308.220 6727.77 6809.62 8851.14 38.290 308.070 6802.21 6884.06 8944.59 37.480 307.470 6875.96 6957.81 9037.95 37.050 309.330 6950.26 7032.11 9131.19 38.450 308.410 7023.99 7105.84 9223.57 37.610 309.630 7096.75 7178.60 9316.81 38.070 310.850 7170.39 7252.24 9408.83 37.300 312.150 7243.21 7325.06 9502.26 37.490 309.950 7317.44 7399.29 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3186.08 N 3059.23W 5962448.24 N 608682.79 E 3203.08 N 3068.61W 5962465.09 N 608673.16 E 3218.45 N 3077.37W 5962480.33 N 608664.17 E 3253.88 N 3100.68W 5962515.41N 608640.34 E 3269.25 N 3112.32W 5962530.60 N 608628.47 E 3285.69 N 3125.97W 5962546.84 N 608614.57 E 3300.58 N 3139.54W 5962561.52 N 608600.79 E 3315.74 N 3154.70W 5962576.45 N 608585.40 E 3329.74 N 3170.09W 5962590.22 N 608569.80 E 3343.31N 3186.30W 5962603.55 N 608553.39 E 3355.36 N 3201.83W 5962615.37 N 608537.68 E 3367.89 N 3218.84W 5962627.64 N 608520.48 E 3391.85 N 3250.72W 5962651.13 N 608488.25 E 3428.34 N 3296.88W 5962686.93 N 608441.56 E 3463.85 N 3340.97W 5962721.78 N 608396.94 E 3498.22 N 3384.07W 5962755.51N 608353.34 E 3532.05 N 3427.01W 5962788.69 N 608309.90 E 3567.61 N 3472.30W 5962823.58 N 608264.09 E 3602.76 N 3517.66W 5962858.05 N 608218.21 E 3637.87 N 3561.96W 5962892.49 N 608173.39 E 3673.68 N 3606.40W 5962927.64 N 608128.42 E, 3709.51 N 3650.62W 5962962.80 N 608083.67 E 3746.46 N 3694.28W 5962999.10 N 608039.47 E 3783.73 N 3736.41W 5963035.74 N 607996.79 E 3820.98 N 3779.20W 5963072.35 N 607953.45 E Alaska State Plane Zone 4 PBU_WOA W Pad Dogleg Rate (°/100fi) Vertical Section (ft) Comment 1.374 5.990 5.789 5.592 5.710 5.936 5.673 5.562 4.388 4.804 2.182 2.324 1.748 1.066 1.094 1.254 1.205 0.952 1.291 1.618 1.220 0.942 1.202 1.444 4385.04 4404.26 4421.80 4464.13 4483.41 4504.76 4524.81 4546.04 4566.48 4587.07 4606.03 4626.27 4664.58 4721.48 4776.36 4829.73 4882.58 4938.22 4993.57 5048.25 5103.59 5158.80 5214.57 5269.68 5325.17 Tie-On Window Point Continued... 18 October, 1999- 14:09 -2- DrlllQuest Sperry-Sun Drilling Services Survey Report for W-26A Your Ref: AP1-$0029216401 Job No. AKMM90153, Surveyed: I October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9594.79 37.040 310.250 7391.08 7472.93 9686.78 36.380 308.950 7464.83 7546.68 9781.54 36.040 309.600 7541.29 7623.14 9874.22 35.820 309.870 7616.33 7698.18 9968.67 35.480 309.920 7693.08 7774.93 10062.30 34.450 310.820 7769.81 7851.66 10155.39 31.780 309.670 7847.77 7929.62 10249.79 29.310 308.060 7929.07 8010.92 10343.00 27.110 305.760 8011.21 8093.06 10435.40 25.880 303.060 8093.90 8175.75 10529.16 25.020 303.880 8178.56 8260.41 10620.09 24.000 304.570 8261.30 8343.15 10714.90 22.940 305.090 8348.26 8430.11 10807.79 21.930 306.600 8434.12 8515.97 10901.19 20.880 308.580 8521.08 8602.93 10990.42 22.220 315.360 8604.08 8685.93 11023.33 25.550 317.460 8634.17 8716.02 11051.47 28.120 324.990 8659.29 8741.14 11084.44 30.420 332.090 8688.05 8769.90 11115.25 32.100 337.820 8714.40 8796.25 11144.73 33.200 339.580 8739.22 8821.07 11176.69 34.880 341.280 8765.70 8847.55 11193.22 35.610 341.220 8779.20 8861.05 11203.79 36.120 340.400 8787.77 8869.62 11229.91 39.210 340.920 8808.44 8890.29 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3857.07 N 3822.06W 5963107.80 N 607910.06 E 3892.12.N 3864.42W 5963142.22 N 607867.18 E 3927.56 N 3907.76W 5963177.01N 607823.32 E 3962.32 N 3949.58W 5963211.15 N 607780.99 E 3997.63 N 3991.81W 5963245.82 N 607738.24 E 4032.38 N 4032.69W 5963279.96 N 607696.84 E 4065.25 N 4071.50W 5963312.24 N 607657.55 E 4095.36 N 4108.83W 5963341.80 N 607619.78 E 4121.84 N 4144.03W 5963367.76 N 607584.18 E 4145.15 N 4178.02W 5963390.55 N 607549.85 E 4167.37 N 4211.63W 5963412.27 N 607515.92 E 4188.58 N 4242.82W 5963433.01N 607484.41E 4210.14 N 4273.82W 5963454.11 N 607453.10 E 4230.89 N 4302.56W 5963474.43 N 607424.05 E 4251.67 N 4329.57W 5963494.81N 607396.73 E 4273.60 N 4353.86W 5963516.37 N 607372.12 E 4283.26 N 4363.04W 5963525.89 N 607362.80 E 4293.16 N 4370.95W 5963535.68 N 607354.74 E 4306.91 N 4379.32W 5963549.30 N 607346.17 E 4321.39 N 4386.06W 5963563.68 N 607339.21 E 4336.20 N 4391.83W 5963578.41 N 607333.22 E 4353.06 N 4397.82W 5963595.17 N 607326.99 E 4362.09 N 4400.89W 5963604.16 N 607323.78 E 4367.94 N 4402.92W 5963609.98 N 607321.66 E 4383.00 N 4408.20W 5963624.95 N 607316.16 E Alaska State Plane Zone 4 PBU_WOA W Pad Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.524 5379.77 1.108 5433.24 0.541 5487.61 0.293 5540,53 0.361 5594.13 1.230 5646.47 2.946 5696.06 2.756 5742.57 2.632 5784.89 1.863 5823.94 0.991 5861.89 1.165 5897.59 1.139 5933.46 1.252 5967.31 1.365 6000.16 3.167 6032.28 10.442 6045.51 15.128 6058.18 12.620 6074.20 11.079 6089.82 4.929 6105.14 6.041 6122,21 4.421 6131.27 6.629 6137.17 11.892 6152.38 Continued... 18 October, 1999 - 14:09 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for W-26A Your Ref: API-50029216401 Job No. AKMM90153, Surveyed: I October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11241.97 41.180 341.690 8817.65 8899.50 11269.22 46.420 343.140 8837.31 8919.16 11304.56 53.480 344.100 8860.04 8941.89 11333.59 60.880 343.570 8875.76 8957.61 11366.11 68.290 343.610 8889.71 8971.56 11399.21 75.330 344.450 8900.04 8981.89 11427.02 80.620 341.100 8905.83 8987.68 11458.04 88.430 343.310 8908.79 8990.64 11489.87 90.840 348.850 8908.99 8990.84 11522.65 93.040 355.550 8907.88 8989.73 11550.50 101.090 355.740 8904.46 8986.31 11581.90 104.930 357.660 8897.39 8979.24 11613.91 105.200 358.720 8889.07 8970.92 11642.88 101.150 0.660 8882.47 8964.32 11678.05 94.630 6.650 8877.64 8959.49 11708.21 90.000 7.650 8876.42 8958.27 11737.46 91.170 6.910 8876.12 8957.97 11768.55 93.380 7.860 8874.89 8956.74 11797.72 95.230 10.850 8872.70 8954.55 11828.56 97.050 12.860 8869.40 8951.25 11864.86 97.590 13.260 8864.77 8946.62 11923.05 97.270 13.780 8857.25 8939.10 12018.13 94.270 12.110 8847.69 8929.54 12051.18 97.180 12.640 8844.39 8926.24 12118.03 98.590 11.590 8835.22 8917.07 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4390.37 N 4410.70W 5963632.29 N 607313.55 E 4408.35 N 4416.38W 5963650.18 N 607307.60 E 4434.29 N 4424.00W 5963676,00 N 607299.60 E 4457.70 N 4430.79W 5963699.31 N 607292.46 E 4485.86 N 4439.08W 5963727.34 N 607283.75 E 4516.07 N 4447.72W 5963757.43 N 607274.66 E 4542.04 N 4455.78W 5963783.27 N 607266.22 E 4571.42 N 4465.20W 5963812.50 N 607256.36 E 4602.30 N 4472.86W 5963843.26 N 607248.25 E 4634.73 N 4477.30W 5963875.63 N 607243.32 E 4662.27 N 4479.40W 5963903.13 N 607240.81 E 4692.81 N 4481.16W 5963933.64 N 607238.60 E 4723.70 N 4482.14W 5963964.52 N 607237.16 E 4751.90 N 4482.29W 5963992.71 N 607236.59 E 4786.63 N 4480.06W 5964027.47 N 607238.31E 4816.52 N 4476.31W 5964057.41N 607241.61E 4845.53 N 4472.60W 5964086.48 N 607244.89 E 4876.34 N 4468.61W 5964117.34 N 607248.42 E 4905.04 N 4463.88W 5964146.10 N 607252.72 E 4935.04 N 4457.58W 5964176.20 N 607258.57 E 4970.12 N 4449.45W 5964211.39 N 607266.18 E 5026.22 N 4435.96W 5964267.69 N 607278.84 E 5118.40 N 4414.77W 5964360.17 N 607298.65 E 5150.52 N 4407.73W 5964392.39 N 607305.22 E 5215.26 N 4393.83W 5964457.33 N 607318.15 E Alaska State Plane Zone 4 PBU_WOA W Pad Dogleg Rate (°/100ft) Vertical Section (ft) Comment 16.846 19.578 20.085 25.537 22.786 21.405 22.372 26.156 18.979 21.5Ol 28.913 13.6o3 3.307 15.425 25.059 15.7o5 4.733 7.736 12.o29 8.764 1.846 1.o43 3.607 8.948 2.621 6159.77 6177.55 6202.86 6225.66 6253.15 6282.49 6308.09 6337.23 6366.51 6395.11 6418.38 6443.85 6469.13 6491.76 6518.18 6539.81 656O.78 6583.00 66o3.1o 6623.29 6646.44 6683.17 6744.12 6765.56 6808.95 Continued... 18 October, 1999 - 14:09 - 4 - DrlllQuest Sperry-Sun Drilling Services Survey Report for W-26A Your Ref: API-50029216401 Job No. AKMM90153, Surveyed: I October, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (fi) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 12143.10 99.380 9.820 8831.31 8913.16 5239.59 N 12174.92 97.440 10.700 8826.65 8908.50 5270.56 N 12204.07 96.830 11.230 8823.03 8904.88 5298.96 N 12270.42 98.060 9.290 8814.43 8896.28 5363.69 N 12298.97 96.390 9.820 8810.84 8892.69 5391.62 N 4389,23W 5964481.73 N 607322.39 E 4383.62W 5964512.78 N 607327.53 E 4378,12W 5964541.25 N 607332.61E 4366.40W 5964606.16 N 607343.37 E 4361o70W 5964634.15 N 607347.65 E 4351,14W 5964690.71 N 607357.38 E 4343.64W 5964724.29 N 607364.37 E 4336.43W 5964757.06 N 607371.10 E 4330.48W 5964784.64 N 607376.64 E 4323.20W 5964813.48 N 607383.49 E 4314.56W 5964845.00 N 607391.66 E 4301.60W 5964891.09 N 607403.94 E 4286.42W 5964944.79 N 607418.32 E 12356.48 89.910 11.390 8807.69 8889.54 5448.03 N 12390.79 88.000 13.850 8808.31 8890.16 5481.50 N 12424.25 89.600 11.060 8809.01 8890.86 5514.16 N 12452.43 95.590 13.350 8807.74 8889.59 5541.66 N 12482.36 100.060 15.090 8803.66 8885.51 5570.40 N 12515.40 99.380 15.700 8798.08 8879.93 5601.79 N 12563.71 99.010 15,840 8790.36 8872.21 5647.69 N 12620.00 99.010 15.840 8781.55 8863,40 5701.17 N All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Alaska State Plane Zone 4 PBU_WOA W Pad Dogleg Rate (°/100fi) 7.652 6.682 2.763 3.441 6.132 11.592 9.076 9.61o 22.752 16.0o6 2.747 0.818 0.000 Vertical Section (ft) Comment 6825.64 6847.02 6866.41 6911.11 6930.61 6969.35 6991.60 7013.37 7031.78 7050.37 7070.27 7099.16 7132.79 Projection The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 323.062° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12620.00ft., The Bottom Hole Displacement is 7132.79ft., in the Direction of 323.062° (True). Continued... 18 Octobe6 1999-14:09 -5- Dr#lQuest Sperry-Sun Drilling Services Survey Report for W-26A Your Ref: API-50029216401 Job No. AKMM90153, Surveyed: I October, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA W Pad Comments Measured Depth (~) 7955.25 7984.00 12620.00 Station Coordinates TVD Northings Eastings (~) (~) (~) 6191.44 3186.08 N 3059.23W 6212.65 3203.08 N 3068.61W 8863.40 5701.17 N 4286.42W Comment Tie-On Window Point Projection 18 October, 1999 - 14:09 - 6- DrillQuest GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATEN: Sherrie NO. 12817 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 9/30/99 Well Job # Log Description Date Blueline Sepia CD A-16A LL% (.-- INJECTION PROF. & RST WFL 990909 1 1 B-22 LEAK DETECTION LOG 990915 1 1 B-22 PSP-LEAK DETECTION LOG 990925 1 1 W-01 LEAK DETECTION LOG 990924 1 1 W-36 LEAK DETECTION LOG 990924 1 1 X-13A LEAK DETECTION LOG 990923 1 1 8-34 ~ ~,O 99330 CNTD 990831 1 1 1 C-09 ~ '~'~ I 99326 CNTD 990808 1 1 1 C-41 ~ ~'2."2_ 99336 CNTD 990829 1 1 1 N-09 ~.~_~_~z_~..-~'~.~.~ 99332 CNTD 990828 1 1 1 Y-36 <.~- .~- ~"~'Z ~ 99327 CNTD 990811 1 1 1 W-26A 99365 USIT 990918 1 Color PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center M83-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 AT[N: Sherrie Received 15'~'~--'/ ~~,~/~--~ TONY KNOWLES, GOVERNOR ALASKA OILAND GAS CONSERVATION CO--SION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 23. 1999 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bav Unit W-26A BP Exploration (Alaska) Inc. Permit No: 99-081 Sur Loc: 945'SNL, 1446~3/EL. Sec. 21. T1 IN. R12E. UM Btmhole Loc. 4672~SL. 579~WEL. Sec. 17. T11N. R12E. UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .... STATE OF ALASKA ALASKA .LAND GAS CONSERVATION COl, ~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 83' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designat~n Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028262 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 945' SNL, 1446' WEL, SEC. 21, T11N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 3397' NSL, 616' WEL, SEC. 17, T11N, R12E, UM W-26A At total depth 9. Approximate spud date Amount $200,000.00 4672' NSL, 579' WEL, SEC. 17, T11N, R12E, UM 8/26/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028244, 579'I No Close Approach 2560 12496' MD / 8820' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8000' MD Maximum Hole Angle 99-8° Maximum surface 2920 psig, At total depth (TVD) 8800' / 3800 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 3147' 7850' 6085' 10997' 8701' 183 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1650' 10847' 8560' 12496' 8903' 240 sx Class 'G' i9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary :" '~"' ,=~' ~- j "!.,, ? :,~ :~' Total depth: measured 12030 feet Plugs (measured) ...... true vertical 9186 feet Effective depth: measured 11920 feet Junk (measured) Fill at 11920' (09/89) true vertical 9109 feet Casing Length Size Cemented :'.~, Structural Conductor 110' 20" 110' 110' Surface 2985' 13-3/8" 4399 cuft Coldset II 3021' 2701' Intermediate 11336' 9-5/8" 2398 cu ft Class 'G' 11373' 8712' Production Liner 909' 5-1/2" 425 cuft Class 'G' 11121' - 12030' 8530' - 9186' Perforation depth: measured 11664'- 11760' (three intervals)0RIGINAL true vertical subsea 8836' - 8905' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Smith, 564-5026 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,._ "~'~. ~ Dan Stone Title Senior Drilling Engineer Date Commission Use Only Permit Number APl Number ,... I Approval,Date. I See cover letter ~I.¢~ --- ~ ~ ~ 50-029-21964-01I ~'~ '~ ~/¢~I for other requirements Conditions of Approval: Samples Required []Yes ~_No Mud Log Required I-lYes r~ No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required []Yes [] No Required Working Pressure for BOPE ['-]2K; 1--13K; ~4K; ,~SK; J--I10K; I-']15K Other: ~'~'¢~'~'- ~O~ "~ :~'""¢~ ~ by order of Approved By ,--,=.-.-.;-- ................... Commissioner the commission Date Form 10-401 Rev. 12-01-85 ORiGiNAL SiGNED-BY Robert N. Ohdstenson Submit In Triplicate I Well Name: [W-26A Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: Target #1 Start: Total Depth 945' FNL, 1446' FEL, Sec. 21, T1 IN, R12E X = 611789.07 Y = 5959308.1 3397'FSL, 616'Fel, Sec. 17, T1 iN, R12E X = 607264 Y= 5963585 Z = 8750' TVDss 4672'FSL, 579'FEL, Sec. 17, T1 IN, R12E X = 607280 Y=5964860 Z= 8820' TVDss I AFENumber: 1 4P1322 [Rig: I Nabors 9ES Estimated Start Date: 8/26/99 IMD 112496' Operating days to complete: I TVDss: 1 8820' 24 I KBE: 183' I Well Design (conv., slim hole, etc.): Horizontal USH Sidetrack Objective: Rig will sidetrack out of existing 9-5/8 in Seabee formation, directionally drill 8-1/2" hole to top Sag River, mn and cement 7" drlg liner, drill out in 6-1/8"hole and thru (1) ZA target, TD at 12496' MD. Run, cmt and test 4 1/2" L80 solid liner, complete with 4 ½", L80 tbg, (3) GLM's and WOA tail assy. Formation Markers Formation Tops MD TVD(ss) Seabee Shale KOP 8000 6142 Kick off in 8-1/2" hole size Miluveach Shale 8855 6842 Kingak Shale 9645 7497 Utilize Shale drilling practices Sag River 10994 8615 Penetrate 10'MD into Sag and mn/cmt 7" drilling liner Shublik 11036 8650 Top Sad 11173 8750 TD 12496 8820 Run and cmt 4-1/2" prod liner Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MDfrVD O.D. 8-1/2" 7" 26# L-80 BTCM 3147' 7850'/6085' 10997'/8701' 6-1/8" 4 1/2" 12.6# L-80 IBT 1650' 10847'/8560' 12496'/8903' liner Mod Tubing 4-1/2" 12.6# L-80 IBT 10817' 30'/30' 10847'/8560' Mod Logging Program: I Open Hole Logs: 9ES Drilling section: MWD/GR from KOP (8800') to 8-1/2" hole TD at 10997'. MWD/GR/PWD/LWD in 6-1/8" hole from 7" liner to TD at 12496'MD MADD pass as per Geologist request. Sample catchers and rig site geologist on site before TD of 8-1/2" hole. Open Hole: DPC Log only if LWD logs of poor quality. Cased Hole Logs None Planned Mud Program: Special design considerations Drill from KOP to TD of 8-1/2" with Baroid LSND mud. Drill 6-1/8" hole with QuikdrilN Lite Polymer system. Density LSRV PV YP Ca++ pH (ppg) (cps) 9.2 LSND 10 15 10.2(before LSND 12 15 Kingak) 8.3 < 12000 5-8 20-25 < 100 9.0-9.5 to to to 8.5+ < 12000 5-8 20-25 < 100 9.0-9.5 Directional: KOP: 1) 8000' MD, drill out of 9-5/8 "casing via whipstock window, drop and turn to 34° angle and 307° azimuth, hold to 8-1/2" TD at Sag River (10997'MD) 2) In 6-1/8" interval build and turn angle at 16°/100, to invert wellbore through targets, TD of interval is at 12496'MD, 8820'TVDss Maximum Hole 99.8°after reaching low point and inverting Angle: Surface Shut-in No wells will need to be shut-in and de-pressurized before rig moves on and off of the well. Close Approach There are no close approach wells to this wellbore Well: identified. Point to point separation Cement Data: Casing/Liner Lead: Tail: Sxs/Wt~ield Comments Sxs/Wt/Yield P&A of original well 48/15.8/1.15 Class "G", TOC pre-rig coil work in 383'cmt 10,300' 364' above top 5-1/2" production liner perfs. 7", 26#, L-80 Liner 111/11.0/3.82 72/15.8/1.16 Lead w/50% excess, TOC at 8200', tail with 30% excess and 500' fillup. 4-1/2", 12.6#, L-80 240/15.8/1.16 Class "G",50% excess liner Shoe at 12496' OH + 200' above liner MD Liner top top w/DP in hole @ 10,847'MD Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter and BOPE system schematics on file with AOGCC. Bottom hole pressure is 3800 psi at 8,800' TVDss, Is 8.0ppg EMW Maximum shut-in casing pressure is 2,920 psi (assumes 0.1 psi/ft gas gradient to surface). Planned BOPE test pressure is 3,500 psi on the W-26A sidetrack NO ANNULAR INJECTION IN THIS WELL. ~.~'~i (?' W-26A Class II drilling wastes will be disposed at DS4 grind and inject facility. If Class I waStes. are generated, they will be taken to Pad 3 disposal site. Name Jim Smith Tony Bunch Greg Bernaski Drilling Eng. Drilling Supt. Geophys Contacts Office Home Pager 564 5026 345 8660 564 5219 348 6683 564 5464 275-4015 275-3703 Drilling Discussion Well Obiective The proposed horizontal sidetrack will target a 1200' horizontal section in Zone 4 below the gas cap. DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There is no well that will need to be shut-in during the rig move on and off of the well. The nearest wells are W-25 and W-27 which are at 35' on either side. SSD management has granted dispensation for the 9ES moves with MOC guidelines and practices in place for close well moves. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move per ASH procedures. DRILLING CLOSE APPROACH WELL SHUT-INS No shut-ins identified on directional well plan Wp #5A due to close approach requirements. PORE PRESSURE: The pore pressure in Zone 4 is expected to be near 8.0 ppg EMW. 8.4 - 8.6 ppg mud will be used drilling Zone 4. The overlying Sag River and Shublik formations will be at similar pressure, the 8.4-8.6 ppg mud will provide sufficient overbalance to the reservoir pressure. HOLE PROBLEMS The planned wellbore may cross a fault in the 8-1/2" interval in the Kingak formation. This fault is considered fairly low risk to drilling operations. The well's design cuts no faults in the 6-1/8" hole interval, but be prepared for the possibility of lost circulation by stocking LCM materials at the rigsite since there is potential for a subseismic faults on any PBU well. No major hole problems are expected. H~_S: W pad is not an H2S Pad The highest reported level of H2S on W pad is 1 lppm or lower based on data through 12/98. There have been incidents of H2S on other pads which involved circulation of annular fluids from the wellbore. H2S precautions will be in effect at all times. These include (but are not limited to): · Regular H2S drills (minimum of two per week) · Proper training of all permanent onsite personnel, unescorted visitors and temporary onsite personnel; · H2S monitors with both audible and visual alarms; · Access to 5-minute emergency escape air packs; · Personal H2S monitors; · Functional wind indicator; · Posted evacuation routes (minimum of two); · Muster points in designated safe areas;H_aS; -- · Functional communications between rig camp and rig floor. Casing Shoe Kick Tolerance The smallest kick tolerance for the 8-1/2" hole interval below 9-5/8" casing (at the KOP of 8000'MD/6225'TVD) is calculated as 47 bbl assuming a swabbed gas influx from the Sag River at a depth of 10997'MD/8701'TVD with 10.2 ppg mud in the hole and 9.5 ppg pore pressure in the Sag River. The smallest kick tolerance for the 6-1/8" interval drilled below 7" casing at 10997'MD/8701'TVD is calculated as infinite influx assuming a swabbed gas influx from Z4 along the planned directional path. Based on 8.4 ppg MW (8.5 ppg reservoir pore pressure), and min. frac at 7" shoe of 11.5 ppg. Well Overview and Program: The W-26 sidetrack (W-26A) is intended to access additional reserves utilizing a horizontal well path in the Ivishak Zone 4. Nabors 9ES is expected to move to W-26A on/about August 20, 1999 after completing the S- 24A sidetrack. The drilling objective of W-26A is to pull the existing 3 1/2" tubing, place a bridge plug at the anticipated kick off depth of 8000'MD in the 9-5/8" casing, set a whipstock and mill through 9-5/8" casing, then directionally drill to the top of the Sag River where a 7" drilling liner will be set. The well will be extended in 6- 1/8" hole size to access the Zone 4 Ivishak targets. At TD a 4-1/2" production liner will be run and cemented and the well completed with production tubing. The objective of the pre-rig work is to ascertain the condition of the 3 1/2" tubing presently in the hole; P & A open perforations with 15.8 ppg cement to 11300' with cement, cut the 3 1/2" tubing; test the 9 5/8" casing and tubing hanger pack offs. Rig Sidetrack Procedure o 9. 10. 11. 1. MIRU. ND tree, NU and test BOPE. Circulate well clean. 2. Pull the existing 3-1/2" tubing completion, tubing will be junked. Tubing cut is at _+ 9,000' MD. Replace the leaking 9 5/8" packoff if necessary. 3. Make GR/JB run to at least 8,500'MD. Run 9-5/8" bridge plug on wireline w/GR/CCL and set at +/-8,030'MD. 4. Set 9-5/8"whipstock on bridge plug and mill window. KOP +/-8,000'MD in the Seabee shale. 5. Displace to LSND mud, kick off and directionally drill the 8-1/2" hole to the top of the Sag River at +/-10,998'MD, 8701 'TVD. d. Run and cement 7" drilling liner with 150' of overlap above the whipstock. ?. Directionally drill a 6-1/8" hole along the directional path after displacing to QuickdrilN Lite. Planned TD is +/-12,500'MD, 8903'TVD in the top of Zone 4 (inverted wellbore). Run MWD/LWD logs while drilling the target interval of the well. Run and cement 4 1/2", L-80 solid production liner with 150' lap inside 7" drilling liner. Test liner and liner lap to 3000 psi. Run 4-1/2" 12.6#, L80 Tubing completion, stab WLEG into 4-1/2" TOL. Test tubing to 3,500 psi and annulus to 3,500 psi. 12. Freeze protect well to 2200' 13. ND BOPE, NU and test tree. RDMO. TREE:' 3" FMC W26 KB. ELEV:91.11' WELLHEAD: FMC BF, ELEV = 54.61' .ACTUATOR: BAKER 31/2" SSSV LANDING O NIPPLE12091' ~ OTiS X 2.750" ~D~ 13 3/8", 68 #/ft,~1 3021' I--~ i~ GAS LIFT MANDRELS I L-80, BTRS , , 7 3386' ] 2852' KOP: 900' 6 6725' : 5188' M~ ANGLE: 51~ ~ 4500' 5 8579' 6565' [ 4 9648' 7347' 3 10244' 7803' 2 10,839' 8243' 3 1/~",9.2~/~,L-80. TDS-TUBING ~ I 10,994' 8350' I TBG ID=2.992".CAP=0.0087 BMUg. I I ~ 1/2 .... X" NIPPLE I 11024' ( OTIS ) ( 2.750" ID) CORKSCREWED TBG. & TIW SEAL ASSY. I 11032' TAKE WT. CHECKS FROM 9 5/8" TIW PACKER I I 10,000' DOWN X X (HBBP) (4.00"ID) I 11048' I ( OIlS ) ( 2.750" ID) I 5 1/2" LINER 11121' ~' '~ 3 1/2" TBG TAIL 11125' (OTIS WLEG) (ELMD) 111124'1 L-80, BTRS MARKER JOINT (ELMD) ~ 11458' PERFORATION SUMMARY ... A s-.HOS CATEGORY II SIZE SPF INTERVALS OPEN/SQZ'D NO SSSV 3 3/8,, 4 11664,_11704, OPEN 8-25-89 3 3/8" 4 11716'-11726' OPEN 8-25-89 3 3/8" 4 11730'-11760' OPEN 8-25-89 2 1/8" 4 11785'-11815' OPEN12-25-91 2 1/8" 4 11825'-11855' OPEN12.25_91 ......................... DATE REV. BY COMMENTS PRUDHOE BAY UNIT 8-26-89 QUIZ INITIAL COMPLETION WELL: W-26 (41-17-11-12) 2-27-91 A. TEEL REVISED APl NO: 50-029-21964-00 SEC 21; TN 11N; PGE 12E 12-25-91 RLV ADD PERKS 3-1-92 G.M. NOTE: CORKSCREWED TBG BP Exploration (Alaska) GAS LIFT MANDRELS ! ~TI~ W/RA AT~H~ Rig AA~I~ T\IR~ · , 7 3386' 2852' 6 6725' 5188' 5 8579' 6565' 4 9648' 7347' 3 10244' 7803' 2 10,839' 8243' I 10,994' 8350' TREE: FMC WELLHEAD: FMC '¢-26A KB. ELEV = 83' BF. ELEV = 54.61' 4 1/2" LANDING NIPPLE I 2200' I L-80, BTRS IKOP: 900' I MAX ANGLE: 51° @ 4500' 4 1/2/",12.6#/FT, L-80. IBT MOd TUBING L~/~ LII- I M/~NIJHI:L,_5 N-° MD(BKB/ TVDss 7 6 5 4 3 2 1 9-5/8" Whipstock at 8000', bottom trip on bridge TOPOF 111121' 5 1/2" LINER 9 5/8", 47#/ft, J 11372' L-80, BTRS PBTD ~--~'~ q33' I 51/2" 17#/ft, I 3S~ DATE .BY COMMENTS 7" 26# L80 BTCM. TOL at 7850', shoe Jar 10997' in top Sag River 1/2" "X" NIPPLES 7" X 4-1/2" Baker SB3 packer at 11,800' .4 1/2" XN NIPPLE WLEG stabbed into 4-1/2" liner at 10850' / 4 1/2" 12.6# L80 IBTMod production liner, solid cemented. TOL at 10850, shoe at 12496' PRUDHOE BAY UNIT WELL: W-26A APl NO: SEC 21 ; TN 11N; RGE 12E BP Exploration (Alaska) Attn Jim Sm' --- Jim, · . -. Take a look at this, Notes: 1.) The first target (T3) and the middle target (T2) will float a bit, 2,) The casing point is 150' SSE of the polygon,as discussed on the phone. 3,) Faidy basic other than that. 4.) Who is the gee type person that might want to look at a digital file? DeWayne I DrillQuest' Prudhoe Bay Unit Alaska State Plane Zone 4 sca[e: linch = 600ft Eastings PBU WOA W Pad -4800 .4200 .3600 -- I WI~4 TI. Pofnl 5618.45 N, 4425.99 W f,C4L Proposal Data for W-26A Wp.5 ~:;A-~"--: ' wa 54OO 4800 O z 4200 MD, 9011.29[I TVD ?olnl Oft: 11646.25ll MD, 8999.77fl TVD Db: 11360.30ft MD, W-2~A Wp4 T:J - PO/hr Not hit, wllt fioa~ later 16.00¢'/100R: 8701.421t I'VD -3000 I - 5400 - 4800 - 4200 6600 7200 7800 St~ DIr ~ 8.000*/lOOfl: 80OO, OOft MD, 6224.82fl TVD 3600 End Dir: 8214.48[I MD, 6394.23ft 'rVD -4800 .......... Lmv~r Crt/. Unc. . 6860.26 TVD · Mi!uveach. 6925.26 T1/D End DIr: 8214.48ft MD. 6394.23~1TVD Tie-on, Start DIr O 8.000°/100~1: 8D00.0Ofl MD, 8224.82~1TVD I -4200 -3600 -3000 Scale: linch = 600ft Reference is True North Eastings 3600 g II .......... ..tK Unco,lformity / Top Kit~ga8 7580.26 84OO W.26A~;stng. Pofnt will be App~ 150' SSE of T3 point ~ x /Slarl Dir · '[6.0¢~100fl: 10997.46fl MD, B701.42fl 'rVD ~ _:~e' ..................... "x ................................... Top ~ag River- 8698.26 TVl) I ..................................................................... J ux°~'N~ .................... -~ .................................Top Sltublik. 8733.26 TV/) Il , ~,. "- Total DODlh: 12496 2,~fl MD 8903 26f TVD } ................................................................................~.,. .................. x: .....................,. ........ ?sat). ~83~:~TVO ' ~ I ,,.=,n w~,,~.,oi., ox.._ 'x ,..~.~_~." - - 0 ~ $ W 26A Wp4 TI Poi t yi ~- 890J 26 TVD · Not hit, will flint laltr , ...................................................................................... ~ ........... ',t ..... ~: ...................... HOT. 9053.26 TVl) ~ I Start Dff O 12.001°/lO0ft: 11648.25fl MD, 8999.77/I TVD / ' End ~ 11861.331t MD 9011.2gR TVD (f) [ Noi hit, wlll,ltottt lnttr 4800 5400 6000 6600 7200 Scale: 1 inch = 600ft Section Azimuth: 321.770° (True North) Vertical Section Prudhoe Bay Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Proposal Report for W-26A Wps - W-26A Wp5 Revised: 11 August, 1999 Vertical Local Coordinates Depth Northlngs Eastings (ft) (ft) (fi) 8000.00 42.367 331.477 6141.56 6224.82 8214.48 34.000 307.000 6310.97 6394.23 8500.00 34.000 307.000 6547.68 6630.94 8776.62 34.000 307.000 6777.00 6860.26 8855.02 34.000 307.000 6842.00 6925.26 9000.00 34.000 307.000 6962.19 7045.45 9500.00 34.000 307.000 7376.71 7459.97 9585.97 34.000 307.000 7447.99 7531.25 9645,09 34.000 307.000 7497.00 7580.26 10000.00 34.000 307.000 7791.23 7874.49 10500.00 34.000 307.000 8205.75 8289.01 10957.46 34.000 307.000 8585.00 8668.26 10993.64 34.000 307.000 8615.00 8698.26 10997.46 34.000 307.000 8618.16 8701.42 11000.00 34.142 307.681 8620.27 8703.53 11036.43 36.557 316.861 8650.00 8733.26 11173.26 50.166 342.210 8750.00 8833.26 11360.30 74.000 3.000 8837.69 8920.95 11500.00 74.000 3.000 8876.19 8959.45 11646.25 74.000 3.000 8916.51 8999.77 11779.57 90.000 3.000 8935.00 9018.26 11861.33 99.796 2.454 8928.03 9011.29 12000.00 99.796 2.454 8904.43 8987.69 12496.25 99.796 2.454 8820.00 8903.26 3211.65 N 3073.30 W 3311.99 N 3156.32 W 3408.07 N 3283.83 W 3501.16 N 3407.37 W 3527.55 N 3442.38 W 3576.34 N 3507.13 W 3744.60 N 3730.42 W 3773.54 N 3768.82 W 3793.43 N 3795.22 W 3912.87 N 3953.72 W 4081.13 N 4177.02 W 4235.08 N 4381.3I W 4247.26 N 4397.47 W 4248.54 N 4399.18 W 4249.41 N 4400.31 W 4263.59 N 4415.83 W 4344.33 N 4460.29 W 4506.19 N 4477.93 W 4640.29 N 4470.90 W 4780.68 N 4463.54 W 4912.09 N 4456.65 W 4993.37 N 4452.78 W 5t29.88 N 4446.93 W 5618.45 N 4425.99 W Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/'~OOft) (ft) 5962473.59 N 608668.34 E 4424.67 5962572.68 N 608583.83 E 8.000 4554.87 5962666.86 N 608454.91 E 0.000 4709.25 5962758,10 N 608330.00 E 0.000 4858.82 5962783.96 N 608294.60 E 0.000 4901.22 5962831.78 N 608229,13 E 0.000 4979.61 5962996.71 N 608003.36 E 0.000 5249,97 5963025.07 N 607964.54 E 0.000 5296.45 5963044.57 N 607937.84 E 0.000 5328.42 5963161.63 N 607777.58 E 0.000 5520.32 5963326.56 N 607551.81 E 0.000 5790.68 5963477.45 N 607345.25 E 0.000 6038.03 5963489.39 N 607328.91 E 0.000 6057.60 5963490.65 N 607327.18 E 0.000 6059.66 5963491.49 N 607326.04 E 16,000 6061.04 5963505.44 N 607310.31 E 16.000 6081.78 5963585.51 N 607264.65 E 16.000 6172.72 5963747.09 N 607244.61 E 16.000 6310.78 5963881.28 N 607249.64 E 0.000 6411.77 5964021.77 N 607254.91 E 0.000 6517.51 5964153.27 N 607259.84 E 12.001 6616.47 5964234.59 N 607262.51 E 12.000 6677,92 5964371.18 N 607266.33 E 0.000 6781.54 5964860.00 N 607280.00 E 0.000 7152.36 Alaska State Plane Zone 4 PBU_WOA W Pad Comment Tie-on, Start Dir @ 8.000°/I00ft' 8000.00ft MD, 6224.82ft TVD End D[r' 8214.48ft MD, 6394.23ft TVD Lower Cret. Unc. Miluveach Sail @ 34.000° Inclination on 307.000° Azimuth JK Unconformity /Top Kingak 7' Casing Top Sag River Start Dir @ 16.000°/100ft' 10997.46ft MD, 8701.42ft 'i'VD Top Shublik TSAD End Dir' 11360.30ft MD, 8920.95ft TVD Start Dir @ 12.001°/100ff · 11646.25ft MD, 8999.77ft TVD End Dir- 11861.33ft MD, 9011.29ft TVD Total Depth ' 12496.25fl MD, 8903.26ft 't'VD 4 1/2' Liner Cont/nued... 11 August, 1999 - 9:38 - 2 - DrillQuest Sperry-Sun Drilling Services Proposal Report for W-26A Wps - W-26A Wp5 Revised: 11 August, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA W Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 321.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12496.25ft., The Bottom Hole Displacement is 7152.36ft., in the Direction of 321.770° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8000.00 6224.82 3211.65 N 3073.30 W 8214.48 6394.23 3311.99 N 3156.32 W 9585.97 7531.25 3773.54 N 3768.82 W 10997.46 8701.42 4248.54 N 4399.18 W 11360.30 8920.95 4506.19 N 4477.93 W 11646.25 8999.76 4780.68 N 4463.54 W 11861.33 9011.29 4993.36 N 4452.78 W 12496.25 8903.26 5618.45 N 4425.99 W Comment Tie-on, Start Dir @ 8.000°/100ff; 8000.00ft MD, 6224.82ft TVD End Dir: 8214.48ff MD, 6394.23ft TVD Sail @ 34.000° Inclination on 307.000° Azimuth Start Dir @ 16.000°/100ft: 10997.46ff MD, 870I .42ff TVD End Dir: 11360.30ft MD, 8920.95ft TVD Start Dir @ 12.001°/100ft- 11646.25ft MD, 8999.77ft TVD End Dir' 11861.33ft MD, 9011.29ft TVD Total Depth - 12496.25ft MD, 8903.26ft TVD Conb'nued... 11 August, 1999 - 9:38 - 3 - DrillQuest Sperry-Sun Drilling Services Proposal Report for W-26A Wps - W-26A Wp5 Revised: 11 August, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA W Pad Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 8776.62 6860.26 6777.00 3501.16 N 3407.37 W 8855.02 6925.26 6842.00 3527.55 N 3442.38 W 9645.09 7580.26 7497.00 3793.43 N 3795.22 W 10993.64 8698.26 8615.00 4247.26 N 4397.47 W 11036.43 8733.26 8650.00 4263.59 N 4415.83 W 11173.26 8833.26 8750.00 4344.33 N 4460.29 W Formation Name Lower Cret. Unc. Miluveach JK Unconformity / Top Kingak Top Sag R~er Top Shublik TSAD Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> To Measured Depth 10957.46 12496.25 Vertical Depth (ft) 8668.26 8903.26 Casing Detail 7" Casing 4 1/2' Liner 11 August, 1999.9:38 - 4 - DrillQuest VENDOR ALASKAST t 4 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT N~T 0720c)9 CK072099 100. 00 " tOO. O0 HANDLING INST' S/H TERRI HUBBLE X46PEI ; L '/ ,. Anchor rilE A'n'ACHEO CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 1 OO.., OO .,. 1 OO. OO :.,:BP ,EXPLORATION (ALASKA).,:,,IN "'AN~HORAGE;ALASI~Ai;; 99519-6612 'F[iRST '~kTIONRL.:BANK OF ASH~;AND ': ;":i · '.. ?i' ,:AN:AFF.'.1UATE. OE ,::?::':' :::' . ~ ':?] ,:. C~EVELAND, OHIO . :~ ::::]:.."56-389: 412 No.. :H :' 00154459:; PAY DATE ',..,~i, , AMOUNT 07/21/99 '1':: I $100'001 :J"ALASKA STATE.;DEPT::OF REVENUE ?30Ot?PORCUPiNE.:... i::;i;O~:'::. :':~:' ' i':':: · . :.. ANCHORAOE AK 99501-3120 ,'&SLLSq"' m:EIt.;l,i?El:~SqSm: BOat, t, WELL PERMIT CHECKLIST COMPANY ~ ~ ~ WELL NAME ~ ~ fJL ~ -,2 ~o/~1 PROGRAM: exp __ dev ,ZX, redrll ~ serv __ wellbore seg ann. disposal para req __ FIELD & POOL ~ (--(/0/Y 0 INIT CLASS D ~ V ! - ~ ,T. ~ GEOL AREA & ? (~) UNIT# I I G $'"'r0 ON/OFF SHORE CO ~ ADMINISTRATION DATE I- 1. Permit fee attached ....................... (~ N 2. Lease number appropriate ................... ~ N 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long stdng to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~_~_~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. (~N Y N Y N Y N GEOLOGY A)~.~R DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones .,. ~ Y N 32. Seismic analysis ofshal~...'~. ....... Y N 33. Seabed co~(if off-shore) ............. Y N 34. ~hone for weekly progress reports [exploratory only] Y N ANNULAR DISPOSAL APPR DATE 35. ' h proper cementing records, this plan (A) ste in a suitable receiving zone; ....... Y N (B) will not contam~ltrate, J.E~hwater; or cause drilling waste... Y N to surface; ~ (c) ~ntegrity o~d for disposal; Y N (D) will not damage producing formation or impair rec from a Y N pool; and ~ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. N ENGINEERING: UlC/Annular COMMISSION: BEW WM DWJ ~ JDH -- RNC -- co c:o ~1,~/,~ ~ Comments/Instructions: 0 Z 0 ---I c:\msoffice\wordian\diana\checklist ~ Weli History File APPENDIX Information of detailed nature that is not ~ parlicula~iy geRnane to the Weli Permitting Process but is part of the history file. To improve the readabil~ty of the Well History file and to sirn.plify finding information, information of this nature is accumufated at the end of the file under APPENDtX. No special efifori has been made to chronologically . organize this category of information. Sperry-Sun Drzillng Services LIS Scan Utllzty SRevlslon: 3 S L~sLzb SRevis~on: 4 $ Mon Apr 22 16:34:32 2002 Reel Header Service name ............. LISTPE Date ..................... 02/04/22 Or~gln ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/04/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD iST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. W-26A 500292196401 BP EXPLORATION ALASKA, INC. Sperry Sun 22-APR-02 MWD RUN 2 MWD RUN 3 MWD RUN 4 AK-MW-90153 AK-MW-90153 AK-MW-90153 E. CRIBBS R. KRELL M. HANIK G. KIDD J. RALL J. RALL 21 llN 12E 945 1446 .00 83.07 54.61 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8000.0 6.125 7.000 10963.0 ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. W-26A KICKS OFF FROM W-26 AT WHIPSTOCK WITH TOP SET ,SCANNED MAY ~, 8 2002 AT 8000' MD, 6224' TVD. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA .RAY (DGR) UTILIZING GE!GER-MULLER TUBE DETECTORS. 5. 554D RUNS 3-4 ARE DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 6. DEPTH SHIFTING WAIVED BY D. SCHNORR PER THE E-MAIL OF 11/10/2001 FROM D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 10. MWD RUNS 2-4 REPRESENT THE MWD DATA FOR WELL W-26A WITH API# 50-029-21964-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12620' MD, 8863' TVDSS. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP ~ SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( ~IEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) PARAMETERS USED IN NEUTRON / POROSITY LOG CALCULATIONS: HOLE SIZE: 6.125" M~D WEIGHT: 8.4 - 8.5 PPG MUD FILTRATE SALINITY: 400 - 500 PPM CHLORIDE FORMATION WATER SALINITY: 11,500 PPM CHLORIDE FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Nuraber ........... 1.0.0 Date of Generation ....... 02/04/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Cor0ment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP NCNT FCNT NPHI RPX RPS RPM RPD FET $ START DEPTH 7990.0 8022 5 10902 5 10902 5 10902 5 10932 0 10932 0 10932 0 10932 0 10932 0 BASELINE CURVE FOR SHIFTS: STOP DEPTH 12578.0 12620.5 12556.0 12556.0 12556.0 12585.0 12585.0 12585.0 12585.0 12585.0 CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH $ MERGE2 DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 7990.0 10964.5 3 10965.0 11247.0 4 11247.5 12620.5 MERGED MAIN PASS. Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD FPH 4 1 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OH~94 4 1 FET MWD HR 4 1 NPHI MWD 4 1 FCNT MWD 4 1 NCNT MWD 4 i Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 Name Service Unit Min DEPT FT 7990 ROP MWD FPH 0.6 GR MWD API 16.37 RPX MWD OHMM 0.76 RPS MWD OHMM 1.44 RPM MWD OHMM 0.06 RPD MWD OHMM 1.6 FET MWD HR 0.5881 NPHI MWD 2.36 FCNT MWD 114.8 NCNT MWD 114.8 Max Mean Nsam 12620.5 10305.3 9262 456.33 58.0736 9197 527.47 104.286 9177 1651.94 10.6278 3307 1651.35 10.2134 3307 2000 29.0179 3307 2000 30.4718 3307 65.7982 3.24365 3307 58.41 21.6737 3308 4595.2 814,819 3308 4595.2 814.819 3308 First Reading For Entire File .......... 7990 Last Reading For Entire File ........... 12620.5 F~le Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/22 Maximum Physlcal Record..65535 File Type ................ LO Next File N~me ........... STSLIB.002 First Reading 7990 8022.5 7990 10932 10932 10932 10932 10932 10902.5 10902.5 10902.~ Last Reading 12620.5 12620.5 12578 12585 12585 12585 12585 12585 12556 12556 12556 Physical EOF F~le Header Service name ............. STSLIB.002 Servlce Sub Level Name... Verslon N,~ber ........... 1.C.0 Da%e of Generatlon ....... 02/04/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.00! Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each blt run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMNJ%RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7990.0 10932.0 ROP 8022.5 10964.5 $ LOG HEADER DATA DATE LOGGED: 25-SEP-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10965.0 TOP LOG INTERVAL (FT): 8022.0 BOTTOM LOG INTERVAL (FT): 10965.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.9 MAXIMUM ANGLE: 46.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data £pecificatlon Block Type ..... 0 Logging D!rection ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 8.500 8000.0 LSND-HT 10.90 40.0 9.4 1500 2.6 .000 .0 .000 156.2 .000 .0 .000 .0 Absent value ...................... -999 Depth Units ....................... Datum Specifzcatzon Block sub-~ype...0 Name Servlce Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 i 68 0 ! ROP MWD02C FPH 4 ! 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unlt Mln Max Mean Nsam DEPT FT 7990 10964.5 9477.25 5950 ROP MWD020 FPH 4.05 213.74 66.3485 5885 GR MWD020 API 45.46 437.15 133.664 5885 First Reading For Entire File .......... 7990 Last Reading For Entire File ........... 10964.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 7990 8022.5 7990 Last Reading 10964.5 10964,5 10932 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI RPX FET RPD RPS RPM GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 3 .5000 START DEPTH 10902 5 10902 5 10902 5 10932 0 10932 0 10932 0 10932 0 10932 0 10932 5 10965 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): STOP DEPTH 11184.0 11184.0 11184.0 11213.5 11213.5 11213.5 11213.5 11213.5 11206.5 11247.0 28-SEP-99 Insite 66.16 Memory 11247.0 10965.5 11247.0 HOLE INCLINATION (DEG MINIMUM ANGLE: M/LXiMUM ANGLE: TOOL STRING ~TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GD/~A RAY CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Data Fo~at Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD030 FPH 4 1 GR MWD030 API 4 1 RPX MWD030 OHMM 4 1 RPS MWD030 OHMM 4 1 RPM MWD030 OHMM 4 1 RPD MWD030 OHMM 4 1 FET MWD030 HR 4 1 NPHI MWD030 4 1 FCNT MWD030 4 1 NCNT MWD030 4 1 34.9 TOOL NUMBER PB02100HWRG6 PB02t00HWRG6 PB02!00HWRG6 6.125 10963.0 QUIKDRIL-N 8.40 39.0 9.3 40O 15.5 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 5.000 78.0 2.300 176.0 6.000 78.0 2.200 78.0 Name Service Unit Min DEPT FT 10902.5 ROP MWD030 FPH 0.79 GR NEWD030 API 20.99 RPX MWD030 OHMM 0.76 RPS MWD030 OHMM 1.44 RPM ~FWD030 OHMM 0.06 RPD MWD030 OHMM 1.6 FET MWD030 HR 1.2273 Max Mean Nsam 11247 11074.8 690 232.41 31.5644 565 527.47 9~.74~5 549 1651.94 31.5966 564 1651.35 28.9105 564 2000 136.228 564 2000 142.092 564 65.7982 9.72176 564 First Reading 10902.5 10965 10932.5 10932 10932 10932 10932 10932 Last Reading 11247 11247 11206.5 11213.5 11213.5 11213.5 11213.5 11213.5 NPHi MWD03C 2.36 58.41 24.5769 FCNT MWD03C !14.8 4595.2 1039.73 NCNT MWD03C 114.8 4595.2 1039.73 Fzrs~ Reaa~ng For Entire File .......... 10902.5 Last Readlng For Entire File ........... 11247 File Trailer Servlce name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/22 Max~mu~ Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 564 564 564 10902.5 10902.5 10902.5 11184 11184 11184 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. 4 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT GR RPS RPX RPM RPD FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 11184.5 11184 5 11184 5 11207 0 11214 0 11214 0 11214 0 11214 0 11214 0 11247 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 12556.0 12556.0 12556.0 12578.0 12585.0 12585.0 12585.0 12585.0 12585.0 12620.5 EWR4 DER CTN $ ELECTROMAG. RESIS. 4 DUAL GAMMA RAY COMP THERMAL NEUTRON 01-OCT-99 Insite 66.16 Memory 12620.0 11247.5 12620.0 46.4 105.2 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 PB02100HWRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONZiT!ONS MUD TYPE: MUD DENSITY (LB/G~: MUD ViSCOSiTY MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF~ MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 QUiKDR!L-N 8.5C 36,0 9.2 500 9.6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FPH 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 4 1 68 32 9 FCNT MWD040 4 1 68 36 10 NCNT MWD040 4 1 68 40 11 5.200 78.0 2.300 185.0 6.000 78.O 2.400 78.0 First Last Name Service Unlt Min Max Mean Nsam Reading_ Reading DEPT FT 11184.5 12620.5 11902.5 2873 11184.5 12620.5 ROP MWD040 FPH 0.6 456.33 45.7982 2747 11247.5 12620,5 GR MWD040 API 16.37 241.64 42.567 2743 11207 12578 RPX MWD040 OHMM 1,8 29.04 6.31627 2743 11214 12585 RPS MWD040 OHMM 1.67 34.36 6.36899 2743 11214 12585 RPM MWD040 OHMM 1.74 72.98 6.97402 2743 11214 12585 RPD MWD040 OHMM~ 1.71 91.33 7.52117 2743 11214 12585 FET MWD040 HR 0.5881 17.5331 1.91166 2743 11214 12585 NPHI MWD040 6.87 32.63 21.0769 2744 11184.5 12556 FCNT MWD040 377 2463.2 768.59 2744 11184.5 12556 NCNT MWD040 377 2463.2 768.59 2744 11184.5 12556 First Readlng Fcr Entire File .......... 11184,5 Last Reading For Entire File ........... 12620.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/22 Maximum Physical Record..65535 File Type ................ LC Nex~ File Name ........... STSLiS.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/04/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Nut, bet ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/04/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
