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Home My WebLink About202-0951 Coldiron, Samantha J (OGC) From:Boman, Wade C (OGC) Sent:Tuesday, March 12, 2024 12:29 PM To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] 10-404 and sundry question for PBU E-08A Attachments:[EXTERNAL] RE: PBU E-08A (PTD #202-095) 10-404 Sundry Report Submittal; PBU E-08B 10-407.pdf Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907‐793‐1238 cell: 907‐687‐4468 From: Kirsty Glasheen <kirsty.glasheen@hilcorp.com> Sent: Tuesday, March 12, 2024 9:20 AM To: Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 10‐404 and sundry question for PBU E‐08A Hi Wade, We opted not to complete the RWO on E‐08A. The 10‐404 noƟﬁcaƟon for pulling the LTP included a noƟﬁcaƟon that the RWO would not be executed. Please ﬁnd aƩached the email detailing this communicaƟon to the state from Hilcorp. E‐ 08A was sidetracked to E‐08B in 2023. So, this well is currently operable and online producing as E‐08B. I have aƩached the 10‐407 for this work. Please let me know if you need any further detail. Thank you! Kirsty Glasheen GC1 Operations Engineer 907‐350‐4310 907‐564‐5258 From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Monday, March 11, 2024 3:03 PM To: Kirsty Glasheen <kirsty.glasheen@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] 10‐404 and sundry question for PBU E‐08A You don't often get email from kirsty.glasheen@hilcorp.com. Learn why this is important 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Hi, Kirsty. For the producer PBU E‐08A we have Sundry 322‐559, allowing for a tubing swap, using SL, Coil, EL, and the Thunderbird #1 rig. However, in July 2023 a 10‐404 was submiƩed reporƟng only the LTP retrieval, which is only the ﬁrst step in in the SL/Coil porƟon of the sundry’s RWO procedure. Was there more work done to this well? Was any further work allowed by the sundry performed? Could you please provide the current status of the well? Thanks. ‐Wade Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907‐793‐1238 cell: 907‐687‐4468 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. 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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. 3-1/2"x3-3/16" By Grace Christianson at 9:58 am, Aug 31, 2023 Abandoned 9/11/2023 JSB RBDMS JSB 091123 xG DSR-9/25/23 Drilling Manager 08/30/23 Monty M Myers Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.30 16:11:23 -08'00' Torin Roschinger (4662) ACTIVITYDATE SUMMARY 7/25/2023 ***WELL SHUT IN ON ARRIVAL*** PRESSURE TEST PCE FROM 200LP - 3000HP RIH WITH 1 7/16 CABLE HEAD, 1.68" DC-MOT, 2.68" BAKER 10 SETTING TOOL, WHIPSTOCK (MAX OD = 2.72" , MAX LENTH = 22') ***JOB CONTINUED ON 26-JULY-23*** 7/25/2023 T/I/O=1184/559/0 Hot oil treatment (pre CTD) Pumped 130 bbls 180* DSL down tbg ***job continued to 07-26-23*** 7/26/2023 ***job continued from 07-25-23*** Pumped an additional 70 bbls 180* DSL down tbg (200 tatal) Final WHP's 1900/866/0 Pad Op notified 7/26/2023 ***WELL SHUT IN ON ARRIVAL*** PRESSURE TEST FROM 200LP - 3000HP SET NS MONO PACK 350 WEDGE ASSEMBLY AT 9795' MD TOW. CCL TO TOW=13.8', CCL STOP DEPTH=9781.2' INCLINATION=25 Deg, PINCH POINT=9795' MD, END OF TRAY=9801', BOTTOM OF WS = 9806'. RA MARKER=9800' MD, ORIENTATED 181.7 Deg ROHS. STACKED 150# OF TOOL WEIGHT AFTER SETTING. LOG TIED INTO SLB PRODUCTION PROFILE WITH GHOST DATED:23-MAY- 2014 ***WELL LEFT S/I, PAD OP NOTIFIED NOT TO POP*** 8/1/2023 T/I/O = 0/0/0. Set 6" J TWC. Removed tree. Installed 7" Spool and Dry Hole Tree. Torqued to spec. FWP = TWC/0/0 8/2/2023 T/I/O=TWC/0/0 PT tree 300 psi low & 5000 psi high (PASSED). Pulled 6" J CIW TWC #421. RD tree cap assembly RU 7" tapped blind flange. Final WHP's= 500/0/0. ***JOB COMPLETE***. RDMO. Daily Report of Well Operations PBU E-08A Activity Date Ops Summary 8/9/2023 Spot sub and pit modules over well E-08A. 8/10/2023 Short Pad, remove the SOW from the Sub and use the Stomper to spot over the well then the pits. Rig spotted, accept rig at 08:00. Start MIRU Ops to secure the cellar and start on MIRU Checklist. Spot Well Support Choke Trailer behind the rig. RU Hardline from the Mod Spool for the 3-1/2 annulus to the choke trailer and T in a return line to the Tiger Tank. PT all hardline to the Tiger Tank to 4500psi, good PT. PT the Tree Cap to the swab to 3850psi, good test, RD Tree Cap. Remove 4-1/16" Adapter. NU the BOPE. Remove 3" Pipe/Slip rams install 2-3/8" x 3-1/2" VBRs. Fluid pack reel and surface lines. Grease valves. Get RKBs, verify test jt measurements. Check and change packoffs. Purge air from lines. Test BOPs as per AOGCC and Hilcorp regs. Test is witnessed by AOGCC Inspector Guy Cook. All tests 250 / 3500 psi. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind / Shear, R2, BL2, C15 - Pass. Test 3: Annular (2-3/8"), TIW1, B1, B4 - Pass. Test 4: Upper 2" Pipe / Slip, TIW2, B2, B3 - F/P on Annular. Test 5: Lower 2" Pipe / Slip, C5, C6, C8, TV2 - F/P on TV2. Test 6: Choke A, Choke C - Pass. Test 7: VBRs (3-1/2"), C1, C4, TV1 - Pass. Test 8: C2, C3 - Pass. Test PVT sensors and gas alarms. Rig down BOP test equipment. Perform Draw Down Test. 8/11/2023 BOP Test completed, RD test equipment and PT PDL's. Continue kicking out Class B used 3-1/2 EUE tubing for holes and start loading new pipe in shed. Continue drift, strap & tally Velocity String. Simops: Two broken links found on injector chain during inspection. Decision is made to swap injectors. Remove UQC prep to unstab pipe. Pull CT out of injector back to shipping spool and secure it. Remove CT stripper, remove pump in sub. Continue prep injector for removal. Continue loading, drifting and strapping 3-1/2" EUE for velocity string. 8/12/2023 Velocity String is ready to run. Start NPT for Injector swap. RD Injector and prep for crane lift. Crane had a mechanical issue with the driving system coming to location, Low Boy trailer called out to bring crane to location. Crane on location, spot in and prep to swap injectors. Lift out old injector, lift in new one. Hook up hydraulic and electrical connections on injector. Test and troubleshoot injector functions. Install elastomers and gripper blocks. Install stripper. 8/13/2023 Finish installing Gripper Blocks and Packoffs. PU the Solid 2" OD joint and pull plate to pull test the injector to 100k. Troubleshooting Lower Traction Cylinder bleeding off/not holding. Pull test injector to 100k, good pull test. Install counter wheel and cart back to stab coil. MU BHI UQC, install floats. PT BHI Connections, good PT. Stab on and PT the Packoffs & Floats, good PT. Nabors off NPT. Hold PJSM to BH Kill well. Fluid pack kill line & stack with methanol and PT night cap to 4000psi, good PT. Open up to well, WHP = 535 psi, online with methanol down the tubing. Pumped 10 bbls of methanol, WHP climbed up to 3465 psi at 1.5 bpm. Shut down the pump and monitor WHP, WHP slow to bleed off, well looks like it's liquid packed. We are not going to be able to BH Kill this well at 7 bpm, prep for nozzle run. WHP slowly bled down to 1780 psi and stabilized. Close swab valves and bleed off to the TT, pressure dropped off, no gas all liquid. Purge stack out to the TT and Night Cap. MU a Nozzle BHA, stab on well and displace coil to Hot KCl. Coil displaced, pressure up to 1700 psi and open the swabs, WHP at 1100psi. RIH holding 100-200psi WHP over initial WHP of 500psi taking returns to the TT. Continue RIH for bottom kill returns to flowback tank. Stop at 7720' adjust gooseneck. Up wt 34k. Continue RIH light tag on whipstock at 9795' uncorrected. Pick up and shut in, vac out TT. RIH to 9790' and swap well to KCl. Gas-cut returns keep out rate < 1:1. Returns start to clean up start stepping down WHP. Stop and vac out TT then continue 2nd B/U continue stepping WHP down to full open choke. Flow check well - Good 20 min no-flow. POOH. 8/14/2023 POOH from bottoms up kill, flow check well while holding a PJSM to LD the Nozzle BHA. Good no flow, <1 bph loss rate. Line up to purge MPD Line out to the TT then purge lubricator. Close lower swab and line up pump to MPD Line for continuous hole fill and monitor well. PU injector and LD the Nozzle BHA. ND the Lubricator & Otis Flange. Lower 8" Riser, install bushings, lower 3-1/2" pup joint into the hand slips to verify clearance to the riser. Riser height is good, NU Riser. Load Dart & TIW Valves on RF. RU Elevators, grease crown sheaves to prep for running pipe. Install Air Boot on 8" Riser. RU tongs. Open swab valve and flow check well while holding PJSM to PU Velocity String. Good no flow. MU the 3-1.2" string with Mule Shoe. 23 jts in we have tagged something 2x and appears to be in the stack. PU and RIH slow, tag and measure distance to the collar. 23' measured, we are tagging at the 7" Adapter Flange, below the 3-1/2 Spool. Talked to WHS Clint Miller and its a 6-3/8" restriction in the adapter. Making an adjustment with the bales as we come down and its avoiding the lip. Continue M/U velocity string jt #100. D1 drill w/ McGrath crew, well secured in 2 min 10 sec. Continue M/U velocity string jt #227. P/U jt #288 and tag. P/U and spaceout. 8/15/2023 Velocity String Landed and LDS ran in. PU WT = 96k, SO WT = 76k. ND Riser and NU Otis Flange with test risers. Shell test against Swab Valves to change VBR's to 2-3/8" Combi's. Good shell test 3700psi. Swap VBR's to Combi Rams. Shell test stack, door seal leak, replace seal, shell test is good. PU test joint and test 2-3/8" Combi's, Test witness waived by AOGCC Insp, Sean Sullivan. Good PT. PT Lubricators on injector, good PT,. PU the milling BHA, mills gauged 2.81" Go, 2.80" No Go. Displace coil to mud. Displace 3-1/2 annulus & Tubing to mud while RIH. 3.5 bpm at 816 psi, set pump trips for 1500psi. Log tie in at 8600', coil and well swapped to mud. Correct depth -3', close EDC. Get up and down WT's and RIH to tag. PU WT = 38k, RIH WT = 24k. Dry tag pinch point at 9794.65', PU start motor and start milling window. Tag pinch point at 9794'. Free spin = 3175 psi. Rate In = 1.80 bpm, Rate Out = 1.80 bpm. Density in = 8.58 ppg, Out Density = 8.67 ppg. WHP = 15 psi, IAP = 487 psi, OAP = 0 psi, ECD = 9..84. Out density dropped off to 0ppg, send returns to TT no readings on the LEL or PPM at the shaker. Pumped 4 bbls out to the TT and returns cleaned up. Sample cup from returns has aired up mud no LEL or PPM readings. 10 bbls pumped to TT density has been stable bring returns inside. Mud balance out 8.7ppg. RIH to continue milling window. Mill window from 9794.7'. 1.78 / 1.77 bpm In / Out. 8.59 / 8.66 ppg. ECD 10.11 on open choke. Periodic 5 bbl lo vis sweep to reduce mud LSRV. Mill window from 9797.53'. 1.79 / 1.78 bpm In / Out. 8.58 / 8.66 ppg. ECD 9.98 on open choke. 8/16/2023 Mill window from 9798.49' to 9798.81. 1.79 / 1.76 bpm In / Out. 8.57 / 8.65 ppg. ECD 10.04 on open choke. DWOB 2.5 - 3k. Mill window 9798.81' to 9799.13'. Rate: 1.81 bpm in, 1.80 bpm out. Mud Weight: 8.57 ppg in, 8.65 ppg out. DWOB: 2.5 to 2.7 klbs. Circ pressure: 3387 psi. Milling off after picking up and restarting. Stalled. Looks like motor chunked. Open EDC, Pooh. Rate: 2.44 bpm in, 2.05 bpm out. Circ pressure: 3545 psi. Mud Weight: 8.57 ppg in, 8.65 ppg out. Perform 100' jog at 1000' Pooh. Tag up. Perform flow check. Good flow check. Rubber in mill. Attempt to blow down motor. Swap motors, Rerun reamer and bit. RIH BHA #3 - 2nd Window Mill. Tie-in depth from 9600' correct -7'. P/U and CCL across velocity string TT, 7" x 4-1/2" XO and CTD liner top area. Close EDC. Pump 1.83 / 1.82 bpm ease down to engage casing. 3150 psi Free Spin. Mill 2.8" window from 9796.3' about 3' higher than yesterday. P/U and tie-in again from 9600' correct +1.5'. RIH dry tag 9797.9'. P/U mill window from 9798.1'. 1.78 / 1.78 bpm In / Out. 8.58 / 8.66 ppg. ECD 10.02 on open choke. DWOB 2 - 3k. 9798.55' pump 5 bbls lo / hi vis sweeps. Progress is slow, P/U and restart. Mill 2.8" window from 9798.4'. 1.80 / 1.79 bpm In / Out. 8.57 / 8.65 ppg. ECD 10.08 on open choke. DWOB 2 - 3k. 50-029-20452-02-00API #: Well Name: Field: County/State: PBW E-08B Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 8/17/2023Spud Date: 8/17/2023 Mill 2.80 window in 3-1/2 liner per NSAK from 9798.4 md to 9800.31'. Rate: 1.81 bpm in, 1.81 bpm out. Mud Weight: 8.57 ppg in, 8.65 ppg out. DWOB: 3.0 to 3.5 klbs. Circ pressure: 3384 psi. Stalled PU. Mill 2.80 window in 3-1/2 liner per NSAK from 9800.31'. Free Spin Circ pressure: 3327 psi (680 psi diff). Rate: 1.80 bpm in, 1.79 bpm out. Mud Weight: 8.57 ppg in, 8.65 ppg out. DWOB: 3.0 to 3.5 klbs. Appears we exited. Mill to 9801' MD. Begin milling rathole. Mill rathole to 9810' MD. Pump 5bbls HiVis. Perform reaming passes 15L , 15R of as milled. 75 psi motor work seen on passes. Perform another round of passes. No issues. Dry drift is clean tag end of rathole. Good 10 min no-flow at window. Open EDC, POOH. TOW 9794'. BOW 9800'. 10 min no-flow at surface. Lift injector, check CT above CTC, good. L/D BHA #3 - Window Mill. Mill and reamer both 2.80" Go / 2.79" NoGo. M/U nozzle to jet stack. Jet stack. M/U BHA #4 - 3.25" Build BHA w/ 1.9 deg AKO. RIH BHA #4. Log tie-in from 9600' correct -5'. Close EDC, up wt 36k. Pass window dry no issue. Go to min rate tag 9810'. PU 36k + 2' go to drill rate. Ease down start drilling. Drill 3.25 build from 9810'. 1.78 / 1.75 bpm. MW 8.57 / 8.66 In / Out. Pcirc 3450 - 3600 psi. Window ECD 10.06 ppg on open choke. ROP 10 - 30 ft/hr. Drill 3.25 build from 9860'. 1.80 / 1.74 bpm. MW 8.57 / 8.67 In / Out. Pcirc 3400 - 3550 psi. Window ECD 10.11 ppg on open choke. ROP 10 - 40 ft/hr. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT E-08A JBR 09/29/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 I did not witness the test on the inside reel valve or the stripper. A combi test joint was used for testing. The sizes tested were 2" and 3.5". The annular failed the initial and was cycled and the pressure on the bag was adjusted. Retested for a pass. The Piper valve (TV2) failed the initial and was serviced and retested for a pass. There will be two 3.5" TIWs and Darts that will be brought out to the rig once they are made up at a different location to be used. They will be tested at that point before they do the well kill or go in the hole to work. I asked that they send me the charts that include the testing of these components. These are in addition the the two TIWs that I witnessed that were 2". Test Results TEST DATA Rig Rep:N. Wheeler/G. CoyneOperator:Hilcorp North Slope, LLC Operator Rep:M. Igtanloc/T. Cavanaugh Rig Owner/Rig No.:Nabors CDR2AC PTD#:2020950 DATE:8/11/2023 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopGDC230810062810 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 2457 Sundry No: 323-395 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2"NT Annular Preventer 1 7 1/16" 5000 FP #1 Rams 1 Blind/Shear P #2 Rams 1 2" solids P #3 Rams 1 2 3/8"x3.5" V P #4 Rams 1 2" solids P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 2 2 1/16" 5000 P Kill Line Valves 2 2 1/16" 5000 P Check Valve 0 NA BOP Misc 2 2" Piper FP System Pressure P3000 Pressure After Closure P2225 200 PSI Attained P15 Full Pressure Attained P39 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10@1960 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 NT Annular Preventer P6 #1 Rams P2 #2 Rams P1 #3 Rams P1 #4 Rams P1 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9999 9 9 9 9 9 9 9 &KDUWVDWWDFKHGIRUWHVWVRIDGGLWLRQDO)ORRU6DIHW\9DOYHV FP FP annular failed Piper valve (TV2) failed two 3.5" TIWs and Darts that will be brought out to the rig once they are made up charts that include the testing of these components. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU E-08A Pull LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-095 50-029-20452-01-00 11776 Conductor Surface Intermediate Liner Liner 9050 80 2645 9497 944 2790 11740 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 9052 30 - 110 29 - 2674 28 - 9525 9002 - 9946 8986 - 11776 30 - 110 29 - 2674 28 - 8508 8028 - 8890 8014 - 9050 11702 2670 4760 7020 13890 10100 5380 6870 8160 13450 9745 - 11610 7" 26# x 4-1/2" 12.6# L80 26 - 9043 8707 - 9054 Structural 7" Baker Packer 8934, 7966 8934 7966 Torin Roschinger Area Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028299, 0028304 26 - 8066 N/A N/A 134 Well Not Online 50177 18 0 500 1305 720 322-559 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:33 am, Jul 13, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.12 20:49:34 -08'00' Torin Roschinger (4662) RBDMS JSB 071323 DSR-7/13/23WCB 3-12-2024 **See the well folder for Kirsty Glasheen's (Hilcorp) email about the disposition of this well. Its RWO was canceled, and the well was sidetracked to E-08B instead. -WCB ACTIVITY DATE SUMMARY 11/11/2022 T/IA/OA=2100/0/0 (Assist Slickline Load and MIT-T). TFS U3. Temp= 38*. Pumped 520 BBLS of 120* crude down the TBG to load for SL. Pumped a total of 4.5 bbls of 50* crude down Tbg to achieve test pressure of MITxT 2000 psi MAX applied 2250 psi . 1st 15min = Tbg lost 50 psi / IA lost 20 psi // 2nd 15 min= Tbg lost 50 psi / IA lost 40 psi. Total test Tbg lost 50/50 psi ***FAIL*** . Did not bleed down Tbg per Sline. TAGS HUNG. Sline incontrol of well and Pad Op. notified of well status upon departure. CV's=OTG FWHP's=2000/600/0 11/11/2022 ***WELL S/I ON ARRIVAL*** (Pre CTD) BRUSHED TOP OF PACKER @ 8,974' MD WHILE THUNDERBIRD LOADED TUBING W/ 520 BBLS OF CRUDE SET LTTP @ 8,974' MD. THUNDERBIRD ATTEMPTED 2000PSI MIT-T(Failed, TBG linear leak 50psi in 15min, IA linear leak 20psi in 15min) RAN READ 40 ARM CALIPER TO LTP @ 8,974' MD ***CONTINUED ON 11/12/22*** 11/12/2022 ***CONTINUED FROM 11/11/22 WSR*** (Profile modification) LOGGED w/ READ 40 ARM CALIPER FROM 8,971' MD TO SURFACE. PULLED LTP TEST TOOL @ 8,974' MD SET 4 1/2" RELEASABLE SPEAR IN LTP @ 8,974' MD JARRED ON SPEAR FOR 1 HOUR TO ENSURE GOOD SET ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 12/3/2022 LRS CTU #2 - 2.0" Coil Job Objective: Fish LTP MIRU CTU. Make up Fishing BHA with 3" Hydraulic GS & RIH. PUW = 26k. Tag & latch baited 4.5" KB LTP at 8,973' CTM, 10k overpull. Work jars up incrementally to 55k-60k. Hit 100 jar licks, no movement of LTP. Pump off fish w/no issues and Pooh w/BHA. ...Job in Progress.... 12/4/2022 LRS CTU #2 - 2.0" Coil Job Objective: Fish LTP Continue Pooh w/BHA. Cut 50' of pipe. M/U YJ Fishing BHA w/3" Hyd GS and RIH. PUW 23k. Tagged & latched LTP at 8,973' CTM (8974 MD). Hit 8 jar licks at 55k and pulled free. Re-tag 6-8k down. No overpull. Pooh w/BHA to inspect. Fish on, unable to close Master Valve. RIH and Leave packer at 8985' CTMD. POOH and shorten BHA. RIH and latch LTP at 8985' CTMD and POOH. LTP Recovered. RDMO CTU. ***Job Complete*** Daily Report of Well Operations PBU E-08A RIH and latch LTP at 8985' CTMD and POOH. LTP Recovered. RDMO CTU By Grace Christianson at 1:31 pm, Jul 13, 2023 323-395 Drilling Manager 07/13/23 Monty M Myers MGR14JUL23 DSR-7/13/23 * 20 AAC 25.112I(i) Alternate plug placement approved for abandonment with fully cemented liner on upcoming sidetrack. * BOPE pressure test to 3500 psi. 10-407 MDG 7/17/2023JLC 7/17/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.18 00:12:49 -05'00'07/18/23 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: July 13, 2023 Re: PBU E-08A Sundry Request Sundry approval is requested to prepare E-08A for a CTD sidetrack. Proposed plan for E-08A Producer: Prior to drilling activities, E-line will then set a 3-1/2" packer whipstock (if not possible, will set with rig). See E-08B PTD request for rig details - A ~3100’ MD coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The whipstock will be set pre-rig in the 3-1/2” liner. The rig will move in, test BOPE and kill the well. CDR2 will run 3-1/2" tubing and sting into the 4-1/2" tubing stub. A dual string window exit (3-1/2"x7") + 10’ of rathole will be milled. The well will kick off in Zone 4 and land in Zone 2 to TD. The proposed sidetrack will be completed with a 2-3/8” L80 solid liner, cemented in place and selectively perforated post rig. This completion will completely isolate and abandon the parent Ivishak perfs. CDR2 will pull the 3-1/2" workstring before leaving the well. This Sundry covers plugging the existing perforations via cement squeeze, liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work - (Estimated to start in July 2023): Pre-Rig Work 1ELSet whipstock 2 Valve Shop Pre-CTD tree work (install 3-1/2" tubing spool, sarber spool, PT swab, leak- tight master) 3 Valve Shop Bleed wellhead pressures down to zero. 4 Valve Shop Bleed production, flow and GL lines down to zero and blind flange. 5 Operations Remove wellhouse and level pad. Rig Work: x MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,457 psi a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Testing of 3-1/2” liner rams required d. Load pits with drilling fluid e. Open well and ensure zero pressure. Kill well if necessary x Run 3-1/2” drilling liner to ~8940’. a. Hang off liner in tubing spool x Mill 2.80” single string window (out of 3-1/2” and 7”) plus 10’ of rathole a. Swap 3-1/2” liner rams for 2-3/8” liner rams. Perform ram test b. Top of window (whipstock pinch point) at 9795’ MD. c. Mill window This completion will completely isolate and abandon the parent Ivishak perfs. Sundry 323-395 d. Hold 9.8 ppg MPD while milling window x Drill build section: 3.25" OH, ~437' (25 deg DLS planned). x Drill production lateral: 3.25" OH, ~2675' (12 deg DLS planned). x Run and Cement 2-3/8” L-80 solid liner. Pump cement job: 26 bbls, 15.3 ppg, TOC at TOL*. x Recover 3-1/2” drilling liner. a. Swap to 3-1/2” liner rams b. Pull 3-1/2” drilling liner c. Freeze protect well from ~2200’ MD (min) d. 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6U5HV(QJ By Samantha Carlisle at 12:32 pm, Jan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• STATE OF ALASKA • RECEIVED ' ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 31 2012 REPORT OF SUNDRY WELL OP RATIONS 1. Operations Abandon LJ Repair Well U Plug Perforations u PerforateV Other CiCe z Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension 10550' - 11200' Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other Er Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development © Exploratory ❑ ` 202 -095 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029 - 20452 -01 ^' 00 7. Property Designation (Lease Number): air l 8. Well Name and Number: ADL- 028299 o.,13l7f' S 1 PBU E -08A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): l 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11776 feet Plugs measured NONE feet true vertical 9050 feet Junk measured 11702 feet Effective Depth measured 11740 feet Packer measured SEE BELOW feet true vertical 9052 feet true vertical SEE BELOW feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" CONDUCTOR 28' -110' 20' -110' Surface 2674' 13 -3/8" 72# L -80 27' -2674' 27' -2674' 4930 2670 Production 9499' 9 -5/8" 47# L -80 26' -9525' 26'-8508' 6870 4760 Liner 936' 7" 29# L -80 9002' -9938' 8028' -8883' 8160 7020 Liner 860' 3 -1/2" 8.81# L -80 8986' -9846' 8014' -8799' Liner 128' 3- 3/16" 6.2# L -80 9846' -9974' 8799' -8915' Liner 1802' 2 -7/8" 6 -16# L -80 9974'- 11776' 8915' -9050' 13450 13890 Perforation depth Measured depth SEE ATTACHED feet True Vertical depth feet 7" 26# L -80 25' -8937' 27' -7968' Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.75# L -80 8937' -9043' 7968' -9043' 7" BAKER PACKER 8934' 7966' Packers and SSSV ( type, measured and true vertical depth) 4-1/2" BKR KB LT 8974 ' 8003 ' 7" BKR LTP 9002' 8028' 12. Stimulation or cement squeeze summary: t�N �I Intervals treated (measured): SEE ATTACHED DISCRIPTION OF WORK COMPLETED S .d A ED jG 2 0 201 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: 480 3 3 6 6 9 18 2151 Subsequent to operation: 812 53 516 16 195 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development © - Service ❑ Stratigraphic ❑ Daily Report of Well Operations g 16. Well Status after work: ., Oil © Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: Contact Nita Summerhays Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatur _4 - �� Phone 564 -4035 Date 07/27/2012 E RBDMS AUG 12c /r S!! � /17-- e/0L �( �r Submit Ori inal OnlZ , rZ Form 10-404 Revised 11/2011 g y � 1 • • • E -08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AcTivIT'r tE J 'SUMMARY 5/28/2012 CTU #9 1.75" Coil Tubing - Job scope = Unload the well with N2 Pumped N2 to unload the well with RIH by 500ft and rate increase by 100scf increments. Stop at 6000' ctm and lift. Pooh and monitored well. Production rates were 1000 - 1200 bbl /d 2.5 - 3.5 mm/d gas with a 4% water cut. Turn well over to production. «» 5/27/2012 CTU #9 1.75" Coil Tubing RIH with 2.25" milling assembly. Tagged liner top at 8984' ctm, puh and rolled pump to get into liner. Tagged plug at 11213' ctm, puh and began to mill on plug. Chased plug down to 11702' ctm. POOH displacing coil to 60/40 methanol. Pumped 25 bbls of 60/60 methanol down the tubing for a freeze protect cap. MU 2.25" JSN and opened well to production. RIH to 1000'. Started pump nitrogen and RIH. <o> 5/27/2012 T /I /O = 280/872/0 ( Test cement plug) Pumped 2.2 bbls of neat meth down TBG reach test pressure of 1000 psi. In a 15 min test the TBG lost 8 psi. Plug is GOOD per WSL. SV, WV,SSV = CLOSED MV, IA, OA = OPEN FWHP = 500/875/0 5/25/2012 CTU #9 1.75" Coil Tubing - Job Scope = Acid wash/Drift, Tie in Log, Set Bridge Plug, Organoseal /Cement <o> Parked at 9100ft and squeezed cement across perforations. After 19.lbbls of cement were pumped (4.35bbls of 19.lbbls injected into the formation) formation locked up with 2bbls of cement in CT. Opened the choke and left 2bbls of cement 1:1 while maintaining constant WHP at 1000psi. PO to safety depth and injected another 2.9bbls of cement with maximum WHP - 2500psi. Totally pumped 21.1bbls of cement. Totally injected 7.25bbls. Launched a ball and started clean out run. Jetted and left Biozan across perforations. POOH while jetting at 80% speed. Chase to surface, rbih to 2500' ctm and freeze protect well with 60/40 methanol to surface. Leave well with 1000 psi trapped on it. <o 5/24/2012 CTU #9 1.75" Coil Tubing - Job Scope = Acid wash/Drift, Tie in Log, Set Bridge Plug, Organoseal /Cement <o> S et plu• at 11216ft corrected depth, good pressure spike observed when ball reached the setting tool. Tag plag with 2klbs to confirm. POOH and BD CBP toolstring. MU slim cementing BHA.RIH and tag the plug at 11208, pump 1% KCL down the backside 270 bbls, followed by 250 bbls of diesel. pumped 260bbls of OrganoSeal with- 1500psi WHP. Pumped 21.1bb1 of SqueezeCRETE down the CT and followed by fresh water. <o> 5/23/2012 CTU #9 1.75" Coil Tubing - Job Scope = Acid wash/Drift, Tie in Log, Set Bridge Plug, Organoseal /Cement Make up and RIH w/ 2.25" drift nozzle, light set down at 11662' ctm, puh above liner and begin fluid packing the well with • • NH4CL. Do a .5, 1, 2, 3 ,4 bbl /min step rate test after 1.5 well bore volumes pumped. Pumped 52 bbls of 12% HCL followed with 55 bbls of 9:1 Mud acid. Over flushed the acid with 300 bbls of NH4CL. Pumped 20 bbls of 60/40 methanol on top of well for freeze protect. MU and RIH w/ BOT coil BHA and SLB memory Gamma Ray and CCL. RIH and logged from 11550ft to 10800ft, flagged pipe (yellow /white) at 11200ft, POOH. Good data verified, RIH with plug setting BHA. «» 5/22/2012 CTU #9 w / 1.75" ct: Job objective. Acid treatment / Set composite Plug / OrganoSEAL / SQZ Crete / Mill plug Arrived on location, RU and spot equipment. MU 2.25" BDJSN drift BHA. «» 5/17/2012 ** *WELL S/I UPON ARRIVAL * ** RAN 2.15" CENT, 1 1/2" SAMPLE BAILER TO DEVIATION @ 10,176' SLM. RAN 4.50 CENT. TAGGED 7.5" x 4.5" X -OVER @ 8892' SLM (45' CORRECTION TO 9437' MD). RAN SBHPS W/ SLB MEMORY GAUGES PER PROGRAM. GOOD DATA ***WELL LEFT S/I UPOIN DEPARTURE*** 12/22/2011 T /I /O= 1720/0/800 ( MITx IA Inconclusive) WSR continued from 12- 21 -11. Bleed IA pressure to 93 psi. RDMO. FWHP= 1720/93/667. Well on line @ departure. IA and OA open to gauges. Operator notified. 12/21/2011 T /I /0= 1720/0 +/800 ( MIT x IA to 1500 psi FAILED) Well flowing during job. Pumped 2 bbls 60/40 meth down the IA to achieve a test press. of 1500 Psi. ( MITx IA FAILED ) IA gained 5 Psi in 1st 15 min and gained 3 Psi in 2nd 15 min for a total gain of 8 Psi in 30 min test. ( NOTE: OA kept gaining press slowly during test causing test to fail. See pumping log for details. ) WSR continued on 12 -22 -11 FLUIDS PUMPED BBLS 251 DIESEL 64.8 METH 371.3 60/40 METH 52 12% HCL ACID 55 9:1 MUD ACID 870 NH4CL 372 1% KCI 86.5 FRESH WATER 21.1 CEMENT 260 ORGANOSEAL 80 BIOZAN 2483.7 TOTAL E -08A PERF ATTACHMENT 202 -095 Sw Nam a Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base E-08A 8/28/02 PER 10,550. 10,900. 9,044.17 9,046.87 E -08A 8/28/02 PER 11,475. 11,520. 9, 048.03 9 , 049.27 E-08A 8/28/02 PER 11,245. 11,425. 9,045.35 9,046.19 E -08A 8/28/02 PER 11,550. 11,610. 9,050.9 9,053.64 E -08A 8/28/02 PER 10,935. 11,090. 9,047.69 9,050.69 E -08A 8/28/02 PER 11,125. 11,200. 9,049.65 9,046.35 E -08A 9/20/08 BPS 10,005. 11,610. 8,940.77 9,053.64 E -08A 10/18/08 BPP 10,005. 11,610. 8,940.77 9,053.64 _ 3/19/0 8 010.8 9 044.17 E -08A 9 10 550. , ' ' -- -- - -- - 8 00 E -08A 12/8/0 P BPP 8 983. 18 9,044.17 ' , . E -08A 5/25/12 BPS 8,983. 11,610. 8,010.8 9,053.64 E -08A - -- 5/27/12 BPP - - - - - 8,983. - -- - - - - -- - -- 8,010.8 9,053.64 AB ABANDONED PER PERF APF ADD PERF BPP BRIDGE PLUG PULLED RPF REPERF ULLED SL I SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK S TO STRADDLE PACK, OPEN OH TOPEN HOLE 1 • TREE= meta( WELLHEAD = MCEVOY • E —0 8A silly NOTES: WELL ANGL.E> 70° @ 10127'. ACTUATOR = OTS KB. ELEV = 60.7' BF. ELEV = 32.56' KOP = 3150' I 2053' H7" OTIS RPB NP, D = 5.962" Max Angle = 93" 0 11697' Datum MD = 10939' _ — I 2596" H9-5/8" DV PKR Datum 1VD= 8800'SS 113 -3/8" CSG, 72#, L -80 BUTT, D = 12.347' H 2674' Minimum ID = 2.36" @ 8981' 4 -1/2" KB LT PKR SEAL UNIT 8910' BKR SBR SEAL ASSY I ! 8934' H9 -5/8" X 7' BAKER PKR, D = 6.00 1 17' TBG, 26#, L -80, .0383 bpf, D = 6.276' —I 8937' 893T Hr X 4 -1/2' XO, D 3.958" I 4 h.. 8974" -8992' H4 -1/2" BKR KB LT PKR, D = 2.36' (03/19/09) I 8981' H4 -1/2" OTIS X NP, D= 3.813" 1 I 8986' J-13.70" BKR DEPLOY SLV, D = 3.00" 1 ■ �• ■ 8991' H3 -112" STL BOX PEN, 0= 2.99? I I TOP OF 7" LNR H 9002' I ►i i 9002' J ' I -5/8" X 7" BKR LTP, D = ? $ I 9012' I— 4-12" OTIS XN NP, PALLED TO 3.80" (0822102) ■ 8Et4N0 CT LNR ► I i 9043' H4-12" BKR S06 ■ 4 -12", 12.75#, L -80, CS HYDRL H 9043' � • . 9044' ,— I4-12' WLEG. D= 3.953' ■ TALPPE, V= 3.953" V • ♦� •i i I 1 H E K) TT NOT LOGGED I : : is ♦i 1 9-5/8" CSG, 47 #, L -80 BUTT, D = 8.681" I 9525' • ♦ .1 ♦ • I • ♦ 1 i� • ♦ i iI • 1 i1 • o• 411 *I 13-1/2" LNR, 8.81#, L -80 STL, .0087 bpf, D = 2.992" H 9846' 9846' _I-13-1/2" X 3-3/16" XO, D = 2.766" 17" BKR GEN 11 WHPSTOCK H 9938' ♦ 1 • • , 3.80" MLL W)OW (E -08A) 9946' - 9953' 1 LNR, 29#, L -80, .0371 bpf, D = 6.184" IH 10283' e•• • • i • i • •• I 9974• H3-3/16" X 2 -7/8 X0, D= 2.372' I PERFORATION SUMMARY ► � � A � � � AWAVA ∎A REF LOG: MWD GR ON 08/27/02 \i �� ...,7 ( 11702' CTM — FISH CEP ANGLE AT TOP PERF: 91° 11245' ' � ► 4 ' • � '4'4'4'4 ' s MLLE) 8 Note: Re @r to Production DB for historical pert data \ / (05/27/12) SIZE SPF 1+ITERVAL Opn/Sqz SHOT : or 2' 4 10550 -10900 S 08/28/02 3 -3/16' LNR, 6.2#, L -80 TC-II, H 9974' 2' 4 10935 -11090 S 08/28/02 0525/12 ,0076 bpf, D = 2.80" 4 1125 -11200 S 08/28/02 05/25/12 2' 4 11 45 -11425 0 r :, :02 2' 4 11475 - 11520 0 08/28/02 PB "' 11740' 2' 4 11550 -11610 0 08/28/02 , I2 -7/8" LNR, 6.16#, L -80 STL, .0058 bpf, D= 2.441" —1 11776' DATE REV BY CO E NTS .. M ATE REV BY CONVENTS PRUDHOE BAY UNIT 05/04/80 N22E ORIGINAL COMPLETE N 03/23/09 MLI/SV SET LTP (03/19/09) WELL E-08A 08/28/02 NORDIC 1' CTD SIDETRACK 05/21/12 SW JJMD DRAWING CORRECTIONS PERMIT No: v 020950 10/15/08 JRA/PJC DRAWING CORRECTIONS 05/30/12 AFLM) CMT SQZ, CUP MLLE') (05/25 -27/1; AA Na: 50- 029 - 20452 -01 10/15/08 GJF /PJC SET WRP (09/20/08) SEC 6, T11 N, R14E, 133' FTL & 500' FE_ 10/27/08 PJC DRAWNNG CORRECTIONS 10/27/08 CM/ PJC PULL WRP/ KB PKR (10/18/08) . 8P Exploration (Alaska) e e WELL LOG TRANSMITTAL þÓt9-(/j5 To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 l~tp0~ RE: MWD Formation Evaluation Logs E-08A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 E-08A: LAS Data & Digital Log Images: 50-029-20452-01 1 CD Rom ~ !II {W~I OIÞ . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth -'h--CiJE-36 :¡~,.Ol!Z-05 g3 -C~NR-13 ífJ- Ie 7 02-07 A ~¥' !(}; N-01A ~"".L&.~1 L5-05 :-ldl F-27 .t; y tl..-O;1 D.S.06-14A ìC¡-¿1'? D.S. 02-27 A "3'.}-10 0.5. 03-22 =2 - Cì5 E-08A ;'1 -157 - E-19A ìS-CL'3 C-08A Well Job # 10679044 10679035 10772272 10772244 10877782 10679070 10662946 10563157 10772247 10687697 10728384 10678042 10728385 RST RST RST RST RST RST RST RST RST RST MCNL RST MCNL SCANr...JEC JUN J 7 2005 Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: 1ø~iç d£Jz ~~9ô /(/ 02/03/05 NO. 3327 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 12/25/03 1 1 11/28/03 1 1 06/06/04 1 1 04/07/04 1 1 08/27/04 1 1 04/05/04 1 1 09/13/03 1 1 05/13/03 1 1 04/10/04 1 1 07/20/04 1 1 01/01/04 1 1 12/21/03 1 1 01/03/04 1 1 ---- - Alaska Data & Consulting Services 2525 Gambell Str. eet.., SU.ite 400 . tL AnChora9.e, AK ~995..03_283?18 ATTN: settf" J//J ' / Rec~¿; by: ,/;æw; ·14 ~ ~' fI ;( 8 J t,rf' ~. (Nf'1 DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2020950 Well Name/No. PRUDHOE BAY UNIT E-08A Operator BP EXPLORATION (ALASKA) INC 5,fA. ¿ ~ '1 &, .4u 1..- API No. 50-029.20452-01-00 MD 11776 ,---- TVD 9050".- Completion Date 8/28/2002"- Completion Status 1-01l REQUIRED INFORMATION Mud log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, Memory CNl, CCl Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name ~ Directional Survey e--c ~Neutron log Neutron ~ E~ ~ C Asc ß216 LIS Verification C Pdf - '--r2216 Rate of Penetration ~ction Log Log Run Scale Media No 1 Blu Directional Survey i11'S30 LIS Verification LIS Verification ~ .~ 25 2 Blu 2 Blu 2 Blu ....L or- --- CC:l5i"9~IIQr I()...dtor ¿p/ Neutron Well Cores/Samples Information: Name Interval Start Stop Sent Received Current Status 1-01l UIC N ---~~ Directional Survey No ----~- (data taken from logs Portion of Master Well Data Maint) .~ Interval OH / Start Stop CH Received Comments 9900 11776 Open 10/2/2002 8766 11724 Case 1/10/2003 8766 11724 Case 1/10/2003 9900 11776 Open 10/2/2002 9932 11741 Case 3/17/2003 9932 11741 Case 3/17/2003 ._-~ ,-.. tA/ t) 9936 11776 9964 11776 Open ROP, DGR 10370 11640 Case 1/30/2004 Production Profile, Memory GRJCCUCNUSTP 10370 116'10 C360 1/30/200'1 PrQduction [1rofilc, Mðmory 10317.~'.' 11(c 10).t../case G~U~~Tr I~ rl./(c¡'/M'¿~' fó '0 1C4 1/3012004 Produ~ivlI PlOfl~.'Memory GRJcrL.iONUSTP Sample Set Number Comments Permit to Drill 2020950 MD 11776 TVD 9050 ADDITIONAL INFORMATION Y{Ð Chips Received? ..y I N ~ ~ Y iN Well Cored? Analysis Received? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. PRUDHOE BAY UNIT E-08A Operator BP EXPLORATION (ALASKA) INC Completion Date 8/28/2002 Completion Status 1-01L Current Status 1-01L Daily History Received? ~ ~/N Formation Tops ~fD Date: API No. 50-029-20452-01-00 UIC N ~---~ } C\t~~'i Color Well Job# Log Description Date Blueline Prints PSI-05 40009587 OH EDIT LWD ARC & ADN (PDC) 09/25/03 PSI-05 40009587 MD VISION RESISTIVITY 09/25/03 1 PSI-05 40009587 TVD VISION RESISTIVITY 09/25/03 1 PSI-05 c)Jfl~ )39 40009587 MD VISION DEN/NEUTRON 09/25/03 1 PSI-05 40009587 TVD VISION DEN/NEUTRON 09/25/03 1 PSI-OS 10703940 RST-SIGMA 10/25/03 1 PSI-05 10679041 ~ST-SIGMA 12/20/03 1 D-18A r()\ '- \o..~ 10564487 RST-SIGMA 06/19/03 1 05~8 ~f. -O~i( 10674406 RST-S1GMA 12/31/03 1 02-04A ~ .' 0- \P? 10728382 MCNL 12/08/03 1 E-08A ':;'c'~...r1:,'""-" 10728384 PRODUCTION PROFILE 01/01/04 1 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. PetrotechnicaJ Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Date Delivered: ----. ," <:::::::-- KC\J \ ~.\. IV'.. U r_~,~ Ä~, ---.... ::---:...'- c" ---'J -"' . ~ ""\.0- ,'''<\... 0 1 123/04 NO. 3098 Company: ~tate of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~.., CD J~~:¿ 'q, ~ 1 1 1 1 1 ~v c¡~ '(- ~C{ , )~'~~ !ç2\.~X <=1. þl.39 ~) Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received by: RECEIVED I ^ ~. -. C: I)I'\{' A 0;',!¡ .), L.i.l\¡L~ :Aj~~a. Oil & Gas Cons. Cornmision A~ ( ~o 2 -(J 1~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue~ Suite 100 J\nchorage,A1aska 99501 June 05~ 2003 RE: MWD Formation EvaIuationLogs: E-08A, AK-MW-22142 E-08A: Digital Log Images 50-029-20452-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, A1aska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, A1aska 99508 f Date:J ~ ( 0 a3 Signed: $~ ¿;¡" "ì .: ""''In . ca -(")~1,5 II tc,,3() WELL LOG TRANSMTITAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Fonnation Evaluation Logs E-08^ 1 LDWG fonnatted Disc with verification listing. API#: 50-029-20452-0 I March II, 2003 AK-MW-22 142 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~., "- ,..,~) Signoo(- ~"" ~ BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ RECEIVED :1 MAR 1 J 2003 AJaliœ œ¡ & Gæ Coos. CormniRion Ancbcnge Scblullbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5111 ATTN: Beth Well E-09Bj::ff:RrmJ~(.,?l')lðl E-08A ~O~-OCf~ NK-27 I q .'1- oa ) Job# 22465 MCNL 22401 MCNL 22485 RST Log Description Date 09/07/02 08/27/02 10/22/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED JAN 1 0 2003 AJaeka œ & Gas Cons. CommIaeion AncflGrlge Blueline 01/06/03 NO. 2644 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints ~ CD ~. Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Receiv~ 6 Ooop--J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 f.:'":' '... ." ...,-1 4. Location of well at surface ',"":,,::;,',:,7.;';"~':-";'~ ~ Irvr-A"'-¡.r,i"¡'¡i ~ .., r '.! ,0 ~! ~ Io.V,,", . ¡ --" " 133' SNL, 500' WEL, SEC. 06, T11N, R14E, UM ~ ',-,I :'.;:';'¡~, t,., , VEftlf~'1:i)~ At top of productive interval * Q, ~ ~. o,.j ! ~.."" I ,~ 2802' NSL 1816' EWL SEC. 32 T12N R14E UM ~..41":""~" '1 ~,",,~t~ . 2~¿i?~~~~~t~69' EWL: SEC. 32: T12N: R14E: UM L:¿fJ i~A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 60.7' ADL 028299 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/24/2002 8/26/2002 8/28/2002 17. Total Depth (MO+TVO) 18. Plug Back Depth (MO+TVO) 19. Directional Survey 11776 9050 FT 11740 9052 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, Memory CNL, CCL Classification of Service Well 7. Permit Number 202-095 8. API Number 50- 029-20452-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number E-08A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2053' MO 1900' (Approx.) ~y'¿ '¿;nð 8~/'" TYb 77'" M-..d....J I' 7" 3.1/2' X 3-3/16" x 2-7/8" WT. PER FT. Insulated 72# 47# 29# 8,81# /6.2# 6.16# GRADE Conductor L-80 L-80 L-80 L-80 CASING! LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 36" 11.8 cu Vds Arcticset Surface 2674' 17-1/2" 3255 cu ft Arcticset " Surface 9525' 12-1/4" 1380 cu ft Class 'G', 130 cu ft AS I 9002' 9942' 8-1/2" 331 cu ft Class 'G' 8986' 11776' 3-3/4" 112 cu ft Class 'G' AMOUNT PULLED 2,~, CASING SIZE 20" X 30" 13-3/8" 9-5/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 10550' - 10900' 9044' - 9047' 10935' - 11090' 9048' - 9051' 11125' - 11200' 9050' - 9046' 11245' - 11425' 9045' - 9046' 11475' - 11520' 9048' - 9049' 11550' - 11610' 9051' - 9054' 25. TUBING RECORD SIZE DEPTH SET (MD) 7",26#, L-80 8937' 4-1/2", 12.6#, L-80 8937' - 9043' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with MeOH PACKER SET (MD) 8934' MD TVD 27. Date First Production September 17, 2002 Date of Test Hours Tested 9/21/2002 4 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 5,985 OIL-BBL GAs-McF 16,311 GAs-McF WATER-BBL 74 WATER-BBL CHOKE SIZE 62° GAS-OIL RATIO 2,725 CALCULATED 24-HoUR RATE OIL GRAVITY-API (CORR) 25.6 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit corRltt II VEO No core samples were taken. 28. OCT 0 j 2002 RBDMS BFl OCT 8 2002 Alaska 011 & Ga. Coni. Commi81iolì Anohorage G I~ Submit In Duplicate Form 10-407 Rev. 07-01-80 ( ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 18 10210' 9030' RECEIVED OCT 0 3 2002 Alaska on & Bal Cons. Commission Anohorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed Terrie Hubble ~~ ~..6ð& Title Technical Assistant Date 10. 09- 'O"d.-. E-08A 202-095 Prepared By Name/Number: Terrie Hubble, 564~4628 Well Number Permit No. / Approval No. Drilling Engineer: Mary Endacott, 564-4388 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, 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 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-08 E-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/22/2002 Rig Release: 8/28/2002 Rig Number: N1 Spud Date: 4/14/1980 End: Date From - To . Hours Task Code NPT Phase Description of Operations 8/21/2002 11 :00 - 12:00 1.00 MOB P PRE Rig Released from 12-14AL 1 @ 11: 00 8/21/2002. Load out trucks & pull rig off well. 12:00 - 12:30 0.50 MOB P PRE Pull rig to edge of pad. Conduct post-operations pad inspection. 12:30 - 13:00 0.50 MOB P PRE Held pre-move safety meeting. 13:00 - 14:30 1.50 MOB P PRE Move rig from DS# 12-14 to central checkpoint station. 14:30 - 18:30 4.00 MOB N WAIT PRE W. O. toolpusher changeout & security. 18:30 - 19:00 0.50 MOB P PRE Held pre-move safety meeting. 19:00 - 20:30 1.50 MOB P PRE Move rig from central checkpoint station to DS# 6. 20:30 - 00:00 3.50 MOB P PRE PJSM. R/U & LID windwalls. RJU tilt cylinders. Scope down derrick. Meanwhile move camp to E-08. 8/22/2002 00:00 - 00:30 0.50 MOB P PRE Held pre-move safety meeting with Security, tool service, CPS & all personnel. 00:30 - 08:00 7.50 MOB P PRE Move rig from DS# 6 to E-08. 08:00 - 08: 15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for raising derrick and windwalls. 08:15 - 11 :00 2.75 MOB P PRE Raise derrick with no problems. Raise windwalls. 11 :00 - 12:30 1.50 MOB P PRE Secure guy wires. Secure tilt rams in storage frame. 12:30 - 14:00 1.50 MOB P PRE Pick up injecter head, M/U guide arch and stab CT into injecter head. 14:00 - 14:15 0.25 MOB P PRE SAFETY MEETING. Review rig back over well procedure, hazards and mitigation. 14:15 -15:00 0.75 MOB P PRE Back rig over well. WHP, lAP, OAP and flowline pressure = 0 PSI. 15:00 - 18:00 3.00 BOPSUR P DECOMP ACCEPT RIG AT 15:00 HRS, 8-22-02 ON E-08A. N/U BOPE. Spot trailers and tanks. 18:00 - 00:00 6.00 BOPSUR P DECOMP Perform initial BOPE press I function test. AOGCC test witness waived by John Spaulding. Meanwhile fill rig pits with 2% KCL bio-water. Finish BOP test with the exception of the inner reel valve. 8/23/2002 00:00 - 01:15 1.25 STWHIP P WEXIT P/U injector & changeout packoff. Cut coil, install Baker CTC, Pull test to 35klbs. 01 :15 - 02:30 1.25 STWHIP P WEXIT Circulate to fill coil. PT CTC to 3500 psi. PT inner reel valve to 3500 psi. 02:30 - 02:45 0.25 STWHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan I hazards & BHA M/U procedures. 02:45 - 04:00 1.25 STWHIP P WEXIT M/U window milling BHA # 1 with Baker straight motor, string reamer & HCC DSM. PJTest MHA to 3500 psi. Stab injector on well. 04:00 - 05:40 1.67 STWHIP P WEXIT RIH with BHA #1. Wt check @ 8950' = 38klbs. Continue RIH BHA#1 to XN nipple tagged @ 9022'. P/U & retag @ same depth. Correct depth to the XN ELM of 8998'. Establish freespin @ 1570psi. 05:40 - 06: 15 0.58 STWHIP P WEXIT Ease into milling from 8997' & mill thru the XN @ 2.5bpm, 1650psi. Make few passes with & without pumping to ensure there are no restrictions/overpulls. 06: 15 - 06:30 0.25 STWHIP P WEXIT Continue RIH BHA #1. Tag cement bridge at 9805 ft. Ream in hole and found cement at 9828 ft. 06:30 - 08:50 2.33 STWHIP P WEXIT Mill hard cement at 2.9 bpm, 2350 psi, 50 FPH, 6K WOB, Mill cement with 2# Biozan system. Milled to 9915 ft. 08:50 - 09:15 0.42 STWHIP P WEXIT Back ream up to 9800 ft. Clean hole. Ream back to bottom. 09:15 -10:00 0.75 STWHIP P WEXIT Mill firm cement to 9938' at 36 fph. Stall motor at 9938'. Pick Printed: 9/4/2002 11 :00:00 AM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-08 E-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/22/2002 Rig Release: 8/28/2002 Rig Number: N1 Spud Date: 4/14/1980 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/23/2002 09:15 - 10:00 0.75 STWHIP P WEXIT up, Bit stuck on bottom, Work pipe, Pull to 70K, motor still stalled, circ 2.2 bpm at 2630 psi, pull to 75K, still stuck. 10:00 - 10:45 0.75 STWHIP N STUC WEXIT Stuck pipe, circ with stalled motor at 2.1 bpm, Work pipe up to 80K, Bit stuck on Whipstock. Circ. 24 bbl high visc sweep with 6% lubtex to bit at 2.9 bpm at 3400 psi. Full returns. Still getting cement cuttings over shaker. Circ. 20 bbl pill out bit and pull free at 81 K. Circulated a total of 120 bbls clean 2# Biozan water thru stalled motor while bit stuck. 10:45 - 11 :30 0.75 STWHIP P WEXIT Back ream up to 9750 ft at 2.7 bpm, 1720 psi. Hole clean. Ream in hole, 42K up wt, 21 K dwn wt. Clean hole. RIH at 1 fpm and tag bottom at 9947 ft. Correct to 9942 ft. Flag CT at 9942'. 11 :30 - 13:00 1.50 STWHIP P WEXIT Mill 3.80" window out 7", 29# liner, starting at 9942 ft. 2.7 bpm, 1720-2100 psi, 1-2K WOB, Fast milling, 4 FPH for first 4 ft. Flag at 9942' is most likely at top of whipstock, not at pinch point. Milled to 9947 ft. 13:00 - 14:50 1.83 STWHIP P WEXIT Milling window, 2.7 I 2.7 bpm, 1720 - 2100 psi, 1-2K WOB, Normal milling now of 1 FPH. Milled to 9948 ft. 14:50 - 16:00 1.17 STWHIP P WEXIT Milling window, 2.7 I 2.7 bpm, 1720 - 2100 psi, 2-3K WOB, Stalled at 9949'. Good stall pressure. Milled to 9949 ft. 16:00 - 17:00 1.00 STWHIP P WEXIT Milling window, 2.7 I 2.7 bpm, 1720 - 2100 psi, 2-3K WOB, Milled to 9950 ft. 17:00 - 17:30 0.50 STWHIP P WEXIT Milling window, 2.7 I 2.7 bpm, 1720 - 2100 psi, 2-3K WOB, Milled to 9951 ft. 17:30 -18:15 0.75 STWHIP P WEXIT Milling window, 2.6/2.6 bpm, 1600 - 2000 psi, 4-6K WOB, Milled to 9953 ft. Top of window at 9946 ft. Bottom of window at 9953 ft. Pinch pt should be 4' below TOWS & final breakout @ 7' from pinch pt. 18:15 -18:40 0.42 STWHIP P WEXIT Milling formation, 2.6 I 2.6 bpm, 1600 - 2000 psi, 4-6K WOB. Stalled @ 9953'. Seems like string mill is exiting the window. 18:40 - 18:55 0.25 STWHIP P WEXIT Backream clean to 9935'. Ream down & tag up @ 9953'. Freespin @ 2.7bpm = 1700psi. 18:55 - 19:25 0.50 STWHIP P WEXIT Mill formation @ 2.7/2.7bpm, 1700/2200psi, 2k WOB. Mill to 9954'. 19:25 - 20:00 0.58 STWHIP P WEXIT Backream clean to 9935'. Ream down to btm. Stall @ 9954'. Backream/ream window. 20:00 - 21:10 1.17 STWHIP P WEXIT Continue milling very slowly with occasional take-ofts. Finally stall @ 9955'. Could be grinding on metal pieces @ btm. Backream/ream window. Stall twice @ 9956'. Mill ahead to 9957'. 21 :10 - 22:30 1.33 STWHIP P WEXIT Continue milling formation @ 2.7/2.7bpm, 1700/2200psi, 3-5k WOB. Start pumping new 8.6ppg, 6# kla-gard, 2% lubex flo-pro mud downhole. Mill formation with couple of stalls to 9964'. 22:30 - 23:00 0.50 STWHIP P WEXIT Dressldrift window & make several backream passes with & without pumping. Window looks clean. 23:00 - 23:30 0.50 STWHIP P WEXIT PUH slowly & backream to cmt tag-depth (9828'). 10k O/pull @ 9890'. RBIH to 9964' & POOH clean thru window to 9800'- liner looks clean. 23:30 - 00:00 0.50 STWHIP P WEXIT Continue POOH window milling BHA#1 to 7800'. 8/24/2002 00:00 - 01:10 1.17 STWHIP P WEXIT Continue POOH window milling BHA#1 to surface. Printed: 9/4/2002 11 :00:00 AM ( Legal Well Name: E-08 Common Well Name: E-08 Spud Date: 4/14/1980 Event Name: REENTER+COMPLETE Start: 8/22/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2002 Rig Name: NORDIC 1 Rig Number: N1 Date From- To Hours Task Code NPT Phase Descri ption of. Operations 8/24/2002 01:10 - 01:45 0.58 STWHIP P WEXIT Layout & inspect milling BHA#1. Formation mill gauge 3.79" & string reamer gauge 3.80". Wear on mill face indicates center crossed the casing wall. 01:45 - 03:00 1.25 DRILL P PROD1 PJSM. Rehead & M/U DS CTC. Pull/Press test. M/U build section BHA #2 with 2 deg bend motor, MWD & re-run Bit #2 [HYC DS49]. M/U injector. 03:00 - 05:10 2.17 DRILL P PROD1 RIH with BHA #2. SHT MWD & orienter @ 450' - OK. Continue RIH to 9900'. Wt check: Up wt = 40k, Dwn wt = 23k. Run thru window with pumps down & tag btm @ 9981'. Correct depth to 9964'. Check TF - @ 45R. 05:10 - 05:30 0.33 DRILL P PROD1 Orient around to HS TF. 05:30 - 06:45 1.25 DRILL P PROD1 Begin drilling build section with HS TF, 2.7/2.7bpm, 2800/3100psi & 50fph ave ROP. Drill to 9996' with occasional motor stalling. 06:45 - 08: 15 1.50 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 2750 - 3100 psi, TF = 23R, 50 FPH, 1500 WOB, Drilled to 10,050 ft. 08:15 - 08:30 0.25 DRILL P PROD1 Wiper trip to window. Clean hole. Pull up to 9770' for tie-in log. 08:30 - 09:00 0.50 DRILL P PROD1 Log GR and tie-in with BHCS/GR of 4-27-80 at 9725 ft. Subtract 4 ft CTD. Corrected window depths are top at 9942 ft. Bottom of window at 9949 ft. 09:00 - 09:10 0.17 DRILL P PROD1 RIH thru window clean. RIH to TD clean. 09:10 - 09:30 0.33 DRILL P PROD1 Orient TF to 30L. 09:30 - 11 :00 1.50 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 2650 - 3100 psi, TF = 30L, 110 FPH, 2500 WOB, Incl = 75 deg. Drilled to 10,180 ft. 11 :00 - 13:00 2.00 DRILL P PROD1 POH for lateral BHA. 13:00 - 13:45 0.75 DRILL P PROD1 At surface, CIO MWD tools, motor and bit. M/U Bit #3, used HYC DS49. M/U 1.04 deg bent motor. 13:45 - 15:45 2.00 DRILL P PROD1 RIH with Lateral MWD BHA #3 with 1.04 deg motor and used DS49 Bit #3. Ran thru window with no wt loss. RIH to TD. 15:45 - 15:50 0.08 DRILL P PROD1 Tag TD at 10,207 ft. Correct depth to 10,180 ft. 15:50 - 16:30 0.67 DRILL P PROD1 Orient TF to 90L. 16:30 - 16:45 0.25 DRILL P PROD1 Drilling lateral, 2.8 I 2.8 bpm, 2850 - 3400 psi, TF = 90l, 110 FPH, 2500 WOB, Drilled to 10,220' 16:45 - 17:10 0.42 DRILL P PROD1 Orient TF to 60R. 17:10 - 18:20 1.17 DRILL P PROD1 Drilling lateral, 2.6 I 2.6 bpm, 2800 - 3400 psi, TF = 60R-80R, 110 FPH, 2500 WOB, Drilled to 10,300 ft. 18:20 - 19:00 0.67 DRILL P PROD1 Orient & drill to 10350' with 85-95R TF, 2.7/2.7bpm, 2800/3200psi, 82fph ave ROP & 3k WOB. Aiming to land @ 8982ftvd. 19:00 - 19:25 0.42 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 19:25 - 19:45 0.33 DRILL P PROD1 Orient TF to 70-80R. 19:45 - 20:00 0.25 DRILL P PROD1 Drill to 10393' with 70-80R TF, 2.7/2.7bpm, 2800/3400psi, 172fph ave ROP. Drill thru (14N) shale from 10365'-10390' (8980-8982ftvd). 20:00 - 20: 10 0.17 DRILL P PROD1 Drill to 10404' with80R TF, 2.7/2.7bpm, 2800/3200psi, 82fph ave ROP. TF rolled over to 100R. 20: 1 0 - 20:25 0.25 DRILL P PROD1 Orient TF to HS. 20:25 - 20:40 0.25 DRILL P PROD1 Drill to 10415' with 45R TF, 2.7/2.7bpm, 2800/3350psi, 44fph Printed: 9/4/2002 11: 00: 00 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-08 E-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/22/2002 Rig Release: 8/28/2002 Rig Number: N 1 Spud Date: 4/14/1980 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/24/2002 20:25 - 20:40 0.25 DRILL P PROD1 ave ROP. Wt stacking. 20:40 - 21:15 0.58 DRILL PROD1 Drill to 10455' with 80R TF, 2.7/2.7bpm, 2800/3200psi, 68fph ave ROP. 21:15 - 21:30 0.25 DRILL P PROD1 Drill to 10465' with 100R TF, 2.7/2.7bpm, 2800/3200psi, 40fph ave ROP. Landed @ 10423' (8982ftvd). However with 14N shale deeper than expected, Geo decides to get back to 87 degs. 21 :30 - 22:00 0.50 DRILL P PROD1 Orient & drill to 10500' with 11 OR TF, 2.8/2.8bpm, 2800/3200psi& 84fph ave ROP. Still stacking wt. Mix & pump 30 bbls of 6% lubetex pill & wt transfer improved instantly. 22:00 - 22:30 0.50 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 22:30 - 22:45 0.25 DRILL P PROD1 Orient TF to 90L. 22:45 - 23:20 0.58 DRILL P PROD1 Drill to 10541' with 80-90L TF, 2.7/2.7bpm, 2850/3050psi, 65fph ave ROP. TF walking to the right. 23:20 - 00:00 0.67 DRILL P PROD1 Reorient to 90L & drill to 10560' with 90-100L TF, 2.7/2.7bpm, 2850/3050psi & 80fph ave ROP. 8/25/2002 00:00 - 00:20 0.33 DRILL P PROD1 Continue drilling to 10579' with 45-60L TF, 2.7/2.7bpm, 2850/3050psi & 65fph ave ROP. 00:20 - 00:25 0.08 DRILL P PROD1 Orient TF to 45R. 00:25 - 00:45 0.33 DRILL P PROD1 Drill to 10602' with 10R TF, 2.7/2.7bpm, 2850/3050psi, 60fph ave ROP. 00:45 - 01 :00 0.25 DRILL P PROD1 Orient 3 clicks & drill to 10608' with 45R TF, 2.6/2.6bpm, 2850/3050psi, 25fph ave ROP. 01:00 - 01:15 0.25 DRILL P PROD1 Orient 2 clicks & drill to 10619' with 80R TF, 2.7/2.7bpm, 2850/3150psi, 48fph ave ROP. 01 :15 - 01 :45 0.50 DRILL P PROD1 Orient & drill to 10650' with 90R TF, 2.7/2.7bpm, 2850/3200psi, 60fph ave ROP. Observe intermittent (on/off) MWD pulsing with no obvious pressure loss. 01 :45 - 02:00 0.25 DRILL P PROD1 Wiper clean to window. Attempt to log GR tie-in"" MWD quit pulsing. Decide to POOH for MWD. 02:00 - 03:45 1.75 DRILL N DFAL PROD1 POOH drilling BHA#3. MWD pulses bounce back from 5000'. 03:45 - 04:45 1.00 DRILL N DFAL PROD1 OOH. PJSM. B/O BHA & test NRT & CT to 3k.... OK. M/U TIW valve on BHA & test MWD + MHA to 2.5k .... no leaks. Decide to swap out MWD & motor. Check bit.... OK, will rerun. UD BHA#3. 04:45 - 05:30 0.75 DRILL N DFAL PROD1 PJSM. M/U drilling BHA #4 with new 1.04 deg bend motor, new MWD & re-run Bit #4 [HYC 0549]. M/U injector. 05:30 - 07:25 1.92 DRILL N DFAL PROD1 RIH with BHA #4. SHT MWD & orienter @ 500' & 4000' .... OK. Continue RIH. 07:25 - 08:00 0.58 EVAL N DFAL PROD1 Log Tie-in with GR to BHCS/GR. [ -26 ft CTD correction.] Note: LOG no longer an activity pick in DIMS. 08:00 - 08:20 0.33 DRILL N DFAL PROD1 RIH to TO. Clean hole. Tagged TD at 10,654 ft. 40K up wt. 20K dwn wt. 08:20 - 08:30 0.17 DRILL N DFAL PROD1 Orient TF. 08:30 - 09:30 1.00 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 2900 - 3400 psi, TF = 120R, Incl = 90 deg. Drilled to 10,710'. 09:30 - 09:45 0.25 DRILL P PROD1 Orient TF. 09:45 - 10:15 0.50 DRILL P PROD1 Drilling, 2.7/2.7 bpm, 2900 - 3400 psi, TF = 100R, Inel = 91 deg. Drilled to 10,810'. 10:15-11:10 0.92 DRILL P PROD1 Wiper trip to window. Clean hole. RIH to TO. Clean hole. Note: WIPER no longer an activity pick in DIMS. 11:10 -12:45 1.58 DRILL P PROD1 Drilling, 2.7/2.7 bpm, 2900 - 3400 psi, TF = 100R, Incl = 89 deg. Drilled to 10,960' Printed: 9/4/2002 11 :00:00 AM ( ( BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-08 E-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/22/2002 Rig Release: 8/28/2002 Rig Number: N1 Spud Date: 4/14/1980 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/25/2002 12:45 - 13:20 0.58 DRILL P PROD1 Wiper trip to window. Clean hole. RIH to TO. Clean hole. Note: WIPER no longer an activity pick in DIMS. 13:20 - 15:20 2.00 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 3000 - 3500 psi, TF = 100R, Incl = 89 deg. Drilled to 11,110'. 15:20 - 16:30 1.17 DRILL P PROD1 Wiper trip to window. Clean hole. RIH to TO. Clean hole. Note: WIPER no longer an activity pick in DIMS. 16:30 - 18:30 2.00 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 3100 - 3500 psi, TF = 110R, Incl = 92 deg. Drilled to 11,243' Stacking WT. 18:30 - 19:20 0.83 DRILL P PROD1 Wiper trip to window. Clean hole. PUH to 9730' for GR tie-in. Note: WIPER no longer an activity pick in DIMS. 19:20 - 19:50 0.50 DRILL P PROD1 Log Tie-in with GR to BHCS/GR. [ +1 ft CTD correction.] 19:50 - 20:15 0.42 DRILL P PROD1 RBIH clean to TO. 20:15 - 20:30 0.25 DRILL P PROD1 Orient TF to 80R. 20:30 - 22:00 1.50 DRILL P PROD1 Drill to 11406' with 80-1 OOR TF, 2.7/2.7bpm, 3050/3450psi, 120fph ave ROP. Geologist wants to get to 91 degs. Meanwhile start pumping new 8.6ppg, 6# kla-gard, 2.5% lubex flo-pro mud downhole. 22:00 - 23:25 1.42 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 23:25 - 23:35 0.17 DRILL P PROD1 Orient TF to 80L. 23:35 - 23:50 0.25 DRILL P PROD1 Drill to 11435' with 75L TF, 2.8/2.8bpm, 3100/3500psi, 110fph ave ROP. Dropping angle @ 75L TF. Have new mud all round. 23:50 - 00:00 0.17 DRILL P PROD1 Orient 2 clicks & drill to 11447' with 35L TF, 2.8/2.8bpm, 3050/3550psi, 80fph ave ROP. 8/26/2002 00:00 - 00:30 0.50 DRILL P PROD1 Orient & drill to 11504' with 35L TF, 2.8/2.8bpm, 3050/3550psi, 130fph ave ROP. 00:30 - 00:45 0.25 DRILL P PROD1 Orient TF to 75L. 00:45 - 00:55 0.17 DRILL P PROD1 Drill to 11509' with 100L TF, 2.8/2.8bpm, 3050/3600psi, 100fph ave ROP. 00:55 - 01 :05 0.17 DRILL P PROD1 Orient 1 click & drill to 11525' with 80L TF, 2.8/2.8bpm, 3050/3600psi, 100fph ave ROP. Observe inclination drop from the 35L drilling. 01 :05 - 01 :10 0.08 DRILL P PROD1 Orient 2 clicks & drill to 11539' with 60L TF, 2.8/2.8bpm, 3050/3600psi, 85fph ave ROP. 01 :10 - 01 :20 0.17 DRILL P PROD1 Orient & drill to 11550' with 60L TF, 2.8/2.8bpm, 3050/3550psi, 65fph ave ROP. Drilling very soft formation. 01 :20 - 02:55 1.58 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 02:55 - 03:05 0.17 DRILL P PROD1 Orient TF to HS to build back angle. 03:05 - 03:15 0.17 DRILL P PROD1 Drill to 11575' with 1 OL TF, 2.8/2.8bpm, 3050/3500psi, 95fph ave ROP. 03:15 - 03:50 0.58 DRILL P PROD1 Drill to 11620' with 1 OL TF, 2.8/2.8bpm, 3050/3500psi, 85fph ave ROP. Getting 180 degs reactive. 03:50 - 04: 10 0.33 DRILL P PROD1 Reorient TF to HS. 04: 1 0 - 04:30 0.33 DRILL P PROD1 Drill to 11620' with 1 OR TF, 2.8/2.8bpm, 3000/3450psi, 50fph ave ROP. 04:30 - 04:50 0.33 DRILL P PROD1 Orient & drill to 11650' with 30R TF, 2.8/2.8bpm, 3100/3500psi, 100fph ave ROP. 04:50 - 06:30 1.67 DRILL P PROD1 Wiper trip Clean to window to enable Geo get btms up samples. RBIH & set down in shale @ 11460'. P/U & work thru. Continue RIH to btm. 06:30 - 07:30 1.00 DRILL P PROQ1 Drilling, 2.7/2.7 bpm, 3000 - 3700 psi, TF = 35R, 92 deg inct. Drilled to 11,765 ft. 07:30 - 07:50 0.33 DRILL P PROD1 Orient TF. Printed: 9/4/2002 11 :00:00 AM (' Legal Well Name: E-08 Common Well Name: E-08 Spud Date: 4/14/1980 Event Name: REENTER+COMPLETE Start: 8/22/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2002 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 8/26/2002 07:50 - 08:00 0.17 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 3000 - 3700 psi, TF = 35R, 92 deg inct. Drilled to 11,770 ft. Anchorage geology called TD at 11,770 ft. 08:00 - 09:00 1.00 DRILL P PROD1 Backream to window. Overpull to 65 Kat 11480 ft. Ream shales from 11550-11450' at 10 FPM. Ream up to window. Clean hole above 11,450 ft. 09:00 - 09:30 0.50 EVAL P PROD1 Log tie-in with BHCS/GR. Added 10ft to CTD. 09:30 - 11 :00 1.50 DRILL P PROD1 RIH to TD. Reamed shales from 11400 - 11550 ft. RIH and tagged Final TD at 11,776 ft BKB. 11 :00 - 12: 15 1.25 DRILL P PROD1 Reamed shales from 11550-11350 ft. RI H and tagged TD again. Back ream shales, clean, up to 11,350 ft. Back ream clean up to window. 12:15 -14:15 2.00 DRILL P PROD1 POH to run Liner. Flag CT at 8900 ft EOP and 7100' EOP. 14:15 -14:45 0.50 DRILL P PROD1 Layout drilling MWD BHA. Bit = 3,1, I 14:45 -15:15 0.50 CASE P COMP Prepare rig floor to run Liner. 15:15 - 15:30 0.25 CASE P COMP SAFETY MEETING: Review procedure and hazards for running liner. 15:30 - 18:00 2.50 CASE P COMP M/U 2-7/8" float equipment on Jt #1. Run 2-7/8", 6.16#, L-80 STL Liner. XO and 4 jts of 3-3/16", TC II liner. 18:00 - 18:30 0.50 CASE P COMP Crew change and Safety Meeting prior to running liner. Fill liner while doing crew change and safety meeting. 18:30 - 19:45 1.25 CASE P COMP M/U 29 jts of 3-1/2", 8.81#, L-80, STL Liner. 19:45 - 21 :00 1.25 CASE P COMP M/U Baker CTLRT. M/U Baker CTC. Pull test to 35k & Pltest to 3500 psi - OK. 21 :00 - 21 :50 0.83 CASE P COMP Load wiper dart, launch & check. Chase dart with mud & pig CT. Dart bumped on catcher @ 55.5bbls. 21 :50 - 23:45 1.92 CASE P COMP RIH with liner on CT. See flag @ 9920'. Correct to 9899'. Check up wt - 47.3k, down wt - 27k. RIH smoothly @ 50 fpm thru window. See 2nd flag right on depth. Tag TD @ 11776' CTD. P/U @ 48.5k. RBIH @ 20k & retag TD @ same depth. 23:45 - 00:00 0.25 CASE P COMP Load 5/8" steel ball & circ with mud @ 2.5/2.5bpm, 2500psi. Set down 10k Ibs down on CTLRT. 8/27/2002 00:00 - 00:30 0.50 CASE P COMP Continue circ to seat. Slow down @ 35 bbls away. Ball on seat @ 45.3bbls. Pressure up to 2700psi & release CTLRT. P/U @ 32k & confirm release. 00:30 - 03:30 3.00 CASE P COMP Displace well to 2% KCI at 3.0/2.9bpm & 2000psi. Meanwhile R/U Dowell cementers. R/U extra hard line for pumping cement thru HP filters. P/test hardline - OK. Ship back used mud to MI. 03:30 - 03:45 0.25 CEMT P COMP PJSM with all personnel concerning cementing operations. 03:45 - 05:40 1.92 CEMT P COMP Batch mix 20bbls 15.8ppg cmt with additives. Cmt to wt @ 04:10 hrs. Flush/PT lines to 4k. Pump 20bbls cmt slurry @ 2.6/2.5bpm & 2200psi. Close inner reel valve & clean lines. Load/launch CTWP & confirm launch. Chase with KCL @ 3.3/2.9bpm & 1380psi. CTWP engage LWP at 55.9bbls away. Shear plug with 3100psi. Continue displacing LWP @ 2.1/2.0 bpm, 1400 psi & bump @ 72.4bbls away. 18bbls cmt pumped around shoe. Floats held. Pressure up to 1000 psi & sting out of liner. CIP at 05:40 hrs 05:40 - 06:00 0.33 CEMT P COMP Displace 30 bbls flopro to TOL. Jet TOL. 06:00 - 08:15 2.25 CEMT P COMP POH CTLRT. 08: 15 - 08:45 0.50 CEMT P COMP LJO BKR CTLRT, hyd disc, circ sub and swivet. 08:45 - 09:00 0.25 CEMT P COMP SAFETY MEETING. Review procedure, hazards and Printed: 9/4/2002 11 :00:00 AM ( BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-08 E-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/22/2002 Rig Release: 8/28/2002 Rig Number: N1 Spud Date: 4/14/1980 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/27/2002 08:45 - 09:00 0.25 CEMT P COMP mitigation for M/U SWS CNLJGR, motor and CSH workstring. 09:00 - 12:00 3.00 CEMT P COMP M/U 2.30" Parabolic used Diamond mill, 2-1/8" motor, SWS CNLJGR Carrier, Circ Sub, Hyd Disc, XO, 92 jts CSH, XO, Hyd Disc, Chk vlv, Locking Swivel, XO and CTC. BHA total length = 2909 ft. 12:00 - 13:00 1.00 EVAL P COMP RIH with CNLJGR and motorlmill BHA. Note: RIH not an Activity in DIMS now. 13:00 - 15:00 2.00 EVAL P COMP Stop at 8800 ft and start logging down at 30 FPM, circ at 1.3 bpm at 1400 psi. Note: Log is not an Activity in DIMS now. Stage 20 bbl high vis FloPro perf pill while logging down. Clean trip to PBTD. No motor work. Tag PBTD at 11,749' CTD, uncorrected. Corrected PBTD is 11,737 ft. 15:00 - 16:40 1.67 EVAL P COMP Log up at 30 FPM with CNLJGR. Lay in high vis FloPro at 0.4 BPM. Log up to 8800 ft. Log not an activity in DIMS. 16:40 - 17:50 1 .17 EV AL P COMP POH with CNL I GR, motor and mill. 17:50 - 18:05 0.25 EVAL P COMP Tag up at surface. Standby for crewchange. 18:05 - 18:25 0.33 EVAL P COMP Safety meeting prior to standing back CSH work string. 18:25 - 20:30 2.08 EVAL P COMP Break off injector, MHA, Stand back CSH workstring. 20:30 - 20:45 0.25 EVAL P COMP PJSM prior to laying down last 2joints and MCNL. Insure cellar and floor are clear while removing RA source in MCNL tool. 20:45 - 21:10 0.42 EVAL P COMP LD MCNL, motor and mill. 21 :10 - 22:00 0.83 EVAL P COMP While waiting for MCNL results....Pressure test liner lap to 2000psi. Bled off slowly, check surface valves, Double block surface valves and re test. Liner lap failed pressure test, lost 445 psi in 30min. Call Baker TT to discuss running a liner top packer. 22:00 - 22:10 0.17 EVAL P COMP Fax MCNL to J. Williams to confirm perf depths. Run with the original perf picks. 22:10 - 22:25 0.25 PERF P COMP PJSM prior to running perf guns in hole. Don't forget to take the time to insure the 5/8" ball drifts all BHA components, place perf signs visibly in cellar, emphasize good communication while picking up guns. Insure we have a safety joint ready prior to PU guns. 22:25 - 00:00 1.58 PERF P COMP MU Emergency joint, PU 51 guns+blanks, 60joints of CSH work string. 8/28/2002 00:00 - 01 :30 1.50 PERF P COMP PU Perf guns 01 :30 - 04:40 3.17 PERF P COMP RIH with perf guns on CSH workstring, with intervals as per proceedure. 04:40 - 05:35 0.92 PERF P COMP Tag PBTD, PU to string wt and correct depth to PBTD =11739. PU to place bottom interval at 11,610'. With guns on depth, pump 9bbls of new flo-pro into reel, launch ball, circulate @ 2.5bpm 3230psi. Slow pump rate to 0.5bpm with 1 Obbls to go before ball on seat. See positive indication of guns firing (CT pressure built up to 2900psi and an abrubt drop off of pressure) 05:35 - 07:15 1.67 PERF P COMP POH at 35-49fpm inside liner, O.4bpm. POH @ 71fpm inside 7" liner, 0.7bpm. Lost 2 bbls of KCL on trip OOH. 07:15 - 07:35 0.33 PERF P COMP Tag up at surface with coil. PJSM prior to standing back injector and tripping CSH OOH. Printed: 9/4/2002 11:00:00 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-08 E-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/22/2002 Rig Release: 8/28/2002 Rig Number: N 1 Spud Date: 4/14/1980 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/28/2002 07:35 - 09:05 1.50 PERF P COMP Stand back injector. Stand back CSH work string. 09:05 - 09:25 0.33 PERF P COMP Safety meeting prior to standing back perf guns. Discuss kick proceedure, handling safety, possible trapped pressure. 09:25 - 12:40 3.25 PERF P COMP Lay down perf guns. All guns fired, all shots fired. 12:40 - 13:30 0.83 PERF P COMP Waiting on Schlumberger. 13:30 - 14:20 0.83 RUNCOIVP COMP PU Baker liner top packer eq. 14:20 - 16:05 1.75 RUNCOIVP COMP RIH with Baker liner top packer BHA. 16:05 -17:15 1.17 RUNCOIVP COMP Weight check at 8900'=34,500 Ibs. RIH. Stab into liner top. Confirm by returns going to 0 bpm while pumping 0.3 bpm. CTP increased when stabbing in from 36 psi at 0.3 bpm to 600 psi. PU 2' to setting depth, 8983' (2' above tag up, Stinger still in liner 4'). Check OA and IA prior to PT down the backside. OA=O, IA=O. Bring WHP up to 2200 psi. After 15 minutes, WHP lost 100 psi, after second 15 minutes it lost an additional 16 psi, OA and IA both held at 0 psi. Liner appears to be holding within tolerance. Bleed off pressure. Consult with town. Decide not to set liner top packer. 17:15 -17:45 0.50 RUNCOIVP COMP POOH with liner top packer. Consult with town again. Decide to set liner top packer. RIH. 17:45 -19:15 1.50 RUNCOIVP COMP Position reel for ball drop. Drop 5/8" ball to set packer. Chase with KCL at 2 bpm. Pump 38 bbls, SD pumps and try to set back down into liner top. Not getting into liner. Not able to get back to flag painted previously. Try pumping down the backside, CT press & WHP track, set dwon 1 OK on liner, no go. Work it a few more times, bleed WHP and work L TP into liner top. Position L TP, pressure up on CT to 2480 and set liner top packer. Pull up, overpull indicates the L TP is set. Set 10k down, bleed CT pressure, pressure test backside to 2200psi. Good test, lost 65psi over 15min. 19:15 - 20:45 1.50 RUNCOIVP COMP POOH with Liner top packer setting tool. Freeze protect with 50/50 MeOH from 2200'. 20:45 - 21 :15 0.50 RUNCOIVP COMP Stand bak injector, LD L TP running tools. 21 :15 - 23:15 2.00 RIGD P COMP Start rigging down. Wash pits. ND, PT the tree. 23:15 - 23:30 0.25 RIGD P COMP PJSM on rig move. Discuss need for good radio contact, anyone can halt the move at any time. 23:30 - 00:00 0.50 RIGD P COMP RD. Release rig at midnight. Printed: 9/4/2002 11 :00: 00 AM t ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well E-08A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,900.00' MD Window / Kickoff Survey 9,953.18 I MD (if applicable) Projected Survey: 11,776.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) aD)~D-~S 02-0ct-02 OCT 0 ~~ 'f ~i, Sperry-Sun Drilling Services North Slope Alaska BPXA PBU- WOA E Pad E-OBA Job No. AKMW22142, Surveyed: 26 August, 2002 Survey Report 30 September, 2002 Your Ref: API 500292045201 Surface Coordinates: 5976930.00 N, 664444.00 E (70020' 35.7881" N, 148039' 55.0221" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ,~^ Surface Coordinates relative to Project H Reference: 976930.00 N, 164444.00 E (Grid) Surface Coordinates relative to Structure Reference: 3725.28 N, 1987.23 E(True) Kelly Bushing: 60. 70ft above Mean Sea Level Elevation relative to Project V Reference: 60.70ft Elevation relative to Structure Reference: 60.70ft sn"""'I'\-5UI1 fn~Ð~:CrN'G~'S'Ê,~,y.,~.çJæ s A Halliburton Company Survey Ref: svy11328 Sperry-Sun Drilling Services Survey Report for PBU- WOA E Pad - E-08A Your Ref: AP/500292045201 Job No. AKMW22142, Surveyed: 26 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 9900.00 24.520 46.400 8787.67 8848.37 2762.53 N 2163.30 E 5979739.32 N 666546.18 E 2729.29 Tie On Point MWD Magnetic 9938.00 24.530 45.070 8822.25 8882.95 2773.54 N 2174.59 E 5979750.57 N 666557.23 E 1 .453 2742.77 9953.18" 26.610 44.020 8835.94 8896.64 2778.21 N 2179.19E 5979755.34 N 666561.72 E 14.023 2748.30 Window Point .~ 9962.56 26.960 44.020 8844.31 8905.01 2781.25 N 2182.13 E 5979758.45 N 666564.59 E 3.731 2751.84 9990.49 34.270 45.000 8868.33 8929.03 2791.38 N 2192.10E 5979768.79 N 666574.34 E 26.233 2763.84 10025.63 42.730 45.500 8895.81 8956.51 2806.76 N 2207.63 E 5979784.51 N 666589.53 E 24.091 2782.43 10054.68 48.910 48.850 8916.05 8976.75 2820.88 N 2222.92 E 5979798.97 N 666604.50 E 22.819 2800.50 10086.04 57.180 43.080 8934.89 8995.59 2838.32 N 2240.86 E 5979816.80 N 666622.05 E 30.175 2821.91 10127.18 69.690 38.330 8953.26 9013.96 2866.21 N 2264.73 E 5979845.20 N 666645.31 E 32.102 2851.44 10159.74 79.130 32.450 8962.01 9022.71 2891.75 N 2282.84 E 5979871.14 N 666662.85 E 33.798 2874.83 10188.56 83.260 26.340 8966.43 9027.13 2916.55 N 2296.80 E 5979896.24 N 666676.27 E 25.379 2894.01 10217.04 81.500 26.870 8970.20 9030.90 2941.79 N 2309.44 E 5979921.75 N 666688.35 E 6.449 2912.01 10255.66 84.580 27.580 8974.88 9035.58 2975.88 N 2326.98 E 5979956.21 N 666705.14 E 8.181 2936.76 10283.29 87.140 32.510 8976.88 9037.58 2999.72 N 2340.77 E 5979980.35 N 666718.40 E 20.062 2955.57 10320.18 86.960 37.800 8978.78 9039.48 3029.83 N 2361.97 E 5980010.92 N 666738.94 E 14.329 2983.00 10362.83 87.490 42.730 8980.84 9041.54 3062.33 N 2389.50 E 5980044.01 N 666765.75 E 11.612 3017.13 10392.68 87.580 46.960 8982.13 9042.83 3083.47 N 2410.52 E 5980065.60 N 666786.30 E 14.161 3042.37 10448.86 91 .980 55.770 8982.34 9043.04 3118.50 N 2454.36 E 5980101.59 N 666829.36 E 17.525 3092.96 10478.41 90.310 58.770 8981.75 9042.45 3134.47 N 2479.21 E 5980118.10 N 666853.85 E 11.617 3120.77 10512.74 88.990 54.010 8981.96 9042.66 3153.47 N 2507.79 E 5980137.72 N 666882.01 E 14.388 3152.89 .~ 10547.83 86.510 51.640 8983.34 9044.04 3174.65 N 2535.72 E 5980159.51 N 666909.47 E 9.772 3184.87 10581.24 86.780 51.010 8985.30 9046.00 3195.49 N 2561.76 E 5980180.92 N 666935.05 E 2.049 3214.93 10616.49 90.030 49.330 8986.28 9046.98 3218.06 N 2588.81 E 5980204.07 N 666961.60 E 10.378 3246.37 10646.36 90.840 53.830 8986.05 9046.75 3236.62 N 2612.21 E 5980223.14 N 666984.58 E 15.307 3273.34 10697.71 91.630 55.420 8984.94 9045.64 3266.34 N 2654.07 E 5980253.77 N 667025.78 E 3.457 3320.81 10725.71 91.280 59.120 8984.23 9044.93 3281.47 N 2677.61 E 5980269.41 N 667048. 98 E 13.269 3347.15 10778.76 90.480 64.410 8983.42 9044.12 3306.55 N 2724.33 E 5980295.52 N 667095.14 E 10.084 3398.31 10820.39 89.250 68.990 8983.52 9044.22 3323.01 N 2762.55 E 5980312.81 N 667132.99 E 11 .391 3439.26 10857.67 87.490 70.930 8984.58 9045.28 3335.78 N 2797.56 E 5980326.35 N 667167.71 E 7.025 3476.24 10886.11 87.930 74.100 8985.71 9046.41 3344.32 N 2824.66 E 5980335.48 N 667194.61 E 11 .244 3504.57 30 September, 2002 - 16:23 Page 2 of4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_ WOA E Pad - E-OBA Your Ref: API 500292045201 Job No. AKMW22142, Surveyed: 26 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 10920.74 88.900 79.560 8986.67 9047.37 3352.20 N 2858.35 E 5980344.10 N 667228.13 E 16.007 3539.17 10958.34 87.930 82.030 8987.71 9048.41 3358.22 N 2895.45 E 5980350.92 N 667265.08 E 7.055 3576.67 10989.79 87.220 85.200 8989.04 9049.74 3361.71 N 2926.67 E 5980355.10 N 667296.22 E 10.320 3607.88 11028.35 89.780 87.670 8990.05 9050.75 3364.11 N 2965.14 E 5980358.34 N 667334.63 E 9.224 3645.90 11057.39 89.780 91.720 8990.16 9050.86 3364.26 N 2994.17 E 5980359.13 N 667363.65 E 13.946 3674.22 11090.09 90.840 94.190 8989.99 9050.69 3362.57 N 3026.82 E 5980358.16 N 667396.33 E 8.220 3705.66 11123.71 92.510 96.300 8989.00 9049.70 3359.50 N 3060.28 E 5980355.83 N 667429.85 E 8.002 3737.57 11153.09 92.690 100.530 8987.67 9048.37 3355.21 N 3089.31 E 5980352.17 N 667458.97 E 14.396 3764.89 11188.21 92.420 102.470 8986.10 9046.80 3348.21 N 3123.69 E 5980345.93 N 667493.49 E 5.572 3796.82 11217.61 91.280 105.460 8985.16 9045.86 3341.12 N 3152.20 E 5980339.47 N 667522.15 E 10.879 3823.00 11262.56 90.570 109.690 8984.43 9045.13 3327.56 N 3195.04 E 5980326.84 N 667565.28 E 9.541 3861.69 11296.06 90.310 113.570 8984.17 9044.87 3315.21 N 3226.17 E 5980315.18 N 667596.67 E 11 .608 3889.25 11326.28 89.960 116.740 8984.10 9044.80 3302.37 N 3253.52 E 5980302.94 N 667624.30 E 10.553 3913.01 11359.16 89.690 120.440 8984.20 9044.90 3286.63 N 3282.39 E 5980287.85 N 667653.50 E 11 .283 3937.59 11389.98 89.320 123.890 8984.47 9045.17 3270.23 N 3308.47 E 5980272.02 N 667679.94 E 11 .258 3959.32 11430.01 87.050 121.680 8985.74 9046.44 3248.57 N 3342.11 E 5980251.10 N 667714.04 E 7.912 3987.22 11481.68 89.160 118.500 8987.44 9048.14 3222.68 N 3386.78 E 5980226.20 N 667759.27 E 7.383 4024.92 11515.41 87.670 115.510 8988.38 9049.08 3207.37 N 3416.82 E 5980211.56 N 667789.64 E 9.901 4050.75 11548.38 86.340 111.980 8990.10 9050.80 3194.12 N 3446.95 E 5980198.96 N 667820.05 E 11 .428 4077.12 11593.56 87.930 109.520 8992.36 9053.06 3178.13 N 3489.14 E 5980183.91 N 667862.59 E 6.4 77 4114.64 11622.23 88.110 107.400 8993.35 9054.05 3169.06 N 3516.32 E 5980175.43 N 667889.96 E 7.417 4139.08 11664.88 90.570 109.160 8993.84 9054.54 3155.69N 3556.81 E 5980162.95 N 667930.73 E 7.092 4175.52 11697.18 92.950 109.160 8992.85 9053.55 3145.09 N 3587.30 E 5980153.03 N 667961.45 E 7.368 4202.85 11734.58 92.250 113.390 8991.15 9051.85 3131.54 N 3622.11 E 5980140.24 N 667996.54 E 11 .452 4233.72 11749.86 92.250 114.100 8990.55 9051.25 3125.39 N 3636.09 E 5980134.40 N 668010.65 E 4.643 4245.95 11776.00 92.250 114.100 8989.53 9050.23 3114.72 N 3659.93 E 5980124.26 N 668034.72 E 0.000 4266.79 Projected Survey All data is in Feet (US) 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 77.0000 (True). Magnetic Declination at Surface is 26.167°(24-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 11776.00ft., 30 September, 2002 - 16:23 Page 30f4 Dril/Quest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA E Pad - E-08A Your Ref: API 500292045201 Job No. AKMW22142, Surveyed: 26 August, 2002 BPXA North Slope Alaska The Bottom Hole Displacement is 4805.89ft., in the Direction of 49.6010 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9900.00 9953.18 11776.00 8848.37 8896.64 9050.23 2762.53 N 2778.21 N 3114.72 N 2163.30 E 2179.19E 3659.93 E Tie On Point Window Point Projected Survey Survey tool program for E-DBA Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (1t) (1t) Survey Tool Description 0.00 9900.00 0.00 9900.00 8848.37 11776.00 8848.37 AK-1 BP _HG - BP High Accuracy Gyro(E-08) 9050.23 MWD Magnetic(E-08A) 30 September, 2002 - 16:23 Page 40f4 DrillQuest 3.03.02.002 Permit update, Nordic 1 will be moving to E-08 this week (" Subject: Permit update, Nordic 1 will be moving to E-08 this week Date: Mon, 19 Aug 2002 17:00:18 -0500 From: "Endacott, Mary S" <EndacoMS@BP.com> To: "Winton G Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Hubble, TeITÍe L" <HubbleTL@BP.com> Winton E-08a was originally permitted to be drilled by Nabors 38 (Permit No. 202-095). Current plan is for Nordic 1 to drill the well, starting Thursday Aug 22nd. I have attached the BOP sketch for Nordic 1 to update the permit. Another change would be the completion will not include the joint of 3 1/2", so Ilve attached an updated schematic. thanks, «N1BOP.doc» «E-08wbs.ZIP» Mary 8. Endacott Coil Tubing Drlg Engr 907-564-4388 737d endacoms@bp.com ¡~~,^_~~__m~~~___^:,-,"~;:;.:-'_-,_w_'_:":':"-':';'.~:"'W^~-^":::'w;,;;;::-'~W;^W^~--^:"'W~;:=;"_~__'N--~~"W~~_W__-'-::":"_:':;"-'^-';-_:::':':'::~.".,^-'w;.._;:..--.::..~~'-w._^_.::....-_- ---- .._~ ~ ..~ .. .........-......,-....,-...-.-.-.- - Name: N1BOP.doc lN1BOP.doc Type: WINWORD File (application/msword); E!~?~~!~,:..~.~~e~~","""m"""'''' .... '"m'''','''','','W'''''''''''''''^W.,w».'~''''''''' ...mNm,J .---..- .-...-... . ---- --...-...- -- -- -_. - - ------- ---- ---.-______n______----- - - - - - -- ---- - - - - ~- ---- -.---..---.--.- -. --a -.-- - . ~- --- ------------.- ._- - ---- . - -.- -..----._.---.-._-.- - ---. - -- -- _. - ---- -.. ',' ----- --.- . ~ ¡ Name: E-08wbs.ZIPi ~n~~resse~(apPl:ati~o=sej ~ z. - '''is PrÒf>osed E-08A I SA~ TREE = WELLHEAD = A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 6" MCEVOY MCEV OY OTIS 60.66' 32.56' 3150' 42 @ 6000' 9913' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I., 2674' ~ Minimum 10 = 3.72511 @ 9012' 4-1/2" OTIS XN NIPPLE 1 7" TBG, 26#, L-80, 0.0383 bpf ,ID = 6.276" 1--1 8937' TOPOF4-1/2"TAILPIFE l-i 8937' ~ 1 TOPOF 7" LNR I., 8991' h [4-1/2",12.75#, L-8O, CS HYDRIL TAILPIFE, ID = 3.953" 1--1 9043' ¡----¡ r 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9525' r---4 (Perf's to be P&A'd prior to Sidetrack) FERFORA TlON SUMMARY REF LOG: SWS BHCS 04/27/80 ANGLE AT TOP ÆRF: 25 @ 9972' Note: Ref er to Roduction DB for historic al perf data SIZE SPF INTERV A L Opn ISqz DA TE 2-7/8" 4 9972'- 10012' S 10/07/89 2-7/8" 4 10022' - 10041' S 10/07/89 2-7/8" 4 10058' - 10080' S 10107/89 3-3/8" 4 10080' - 10130' 0 10/10/89 1 A3TD 1-1 10240' 1 7" LNR, 29#, L-80, 0.0371 bpf. ID = 6.184" 1-1 10283' DA TE REV BY COMMENTS 05/04/80 ORIGINAL OJMPLETION 01124/01 SIS-QAA CONVERTED TO CANV AS 03/08/01 SIS- MD FINA L 07/15/01 RN/KAK CORRECTIONS DA TE REV BY 8 í r :8: ~ .. I I I I ...1 COMMENTS ,ES 2053' 1-17" SSSV OTIS LANDING NIP,ID = 3.813" 1 .. 8910' I., BAKER SBR SEAL A SSY I 8934' 1-19-5/8" X 7" BAKER R<R 1 8937' 1-17" X 4-1/2" XO 1 8981' 1.,4-1/2"OTISXNIP,ID=3.813" I 9002' I., Liner top wI XN nipple 9012' 1-14-112" OTIS XN NIP, ID = 3,725" I 9043' 1-14-1/2" BAKER SOS TBG TAIL 1 9029' 1--1 ELMD TT LOGGED 04/02/93 1 9740' 1-1 Top of Cement I 9938' l---i Mill Window off Mechanical Whipstock 1 -110040'1" 3-3/16" X 2- 7/8" XO I 13 - 3/4' H ':' I-=-I ,\ . . . . P,~~,A CElrnent I I:? 7/':" Llno:r, ':::t?mo?n¡e,j ~,F-:>rf',j I., 11750' PI={UDHOEBAY UNIT WELL: E-08 FERrvllT No: 80-0240 ,'\PI No: 50-029-20452-00 Sec, 6, T11 N, R14E BP E:xploration (Alaska) All Measurements are from top of Riser 8/19/2002 L- ID en a::: top of bag \ l i II ~ ...1....-.. I ~I~. BAG bttm of bag middle of pipe/slips Blind/Shears .........,.........,.... I TOTs 2 3/8" combi ram/slips .......................... ~- r- Mud Cross Mud Cross ----.. '-" variable bore pipe 3 1/2".2 7/8" . ,........., """ """" TOTs 2 3/8" combi ram/slips ........................., middle of slips middle of pipes middle of flow cross middle of blind/shears Flow Tee ~~!Æ~E : F !Æ~!Æ~~~!Æ AI,ASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit E-08A BP Exploration (Alaska), Inc. Permit No: 202-095 Sur Loc: 133' SNL, 500' WEL, Sec. 06, TIIN, RI4E, UM Btmhole Loc. 2964' NSL, 3194' EWL, Sec. 32, TI2N, RI4E, UM Dear Ms. Stagg: 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 by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit E-08A. 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 may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (¡}AI.M."'~' ~ C~;;;Šechsli Taylor Chair . BY ORDER OF THE COMMISSION DATED thish-J-day of May, 2002 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 133' SNL, 500' WEL, SEC. 06, T11N, R14E, UM At top of productive interval 2581' NSL, 1617' EWL, SEC. 32, T12N, R14E, UM At total depth 2964' NSL, 3194' EWL, SEC. 32, T12N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well /' ADL 028300, 2086' MD No Close Approach 16. To be completed for deviated wells / Kick Off Depth 9945' Maximum Hole Angle 91 0 18. CasinfJ Program SPecifications Size Hole CasinQ Weight Grade CouolinQ 3-3/4" 3-112" x 3-3116" S.S1# 16.2# L-80 ST-L x2-7/S" 6.16# STATE OF ALASKA ALASKA d AND GAS CONSERVATION COMMI( ~N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 ~ratigraphic Test II Development Oil 0 Service 0 Development Gas aSingle zone) l) 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 60.7' Prudhoe Bay Field / Prudhoe 6. Property De~gnati.~~. . Bay Pool ADL OŽ~99 Y ~~ 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' E-08A 9. Approximate spud date 05/15/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11750' MD / 8991' TVDss 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} Maximum surface 2424 psig, At total depth (TVD) 8800' / 3480 psig Setting Depth Too Bottom Quantitv of Cement LenQth MD TVD MD TVD (include staQe data) 2760' 8990' 7957' 11750' 8991' 81 cu ft Class 'G' It-/GA. 4-/~/oL 4- Í1;{ ~Ö--o ':::L- 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10285 feet 9197 feet 10240 feet 9156 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 110' 110' 2674' 2674' 9525' 8508' 110' 20" x 30" 2674' 13-3/8" 9525' 9-5/8" 1283' 7" 11.8 cu yds Arcticset Concrete 3255 cu ft Arcticset II 1380 cu ft Class 'G', 130 cu ft AS I 331 cu ft Class 'G' ~F):1r~8f'~ . ß028' - 9197' L\,,~Lcl ¡~ LIJ Perforation depth: measured ~- 20. Attachments vi" Open: 10080' - 10130' Sqzd: 9972' - 10012', 10022' - 10041', 10058' - 10080' true vertical Open: 9012' - 9057' Sqzd: 8914' - 8950', 8959' - 8977', 8992' - 9012' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 :~~~. ,- " .~~~ . Permit Number. API Number Approval ~at~ See cover letter 202- - ()c¡ S- 50- 029-20452-01 5 Ô\ (), (1\ for other requirements Conditions of Approval: Samples Required 0 Yes MNO Mud Log ReqJir d. D. Yes ISlNo Hydrogen Sulfide Measures JX1' Yes 0 No Directional Survey Required J(I Yes (j No Required Working Pressure for BOPE D2K 0 3K 0 4K 0 5K 0 10K 0 15K ~.5K psi for CTU Other: "'i) Approved By Form 10-401 Rev. 12-01-85 0ngmal Signed By Cammy Oechsli T aylorr Commissioner by order of the commission ç' Date') l) O;J- SIJbmi~ In Triplicate I~ ( BP E-08a CTD Sidetrack Summary of Operations: A CTD through tubing sidetrack j.s planned for E-08 which has been shut in since April 2001. The coil sidetrack, E-08a, will exit the 7" liner in Zone 2 and target Zone 1 Band 2A. E-08a will be completed with a fully cemented liner and selectively perforated after running a cased hole CNL log. Phase 1: Prep work. Planned for April 3-5, 2002. 1. E-line to set a flow through whipstock at 9945' MD. 2. Service coil will pump a minimum of 15 bbls 13.8 ppg cement to shut off perfs below the whipstock. / ,/' Phase 2: Mill window, Drill and Complete sidetrack: Planned for May 15, 2002. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Maximum hole angle will be 91 degrees. Mud Program: . Phase 1: Seawater / . Phase 2: Mill with seawater/biozan, drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: / . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: The production liner will be a 3 Y2" ST-L x 3 3/16" TC II x 27/8" cemented liner from TD to approx. 8990'MD (7957'ss). Only the top joint will be 3Y2".v Open hole will b~.75" ."'Liner will be cemented with a minimum of ;J.4':5bbIS'15.8 ppg cement to bring cement approx.170 ft above the window. Ie¡ V44k- Well Control: . BOP diagram is attached. ./ . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 91 deg. / . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging /' . MWD Gamma Ray will be run over all of the open hole section. Memory CNL will be run inside the cemented liner. Hazards . /' The maximum recorded H2S on E-08 is 10 ppm on 9/5/2000. There are no mapped faults along the wellpath. Lost circulation risk is low. . Reservoir Pressure Res. press. is estimated to be 3480 psi at 8800'ss (7.6 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2424 psi../ TREE=, WELLHEAO = .ACTUA TOR = KB. ELEV = BF. ELEV = KOP= -. - - Max Angle = Datum MO = Datum 'TV 0 = 6" MCEVOY MCEVOY OTIS 60.66' 32.56' 3150' 42 @ 6000' 9913' 8800' SS Pror :)sed E-08A SAF7 "IOTES 8 2053' 1-17" SSSV OTIS LANOING NIP, 10 = 3.813" I 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2674' ~ ~ Minimum 10 = 3.725" @ 9012' 4-1/2" OTIS XN NIPPLE 1 TOP OF 7" LNR 1-1 8991' 1 í ~ 8910' 1-1 BAKER SBR SEAL ASSY I :g ¿s) 8934' 1-19-5/8" x 7" BAKER PKR I n! 8935 1'1 Top of Proposed 3-1/2" Liner 1',1 893; H 7" X 4-112" XO I 8945' 1'13-1/2" XN Nip, 10 = 2.75" 8981' 1'14-1/2" OTIS X NIP, 10 = 3.813" 1 Ii I I 7" TBG, 26#, L-80, 0.0383 bpf, 10 = 6.276" 1'1 8937' TOPOF 4-1/2" TAILPIPE 1-1 8937' 14-1/2",12.75#, L-80, CS HYORIL TAILPIPE, 10 = 3.953" 1-1 9043' r-!l I I ~I 9012' 1-14-1/2" OTIS XN NIP, 10 = 3.725" I 9043' 1'14-1/2" BAKER SOS TBG TAIL I 9029' 1'1 ELMO TT LOGGED 04/02/93 I I 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9525' r--4 (Perf's to be P&A 'd prior to Sidetrack) / ÆRFORA TION SUMMARY REF LOG: SWS BHCS 04/27/80 ANGLEATTOPÆRF: 25@9972' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz OATE 2-7/8" 4 9972' - 10012' S 10/07/89 2-7/8" 4 10022' - 10041' S 10/07/89 2-7/8" 4 10058' - 10080' S 10/07/89 3-3/8" 4 10080' - 10130' 0 10/10/89 I PBID 1-1 10240' I i I i J¡ ~'r! II I.. ~ ~t'i ! I ~. I I ' Ji I r I ~ I 9775' 1'1 / ~ 9945' 1---1 , ./ 110000'1'1 Top of Cement 1 / Mill Window off Mechanical Whipstock I 3-3/16" X 2-7/8" XO I 13-3/4" Holel 9645'\--¡ P&A Cement \ 12-7/8" Liner, Cemented & Perf'd 1-1 ~ 11lS0 t ~~ I 7" LNR, 29#, L-80, 0.0371 bpf, 10 = 6.184" 1-1 10283' OA TE REV BY COMMENTS 05/04/80 ORIGINAL COMPLETION 01/24/01 SIS-QAA CONVERTED TO CANVAS 03/08/01 SIS-MD FINAL 07/15/01 RN/KAK CORRECTIONS DA TE REV BY COMMENTS PRUDHOE BAY UNrr WELL: E-08 PERMIT No: 80-0240 API No: 50-029-20452-00 Sec. 6, T11 N, R14E BP Exploration (Alaska) -~---._--~"---~---------~-----"-- --------~._----~---_._----_._----------- - BP Amoco ... .... INTEQ LEGEND ---- E-08 (E-08) - - E-11 (E-11A) E-11 (Plan E-11B) - Plan#5 E-08A - -- Plan #5 T ^M ¿ Azimuths tD True North Plan: Plan #5 (E-08/Plan#5 E-08A) Magnetic North: 26.51° Created By: Brij Potnis Date: 12/10/2001 Ma~netic Field Contact Information: Strengt : 57502nT ~~te:nf~71 ggg~; ~~~;1¡ (~~n;t~¡~~i~~eqCOm Model: BGGM2001 Baker Hughes INTEQ: (907) 267-6600 WELLPATH DETAILS Plan#5 E-08A 500292045201 bp Parent Wellpath: Tie on MD: E-08 9945.00 Rig' Ref. Datum: V.sectlon Ang" 77.00' 12 ,0841141198000,00 80.70ft o+r;p,~ C:~= 0.00 ::::;to 3800--- I . [E:111E:fj~) ( 0.00 REFERENCE INFORMATION 3700-= Co-ordinate (N/E) Reference: Well Centre: E-08, True North Vertical (TVD) Reference: System: Mean Sea Level Seclion (VS) Reference: Slot - 08 (O.OON,O.OOE) Measured Depth Reference: 12: 084/14/198000:00 60.70 Calculation Method: Minimum Curvature 3600--:-- SECTION DETAILS +EJ.W DLeg TFace 1 9900.00 24.52 48.40 8787.67 2782.S4 2183.29 2 9945.00 24.54 44.82 8828.81 2775.61 2176.64 : 1rJt.: ::g: ::::~::= ~m::l ~~:~ 5 10388.45 90.64 28.08 88 3045.30 2416.08 I ~=!~e ::: ñ:~ 8880:~: iill~i 5iI:n s¡ 11212.28 8905 11140 8984.18 3231.80 311'1.93 !i Uii~~ =~!! 1=~ ::::: g!!i::! :i~:: 1311750.00 90.00 127.82 8890.95 3099.48 38$3.08 VSec Target 0.00 2.J:OO 27 .28 1.48 .> ~:O3 27 .23 ~i :~! ~i~ ~~5 25:= æ:iI 12.00 90.00 4285.90 -¡:-3300-= ~ 3200-; . 0 ... 310Q----' - -- ~3000..j=~~~~>~~L3~- i 2900-=-H mm:HHH'_IJ-_:-~_. ~28VO-~~=;~~,," æ 2700-~~,7biJ-:m g/-~-- en 260~- "Noerrors" risk based rule assigned to Plan E. 118. Plan E-118 is not going to be pursued any more, since E-08A drills to the same targets. ANNOTATIONS TARGET DETAILS TVD +Nf.-S +EI-W Shape ImfWnS.1 !æ:~ nUIi üä:i! if TVD MD Anno..tlon 8787.67 8800.00 TIP 8828.81 8945.00 KOP 8837.83 89$5.00 1 8981.70 10243.45 2 8980.89 10388.45 3 8980.32 10487.28 4 8880.32 10837.28 5 8980.89 10882.28 8 8984.18 11212.28 7 8988.10 11412.28 8 8980.30 11512.28 9 8990.85 11571.71 10 8990.95 117$0.00 TD ----~-- 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 West(-)/East(+) [100ft/in] ----;--.. + tfEn \l'liI)IqT~~J I fJ:oaEfs.3! 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 3650 3700 3750 3800 3850 3900 3950 40004050 4100 4150 4200 4250 4300 4350 4400 4450 4500 4550 Vertical Section at 77.000 [50ft/in] -~._~------------ ---------------~~---- - 12/10/2-001 1:48RM ----~-~- _._-------_.~--- ..--.", .~ I I I .J BP Amoco Baker Hughes INTEQ Planning Report ObP ( i Company: Field: Site: : Well: . Wellpath: BP Amoco Prudhoe Bay PB E Pad E-Qa Plan#5 E-08A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Datum: Mean Sea Level --.--"'--- PB E Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft ----_.-_._.__._._-~_w. E-08 E-08 Well Position: Well: ( IS.. BAICIII! ..... IN'TEQ Date: 12/10/2001 Time: 13:46:18 Co~rdinate(NErReference: Well: E-08, True North Vertical (TVD)Reference: System: Mean Sea Level Seetion(VS) ~eference: Well- (0. 00N,0.00E,77 .00Azi) Survey Calculation Method: Minimum Curvature Db: Map Zone: Coordinate System: Geomagnetic Model: ----~~---- 5973160.88 ft 662538.97 ft Latitude: Longitude: North Reference: Grid Convergence: _._..".---'~_._-,-_'- Slot Name: +N/-S 3727.21 ft Northing: 5976930.00 ft +E/-W 1986.40 ft Easting: 664444.00 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan#5 E-08A 500292045201 Current Datum: 12: 084/14/198000:00 Magnetic Data: 12/10/2001 Field Strength: 57502 nT Vertical Section: Depth From (TVD) ft 0.00 _._..._.__._~'---"--_._- 1______---- ------ -~-_._-_._.~._."_._------ Plan #5 Identical to Lamar's Plan #5 Principal: Yes Plan: Targets -----_._-"ø_,~---~--- Description TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8980.00 E-08A Polygon5.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 E-08A T5.1 E-08A T5.2 8990.00 8990.00 E-08A T5.3 _.__m_.~____._,.-.~.,_._,,---",._---_._._----- Annotation --------- TVD ft 8787.67 8828.61 8837.63 8981.70 8980.99 8980.32 8980.32 8980.89 TIP KOP 1 2 3 4 5 6 9900.00 9945.00 9955.00 10243.45 10368.45 10487.26 10837.26 10962.26 --'-'--'-'-."----------- Height 60.70 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 .-----..--- Date Composed: Version: Tied-to: Page: Oracle Alaska, Zone 4 Well Centre BGGM2001 ---,--,-'~----'-'--'- 70 19 59.134 N 148 40 53.054 W True 1 .24 deg 08 70 20 35.788 N 148 39 55.022 W ------ E-08 9945.00 ft Mean Sea Level 26.51 deg 80.82 deg Direction deg 77.00 12/10/2001 1 From: Definitive Path ~--~._~._._~_._-- Map Map <- Latitude---> <--- Longitude ---> +N/-S +E/,.W Northing Easting Deg Min See Deg Min See ft ft ft --~-.._--_.----- 3305.91 2773.48 667144.11 70 21 8.296 N 148 38 33.960 W 3305.91 2773.48 5980295.72 667144.11 70 21 8.296 N 148 38 33.960 W 3397.77 3150.59 5980395.83 667519.08 70 21 9.198 N 148 38 22.937 W 3250.00 3737.56 5980260.98 668109.11 70 21 7.742 N 148 38 5.784 W 2603.01 4973.92 5979641.31 669359.28 70 21 1.372 N 148 37 29.661 W 2579.07 4463.25 5979606.17 668849.30 70 21 1 .140 N 148 37 44.585 W 3007.74 3377.20 5980010.89 667754.18 70 21 5.361 N 148 38 16.319 W 2893.27 2889.57 5979885.76 667269.21 70 21 4.238 N 148 38 30.572 W 3251.12 2796.42 5980241.46 667168.24 70 21 7.757 N 148 38 33.290 W 3165.40 3529.81 5980171.84 667903.28 70 21 6.911 N 148 38 11.857 W 3037.82 3882.18 5980052.04 668258.34 70 21 5.655 N 148 38 1.560 W ----------.----- -'---- ----------~_.._..--- ------_._'-----~----- .------- --.-..--------"--.---...-- ObP BP Amoco ... .... Baker Hughes INTEQ Planning Report IN'TEQ r--"-----------------.------- Company: BPAmoco Date: 12/10/2001 Time: 13:46:18 Page: 2 Field: PrudhOè Bay Co-ordinate(NE) Reference: Well: E-08. True North Site: PB E Pad Vertical (rVD) Reference: System: Mean Sea Level Well: E-08 Section(VS) Reference: Well (0.00N,0.00E.77.00Azi) Wellpatb: Plan#5 E-08A Survey Calculation Metbod: Minimum Curvature Db: Oracle Annotation .- ---~._---"'-----~-----_._._------_._---------"_._---_.------,_._. MD TVD ft ft 11212.26 8984.16 7 11412.26 8988.10 8 11512.26 8990.30 9 11571.71 8990.95 10 11750.00 8990.95 TO ._---~-_.__._---- _.-'-~'--,--'------'------'--._----"- ---'---'--'-'- Plan Section Information 9900.00 24.52 46.40 8787.67 2762.54 2163.29 0.00 0.00 0.00 0.00 9945.00 24.54 44.82 8828.61 2775.61 2176.64 1.46 0.04 -3.51 271.03 9955.00 26.54 44.82 8837.63 2778.67 2179.67 20.00 20.00 0.00 0.00 10243.45 90.00 44.82 8981.70 2943.93 2343.91 22.00 22.00 0.00 0.00 10368.45 90.64 26.08 8980.99 3045.30 2416.08 15.00 0.51 -14.99 272.00 10487.26 90.00 43.89 8980.32 3142.25 2483.93 15.00 -0.54 14.99 92.00 10837.26 90.00 96.39 8980.32 3257.03 2801.71 15.00 0.00 15.00 90.00 10962.26 89.48 81 .40 8980.89 3259.44 2926.33 12.00 -0.41 -11.99 268.00 11212.26 89.05 111.40 8984.16 3231.90 3171.93 12.00 -0.17 12.00 91.00 11412.26 88.73 87.40 8988.10 3199.49 3367.76 12.00 -0.16 -12.00 269.00 11512.26 88.75 99.40 8990.30 3193.58 3467.38 12.00 0.03 12.00 90.00 11571.71 90.00 106.42 8990.95 3180.30 3525.29 12.00 2.09 11.82 80.00 11750.00 90.00 127.82 8990.95 3099.49 3683.06 12.00 0.00 12.00 90.00 _._-----,----'---'----'-~ Survey ------------_.w_-----~~_.- N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9900.00 24.52 46.40 8787.67 2762.54 2163.29 5979739.14 666546.02 0.00 2729.28 0.00 TIP 9925.00 24.53 45.52 8810.42 2769.75 2170.75 5979746.51 666553.32 1.46 2738.17 271.03 MWD 9945.00 24.54 44.82 8828.61 2775.61 2176.64 5979752.50 666559.08 1.46 2745.23 271.83 KOP 9950.00 25.54 44.82 8833.14 2777.11 2178.13 5979754.03 666560.53 20.00 2747.02 0.00 MWD 9955.00 26.54 44.82 8837.63 2778.67 2179.67 5979755.62 666562.04 20.00 2748.87 360.00 1 9975.00 30.94 44.82 8855.17 2785.49 2186.45 5979762.58 666568.67 22.00 2757.01 0.00 MWO 10000.00 36.44 44.82 8875.96 2795.32 2196.22 5979772.63 666578.23 22.00/2768.74 0.00 MWD 10025.00 41.94 44.82 8895.33 2806.52 2207.35 5979784.07 666589.11 22.00 2782.11 0.00 MWD 10050.00 47.44 44.82 8913.10 2818.99 2219.74 5979796.80 666601.22 22.00 2796.98 0.00 MWD 10075.00 52.94 44.82 8929.10 2832.60 2233.27 5979810.71 666614.45 22.00 2813.23 0.00 MWD 10100.00 58.44 44.82 8943.18 2847.25 2247.82 5979825.67 666628.67 22.00 2830.70 0.00 MWO 10125.00 63.94 44.82 8955.22 2862.78 2263.26 5979841.54 666643.76 22.00 2849.24 0.00 MWD 10150.00 69.44 44.82 8965.11 2879.06 2279.44 5979858.17 666659.58 22.00 2868.66 0.00 MWD 10175.00 74.94 44.82 8972.76 2895.93 2296.21 5979875.40 666675.97 22.00 2888.80 0.00 MWD 10200.00 80.44 44.82 8978.08 2913.25 2313.42 5979893.10 666692.80 22.00 2909.46 0.00 MWD 10225.00 85.94 44.82 8981.05 2930.85 2330.91 5979911.07 666709.90 22.00 2930.47 0.00 MWD 10243.45 90.00 44.82 8981.70 2943.93 2343.91 5979924.43 666722.61 22.01 2946.08 360.00 2 10250.00 90.03 43.84 8981.70 2948.62 2348.48 5979929.22 666727.07 14.99 2951.58 272.00 MWO 10275.00 90.16 40.09 8981.66 2967.20 2365.19 5979948.16 666743.37 15.00 2972.05 272.00 MWD 10300.00 90.29 36.34 8981.56 2986.84 2380.66 5979968.13 666758.40 15.00 2991.53 271.99 MWO 10325.00 90.42 32.60 8981.40 3007.45 2394.80 5979989.04 666772.09 15.00 3009.95 271.98 MWD 10350.00 90.55 28.85 8981.19 3028.93 2407.57 5980010.80 666784.38 15.00 3027.23 271.95 MWO 10368.45 90.64 26.08 8980.99 3045.30 2416.08 5980027.35 666792.53 15.01 3039.20 271.87 3 10375.00 90.61 27.06 8980.92 3051.16 2419.01 5980033.27 666795.33 15.00 3043.37 91.84 MWD 10400.00 90.48 30.81 8980.69 3073.03 2431.10 5980055.41 666806.94 15.00 3060.08 92.01 MWD 10425.00 90.34 34.56 8980.51 3094.07 2444.60 5980076.73 666819.97 15.00 3077.96 92.05 MWD 10450.00 90.20 38.30 8980.39 3114.18 2459.44 5980097.16 666834.37 15.00 3096.95 92.07 MWD 10475.00 90.07 42.05 8980.33 3133.28 2475.57 5980116.61 666850.07 15.00 3116.96 92.09 MWD 10487.26 90.00 43.89 8980.32 3142.25 2483.93 5980125.76 666858.23 15.00 3127.12 92.10 4 10500.00 90.00 45.80 8980.32 3151.28 2492.91 5980134.99 666867.01 15.00 3137.90 90.00 MWO ObP BP Amoco ( BIi. ..... Baker Hughes INTEQ Planning Report IN'TßQ -------.- Company: BP Amoco Date: 12/10/2001 Time: .. 13:46: 18 Page: 3 Field: Prudhoe Bay Co-órdinåte(NE) Reference: Well: E~8, True North Site: PB E Pad Vertical (TVD) Reference: System: Mean Sea Level Well: E-08 Section (VS) Reference: WeU.(O.OON,O.OOE, 77.00Azi) Wellpath: Plan#5 E-08A Survey Calculation Method: Minimum Curvature Db: Oracle Survey ~-"-"-'---"-'_._-_u_._----------_... -- ----- MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg _.,,------_._-"---.'-----,-----~-- .--...------ 10525.00 90.00 49.55 8980.32 3168.11 2511.39 5980152.22 666885.12 15.00 3159.69 90.00 MWD 10550.00 90.00 53.30 8980.32 3183.70 2530.93 5980168.23 666904.31 15.00 3182.24 90.00 MWD 10575.00 90.00 57.05 8980.32 3197.97 2551.45 5980182.95 666924.51 15.00 3205.44 90.00 MWD 10600.00 90.00 60.80 8980.32 3210.87 2572.86 5980196.31 666945.63 15.00 3229.21 90.00 MWD 10625.00 90.00 64.55 8980.32 3222.34 2595.07 5980208.27 666967.58 15.00 3253.43 90.00 MWD 10650.00 90.00 68.30 8980.32 3232.34 2617.98 5980218.77 666990.26 15.00 3278.00 90.00 MWD 10675.00 90.00 72.05 8980.32 3240.82 2641.49 5980227.75 667013.58 15.00 3302.81 90.00 MWD 10700.00 90.00 75.80 8980.32 3247.74 2665.51 5980235.20 667037.44 15.00 3327.77 90.00 MWD 10725.00 90.00 79.55 8980.32 3253.07 2689.93 5980241.07 667061.74 15.00 3352.77 90.00 MWD 10750.00 90.00 83.30 8980.32 3256.80 2714.65 5980245.34 667086.36 15.00 3377.69 90.00 MWD 10775.00 90.00 87.05 8980.32 3258.90 2739.55 5980247.98 667111.22 15.00 3402.43 90.00 MWD 10800.00 90.00 90.80 8980.32 3259.37 2764.54 5980249.00 667136.19 15.00 3426.89 90.00 MWD 10825.00 90.00 94.55 8980.32 3258.20 2789.51 5980248.38 667161.18 15.00 3450.95 90.00 MWD 10837.26 90.00 96.39 8980.32 3257.03 2801.71 5980247.48 667173.40 15.00 3462.57 90.00 5 10850.00 89.95 94.86 8980.33 3255.78 2814.39 5980246.51 667186.10 12.00 3474.65 268.00 MWD 10875.00 89.84 91.86 8980.37 3254.32 2839.35 5980245.59 667211.08 12.00 3498.64 268.00 MWD 10900.00 89.74 88.87 8980.47 3254.16 2864.34 5980245.98 667236.07 12.00 3522.96 268.01 MWD 10925.00 89.63 85.87 8980.60 3255.31 2889.31 5980247.68 667261.01 12.00 3547.55 268.02 MWD 10950.00 89.53 82.87 8980.78 3257.76 2914.19 5980250.68 667285.83 12.00 3572.34 268.03 MWD 10962.26 89.48 81.40 8980.89 3259.44 2926.33 5980252.62 667297.93 11.99 3584.54 267.96 6 10975.00 89.46 82.93 8981.01 3261.18 2938.95 5980254.63 667310.51 11.99 3597.23 90.91 MWD 11000.00 89.41 85.93 8981.26 3263.60 2963.83 5980257.60 667335.32 12.00 3622.02 90.99 MWD 11025.00 89.36 88.93 8981.53 3264.73 2988.80 5980259.27 667360.26 12.00 3646.60 90.96 MWD 11050.00 89.31 91.93 8981.82 3264.54 3013.80 5980259.64 667385.25 12.00 3670.92 90.92 MWD 11075.00 89.26 94.93 8982.13 3263.05 3038.75 5980258.69 667410.23 12.00 3694.89 90.89 MWD 11100.00 89.22 97.93 8982.46 3260.25 3063.59 5980256.44 667435.12 12.00 3718.46 90.85 MWD 11125.00 89.18 100.93 8982.81 3256.15 3088.24 5980252.89 667459.86 12.00 3741.57 90.81 MWD 11150.00 89.14 103.93 8983.18 3250.78 3112.65 5980248.04 667484.38 12.00 3764.14 90.77 MWD 11175.00 89.10 106.93 8983.56 3244.13 3136.75 5980241.93 667508.61 12.00 3786.12 90.73 MWD 11200.00 89.07 109.93 8983.96 3236.23 3160.46 5980234.55 667532.49 12.00 3807.45 90.68 MWD 11212.26 89.05 111.40 8984.16 3231.90 3171.93 5980230.48 667544.05 12.01 3817.65 90.70 7 11225.00 89.03 109.87 8984.38 3227.41 3183.85 5980226.25 667556.07 12.02 3828.26 269.07 MWD 11250.00 88.98 106.87 8984.81 3219.54 3207.57 5980218.90 667579.95 12.00 3849.60 269.03 MWD 11275.00 88.93 103.87 8985.27 3212.91 3231.67 5980212.80 667604.19 12.00 3871.59 269.08 MWD 11300.00 88.89 100.87 8985.75 3207.56 3256.08 5980207.99 667628.71 12.00 3894.17 269.13 MWD 11325.00 88.84 97.87 8986.24 3203.49 3280.74 5980204.46 667653.45 12.00 3917.28 269.19 MWD 11350.00 88.81 94.87 8986.76 3200.72 3305.58 5980202.23 667678.34 12.00 3940.86 269.25 MWD 11375.00 88.77 91.87 8987.28 3199.25 3330.52 5980201.31 667703.31 12.00 3964.84 269.31 MWD 11400.00 88.74 88.87 8987.83 3199.09 3355.52 5980201.70 667728.30 12.00 3989.15 269.37 MWD 11412.26 88.73 87.40 8988.10 3199.49 3367.76 5980202.37 667740.53 11.96 4001.17 269.55 8 11425.00 88.73 88.93 8988.38 3199.90 3380.50 5980203.06 667753.26 11.97 4013.67 90.11 MWD 11450.00 88.73 91.93 8988.93 3199.71 3405.49 5980203.42 667778.24 12.00 4037.98 89.97 MWD 11475.00 88.74 94.93 8989.49 3198.22 3430.43 5980202.48 667803.21 12.00 4061.95 89.90 MWD 11500.00 88.75 97.93 8990.04 3195.42 3455.27 5980200.22 667828.10 12.00 4085.52 89.83 MWD 11512.26 88.75 99.40 8990.30 3193.58 3467.38 5980198.65 667840.25 12.01 4096.91 89.96 9 11525.00 89.02 100.90 8990.55 3191.33 3479.92 5980196.67 667852.84 12.00 4108.62 79.81 MWD 11550.00 89.54 103.86 8990.86 3185.97 3504.33 5980191.85 667877.36 12.00 4131.21 79.97 MWD 11571.71 90.00 106.42 8990.95 3180.30 3525.29 5980186.64 667898.44 11.98 4150.35 79.92 10 11575.00 90.00 106.82 8990.95 3179.36 3528.44 5980185.77 667901.61 12.12 4153.21 90.00 MWD 11600.00 90.00 109.82 8990.95 3171.50 3552.17 5980178.44 667925.50 12.00 4174.56 90.00 MWD 11625.00 90.00 112.82 8990.95 3162.41 3575.46 5980169.86 667948.98 12.00 4195.21 90.00 MWD 11650.00 90.00 115.82 8990.95 3152.12 3598.24 5980160.07 667971.98 12.00 4215.09 90.00 MWD 11675.00 90.00 118.82 8990.95 3140.65 3620.45 5980149.09 667994.43 12.00 4234.15 90.00 MWD ---.-- _._--""'---"'-~'---'-----'--"-~'~----'---'-----"- ObP Company: BP Amoco Field: Prudhoe Bay Site: PB E Pad Well: E-08 Wellpath: Plan#5 E-08A Survey .-.-.----.-- I MD Incl Azim ft deg deg 11700.00 90.00 121.82 11725.00 90.00 124.82 i ---~~-~~~~~-~----~~~?_- 127.82 BP Amoco Baker Hughes INTEQ Planning Report -.. .... INTEQ I>ate: -- 12/1012001 Time: --.13:46:18 Cø.ordiriáte(NE) Reference: Well: E.08,True North Vertical (TVD) lteferenœ: System: Mean Sealevel Seetjon(VS)Reference: Well (0.00N,0.00E,77.00Azi) i Survey çatcuJation Method: Minimum Curvature Db: Oracle I --------~ Page: 4 SSTVD N/S EIW MapN MapE DLS VS TFO Tool ft ft ft ft ft deg/1 DOft ft deg 8990.95 3128.03 3642.02 5980136.95 668016.28 12.00 4252.33 90.00 MWD 8990.95 3114.30 3662.91 5980123.68 668037.46 12.00 4269.60 90.00 MWD 8990.95 3099.49 3683.05 5980109.32 668057.92 12.00 4285.89 90.00 TO Well # ( Dat~ All Measurements are from top of Riser 4/24/2002 24.71 from top of floor to rig mats 21.S1 of room under floor to rig mats s- a> en .- c::: Flanae to Flanae Heiahts top of bag 7" otis X-O .70' BAG 2.80' btlm of bag middle of slips Blind/Shears ...,.,.............." TOTs / 1.90' middle of pipes 2-3/8" pipe/slips """"""""",'/' - r-- Mud Cross Mud Cross 1.70' middle of flow cross --- '--' 3-1/2" pipe/slips ..,."......,..,..., / middle of blind/shears TOTs 1.90' middle of pipe/slips 2-3/8 X 3.5 Var. pipe ,.,...,/.,/'" middle of master - Tubing spool adapter .... Lock down screws Tubing Spool Rig mats ,"..-;..("---;.>~.., ~~:'''4--:..-,'"''-~''',<.' ..-,~..-.-,<--><,->' -~.--> H 206301 DATE 03/14/02 CHECK NO. 00206:]() i DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS 100, 00 VENDOR DISCOUNT Ai ,ASV...An I I .A NET 100.00 00 031202 CK031202K PYMT COMMENTS: HANDL!NG INST: H Permit to Drill Fee S/H - Terrie Hubble X4628 t:;08A THE AITACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100. 00 100, 00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 206301 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 ---¡:j'2 00206301 PAY ONE HUNDRED & 00/100************************************* US DOLLAR ,~, DATE 03/14/02 AMOUNT $100. 00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 <WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 Q' "'.""""', , ," ,.$ rØ " '''1 ,'. " \, , n, /J..I h",. /: I \ ~ ç;.~ (j"I~ "~--1.:~, III 2 0 b j 0 . III I: 0... ¡. 2 0 j B 9 5 I: 0 0 B ...... ¡. 9 II' ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITI AL LETTER f?5Lt E-QBA CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOP7E / REDRlLL EXPLORA TJON INJECTION WELL INJECTION WELL REDRlLL WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL~ D~OSAL ~NO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL "CLUE" Tbe permit is for a new wellbore segment of existing well ----' Permit No, . API No. . . Production should continue to be reported as a function of the original API number stated above. . In accordance with ~O AAC 25.005(f), aU records, data and logs acquired for tbe pilot bole. must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel~ (n~me on permit). . Annular disposal has ~ot been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbatan disposal of fluids generated... . ANNULUS L-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. Tbe permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY ~¡?>G WELL NAME $'¿¿£ -~A FIELD & POOL ~t/O/~ INITCLASS ~Ú I ûlL ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . .. . . . . . . . . . . . . .. . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . '. . . . N APm PA T~ 12. Permit ca~ be issued without administrativ~ approval.. . . . . ' N ~j/ 'f .¿'1..0Z-13. Can permit be approved before 15-day walt.. . . . . . . . . . N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . .¥-N- 15. Suñace casing protects all known USDWs. . . . . . . . . . . -¥--N- Ai J A- 16. CMT vol adequate to circulate on'conductor & suñ csg. . . . . -¥-t+ II 17. CMT vol adequate to tie-in long string to suñ csg. . . . . . . .~ J - 18. CMT will cover all known productive horizons. . . . . . . . . . ' , NN 4"dL"Q ~t....f Ue¿ss. 19. Casing designs adequate for C. T. B & permafrost. . . . . . . (j 20. Adequate tankage or reserve pit.. . . . .. . . . . . . . . . . NeT Þ u.... 21. If a re-drill, has a 10-403 for abandonment been approved. .. * X. NN pr D t go '- 0 'l..-"f j ~ (.(.¡\.. d V\{ '30 'Z. - t.f'S ' 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 0tt 23. If diverter required, does it meet regulations. . . . . . . . . .Y N ,f'.l/Æ- 24. Drilling fluid program schematic & equip list adequate. . . . . ¿¡¿ N 25. BOPEs. do they meet regulation. . . . . . . . . . . . . . . . IN U AP~R D~Tij 26. BOPE press rating appropriate;testto 3S00 psig. N Nl~P - 2..<.{23../ p~ STtt. C7Dt1.. þc;t. WGø\ 'Ir",;(o L 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ - . , 1f't:'ìht11 Ul 28. Work will occur without operation shutdown. . . . . . . . . . . " N '-4 A L. .("0 i . " . kJi!:./' I ~l~-ß;:> 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . ,~f.J<. ~ GEOLOGY 30. Permit can be issuedw/ohydrogen sulfide measures. . . .. ÆN #z:;.¿ ~ i--«-- é:;-ò8' (/oó(J~' ~ 31. Data presented on potential overpressure zones. . . . . . . t/ 32. Seismic analysis of shallow gas zones. . . . . . . . . Z. . . Y N APeR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . Y N ~ t/.L'7 ,02-- 34. Contact name/phone for weekly progress reports [expl tory only] Y N ANNULAR DISPOSAL 35. With proper cementing records. this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to suñace; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPC TEM Jt~ SF~ WGA vJf;/í APPR DATE PROGRAM: Exp - Dev ~Redrll :::. Serv - Wellbore seg - Ann. disposal para req - GEOLAREA 67D UNIT# O//~,çð ONfOFFSHORE O}/) -3-~a-"'-- /oc:~=<- ~ ~L £2.~30sL; --r<>rr~ ~4J/--f ~ ¡,:D. vÁ.- 4-:DL OZ$¿;/ ~" ) Y N Y N AlA Y"a ¡JJ?<;;fd . ~(L~<è ~ c;"c! 3:" Comments/Instructions: I COT , DTSGSJO~/OL- JMH Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically. . organize this category of information. ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 10 11:57:39 2003 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/03/10 Origin...................STS Reel Name................ UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name............ .LISTPE Date.....................03/03/10 Origin. . .. . . . . . . . . . . . .. . . STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. ( Scientific Technical Services Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-022142 C. ZAWADZKI WHITLO'ii'ilIEGBI # SURFACE LOCATION SECTION: TO'iiiJNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD E-08A 500292045201 BP Exploration Sperry Sun 10-MAR-03 MWD RUN 2 AK-MW-022142 C. ZAWADZKI WHTTLOW/EGBI 6 UN 14E 133 500 55.41 .00 28.54 (Alaska) Inc. MWD RUN 3 AK-MW-022142 C. ZAWADZKI WHITLOW/EGBI OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 9.625 9525.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS) . ~Od-L)9.5 I J !c):3() (' (,: 3. WELL KICKED OFF FROM E-08 WITH TOP OF WHIPSTOCK SET AT 9953' MD, 8780' TVDSS. 4. MWD RUN 1-3 WERE DIRECTIONAL WITH G~1A MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. DIGITAL DATA ONLY WAS DEPTH SHIFTED TO THE SCHLUMBERGER MEMORY CNL OF 8/27/2002, PER THE 1/712003 E-MAIL FROM D. SCHNORR (BP EXPLORATION). LOG AND HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-3 REPRESENT WELL E-08A WITH API # 50-029-20452-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 11776' MD 1 8934' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/10 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 9932.5 9960.5 STOP DEPTH 11741.5 11769.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 9770.0 9964.0 10025.0 10059.0 10076.0 10099.0 10120.5 10195.0 10270.0 10359.5 10387.0 10413.5 10433.0 10489.5 10673.5 10833.0 10896.5 10903.0 10943.0 10964.0 10989.0 11010.0 11098.0 11118.5 11198.0 11214.5 11236.0 DEPTH GR 9773.5 9967.5 10025.5 10060.0 10077.0 10100.0 10121. 0 10194.5 10271.5 10361. 0 10391. 5 10421.0 10438.5 10493.0 10677.5 10836.0 10903.0 10907.5 10947.5 10970.0 10996.0 11012.5 11101. 5 11123.0 11202.5 11218.0 11240.5 ( (' 11301.0 11352.5 11376.0 11391.5 11401.5 11430.5 11443.0 11452.5 11461. 0 11498.5 11519.5 11612.5 11624.0 11674.5 11710.5 11741.5 $ 11306.0 11359.5 11382.0 11395.5 11406.5 11436.0 11448.0 11458.0 11466.5 11504.0 11525.5 11616.5 11629.0 11681. 0 11717.0 11748.0 # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 9936.0 2 10180.5 3 10654.5 MERGE BASE 10180.0 10654.0 11776.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units.............,.......... Ddtum Specification Block sUb-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9932.5 11769.5 10851 3675 9932.5 11769.5 ROP MWD FT/H 0 1966.2 123.394 3619 9960.5 11769.5 GR MWD API 14.39 336.44 47.0926 3619 9932.5 11741.5 First Reading For Entire File..........9932.5 Last Reading For Entire File...........11769.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/10 Maximum Physical Record..65535 Fi 1 e TY'Pe................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.......,..... .STSLIB. 002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/10 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ( header data for each bit run in separate files. 1 .5000 START DEPTH 9936.0 9964.0 STOP DEPTH 10152.0 10180.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXH1UM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER I S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (1B/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..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value..................... .-999 24-AUG-02 Insite 4.3 Memory 10180.0 9964.0 10180.0 26.6 79.1 TOOL NUMBER 126583 3.750 Flo-Pro 8.60 .0 9.1 22000 12.8 .000 .000 .000 .000 .0 130.8 .0 .0 (' Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9936 10180 10058 489 9936 10180 ROP MWD010 FT!H 1 135.66 80.917 433 9964 10180 GR MWD010 API 14.61 161.77 36.2297 433 9936 10152 First Reading For Entire File..........9936 Last Reading For Entire Fi1e...........10180 File Trailer Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/10 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.OO3 Service Sub Level Name... Version Number....... . . . .1.0.0 Date of Generation.......03/03/10 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OO2 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 10152.5 10180.5 STOP DEPTH 10626.5 10654.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 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: MAXTMUM ANGLE: 25-AUG-02 Insite 4.3 Memory 10654.0 10180.0 10654.0 81.5 92.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER 126583 ( # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 # 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: Flo Pro 8.60 .0 9.0 22000 8.6 .000 .000 .000 .000 .0 141.4 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10152.5 10654 10403.3 1004 10152.5 10654 ROP MWD020 FT/H 0 1242.01 103.358 948 10180..5 10654 GR MWD020 API 19.51 134.41 45.2586 949 10152.5 10626.5 First Reading For Entire File..........10152.5 Last Reading For Entire File...........l0654 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Nurober...........1.0.0 Date of Generation.......03/03/10 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.OO4 Service Sub Level Name... ( Version Number...........1.0.0 Date of Generation.......03/03/1C Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEl\.DER FILE NUMBER: RAW MWD Curves and log BIT RUN NU!'1BER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 ( header data for each bit run in separate files. 3 .5000 START DEPTH 10627.0 10654.5 STOP DEPTH 11748.0 11776.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 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 DGR DUAL GAMMA RAY $ # 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..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined 26-AUG-02 Insite 4.3 Memory 11776.0 10654.0 11776.0 86.3 93.0 TOOL NUMBER 126583 3.750 Flo Pro 8.60 .0 9.4 22000 14.4 .000 .000 .000 .000 .0 148.5 .0 .0 (' Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 }\PI 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10627 11776 11201. 5 2299 10627 11776 ROP MWD030 FT/H 0 1966.2 140.406 2244 10654.5 11776 GR MWD030 API 14.39 336.44 50.0538 2243 10627 11748 First Reading For Entire File..........10627 Last Reading For Entire File...........l1776 File Trailer Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/10 Maximum Physical Record..65535 Fi 1 e Type................ .10 Next File Name...........STSL1B.005 Physical EOF Tape Trailer Service name.............LISTPE Date.....................03/03/10 Origin...................STS Tape Name................ UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Coroments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................03/03/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Coromen t s. . . . . . . . . . . . . . . . . ST S .11 S Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File