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Home My WebLink About204-2187. 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 05-24A Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-218 50-029-22204-01-00 12302 Conductor Surface Intermediate Production Liner 8933 80 3854 9380 3086 12217 20" 10-3/4" 7" 4-1/2" 8934 31 - 111 30 - 3884 26 - 9406 9216 - 12302 31 - 111 30 - 3513 26 - 8362 8194 - 8933 12172 470 2090 5410 7500 None 1490 3580 7240 8430 9942 - 12210 4-1/2" 12.6# 13CR 28 - 9228 8729 - 8934 Structural 4-1/2" HES TNT Packer 9171 , 8154 8997, 9171 7995, 8154 Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907.564.4672 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 0028325 28 - 8205 N/A N/A 151 125 0 0 1927 1658 1600 992 305 300 325-219 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S-3 Perm Packer 8997 , 7995 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 No SSSV Installed By Grace Christianson at 2:24 pm, May 20, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.20 13:02:51 - 08'00' Bo York (1248) JJL 6/13/25 DSR-6/3/25 RBDM JSB 052325 ACTIVITY DATE SUMMARY 5/8/2025 LRS CTU #1 - 1.50" Blue Coil - Job Objective - Jewelry log/Ext AdPerf Travel to DS5, MIRU CTU.. M/U NS MHA. Confirm CTC tag against brass 13k. M/U HES GR/CCL with 2.25" JSN. PT stack and safety joint to 300/4300. RIH and load well with 1% KCl w/ Safelube. Log from TD tag at 12216' CTMD to 9800', painting tie- in flag at 10800'. Kill well at rate with slick 1% KCl w/ Safelube, well remained on a vac and continue with MCHF rate. Confirm well kill at surface and lay down logging BHA. Perform PJSM with kick drill for safety joint deployment and discuss contingencies if unable to deploy. ...Continued on WSR 5-9-25... 5/9/2025 LRS CTU #1 - 1.5" Blue Coil ***Cont. from WSR 5-8-25*** Job Objective: Extended AddPerf Deploy perf gun BHA #1 with 500' (325' loaded) of 2" Maxforce perf guns, 6 spf. RIH, correct at flag to top shot. Attempt to RIH to top shot and tag early, 11461. Continue working pipe, trip up hole, pump a WBV and RIBIH. Tag at 11463 at 50fpm, pick up and RIH at 70fpm and start pushing. Run past and pick up into top shot depth. Perforate 11595-11760, 11935-12095'. POOH pumping MCHF.L/D spent guns. Recover 1/2" ball. PT MHA. M/U gun run number 2 with 500' (310' loaded) of 2" Maxforce perf guns, 6 spf. RIH, correct at flag to top shot. Perforate 10220'-10325' and 10515'-10720'. POOH and confirm well kill. Recover perf gun BHA #2 with all shots fired. ...Continued on WSR 5-10-25... 5/10/2025 LRS CTU #1 - 1.50" Blue Coil ***Cont. from WSR 5-9-25*** Job Objective: Extended AddPerf Retrieve perf gun BHA #2. Freeze protect tubing. Rig down CTU. ***Job Complete*** 5/12/2025 LRS WTU #6 Begin WSR 5/12/25. Post Perf Flowback Continue WSR on 5/13/25 5/13/2025 LRS WTU #6 Continue WSR from 5/12/25. Post Perf Flowback, SLBU Continue WSR on 5/14/25 5/14/2025 LRS WTU #6 Continue WSR from 5/13/25. Post Perf Flowback, SLBU Continue WSR on 5/15/25 5/15/2025 LRS WTU #6 Continue WSR from 5/14/25. Post Perf Flowback, SLBU Continue WSR on 5/16/25 5/16/2025 TFS Unit 1 Assist Well Testers with (Flowline Freeze Protect) Pumped 3 BBLS 60/40 and 20 BBLS of Crude to Freeze Protect 05-05 Flowline. Pressured FL to 1500 psi per Pad Op. Flags and Tags hung on Wing Valve upon departure. 5/16/2025 LRS WTU #6 Continue WSR from 5/15/25 Post Perf Flowback Rig Down move unit End WSR 5/16/25 Daily Report of Well Operations PBU 05-24A 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 05-24A Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-218 50-029-22204-01-00 ADL 0028325 12302 Conductor Surface Intermediate Production Liner 8933 80 3854 9380 3087 12217 20" 10-3/4" 7" 4-1/2" 8934 31 - 111 30 - 3884 26 - 9406 9216 - 12303 2430 31 - 111 30 - 3513 26 - 8362 8194 - 8933 12172 470 2090 5410 7500 none 1490 3580 7240 8430 9942 - 12210 4-1/2" 12.6# 13CR 28 - 91008729 - 8934 Structural 4-1/2" HES TNT , 4-1/2" Baker S-3 Perm , No SSSV 8997 , 9171 7995 , 8154 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 5-1-2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-219 By Gavin Gluyas at 9:56 am, Apr 11, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.04.11 05:42:01 - 08'00' Bo York (1248) DSR-4/11/25 10-404 Perforating gun not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment JJL 4/15/25 A.Dewhurst 11APR25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.16 11:54:13 -08'00'04/16/25 RBDMS JSB 041725 Ext Add Perf 05-24A PTD:204-218 Well Name:05-24A API Number:50-029-22204-01-00 Current Status:Operable - Producer Rig:CTU Estimated Start Date:5/01/25 Estimated Duration:2days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd:Check status Regulatory Contact:Carrie Janowski (907) 564-5179 First Call Engineer:David Bjork (907) 564-4672 (907) 440-0331 Expected Rates Post Work ~1 MSCFD, 300 BOPD and2000BWPD Current Bottom Hole Pressure:3310 psi @ 8,800’ TVD 7.3 PPGE | (Average Ivishak BHP) Maximum Expected BHP:3310 psi @ 8,800 TVD 7.3 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1200 psi (Taken on 12/15/22) Min ID:2.37” Patch @ 9,958’ MD Max Angle:95 Deg @ 11,371’ MD, 70 Deg at 10,222’ MD Brief Well Summary: 05-24 was sidetracked in Nov 2004. 05-24A is a gravity drainage well with open Z1A perfs in the 4-1/2” liner. A Z2C lens was perfed in 2005 and patched over in 2002. Unswept Z1A remains unperforated. Current oil and gas rates are low with 98% watercut. Objective:Perforate remaining unswept Z1A interval. Future opportunities include Z1B at the heel and Z4/Sag rich gas. Procedure Coiled Tubing 1. MU drift BHA with GR/CCL in 2.25” carrier, drift to 12,150ft. Note: 2.37” ID patch from 9,928ft-9,958ft 2. Correlate with attached log information. a. Correct flag and send to OE for confirmation. Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead 1.2x wellbore volume ~190 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 157 bbls b. 4-1/2” tubing/liner – 10,335’ X .0152 bpf = 157 bbls Ext Add Perf 05-24A PTD:204-218 3. At surface, prepare for deployment of TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 5.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. c.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 6.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2” Millenium guns or similar Perf Interval (tie-in depths) Lengths Total Gun Length Weight of Gun (lbs) Run #1 11,595’ - 11,760’ 175’ blank 11,935’ - 12,095’ 11,595’–12,095’500’~2,800 lbs (5.6 ppf) Run #2 10,220’ – 10,325’ 190’ blank 10,515’ – 10,720’ 10,220’–10,720’500’~2,800 lbs (5.6 ppf) 7. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Ext Add Perf 05-24A PTD:204-218 Attachments: Wellbore Schematic, Proposed Schematic, Tie-In Log, BOPE and rig-up diagram, Sundry Change Form Current Wellbore Schematic Ext Add Perf 05-24A PTD:204-218 Proposed Wellbore Schematic 11,595’-11,760’ 11,935’-12,095’ 10,220’-10,325’ 10,515’-10,720’ New Perforations Ext Add Perf 05-24A PTD:204-218 Tie-in Log Ext Add Perf 05-24A PTD:204-218 Ext Add Perf 05-24A PTD:204-218 BOP Schematic Ext Add Perf 05-24A PTD:204-218 Ext Add Perf 05-24A PTD:204-218 Ext Add Perf 05-24A PTD:204-218 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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 05-24A Patch Perfs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-218 50-029-22204-01-00 12302 Conductor Surface Intermediate Production Liner 8933 80 3854 9380 3087 12217 20" 10-3/4" 7" 4-1/2" 8934 31 - 111 30 - 3884 26 - 9406 9216 - 12303 31 - 111 30 - 3513 26 - 8362 8194 - 8933 12172 470 2090 5410 7500 none 1490 3580 7240 8430 9942 - 12210 4-1/2" 12.6# 13CR 28 - 9100 8729 - 8934 Structural 4-1/2" HES TNT, 8997 , 7995 No SSSV 8997 , 9171 7995 , 8154 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028325 28 - 8089 31 218 0 0 2335 1431 0 0 308 332 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S-3 Perm ,9171 , 8154 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 Anne Prysunka at 10:22 am, Jan 04, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.01.03 15:06:39 -09'00' RBDMS JSB 010523 PBU 05-24A Patch Perfs Development Sundry Number DSR-1/6/23 PRUDHOE BAY, PRUDHOE OIL Plug Perforations 204-218 N/A WCB 10-23-2023 ACTIVITYDATE SUMMARY 11/11/2022 *** WELL FLOWING ON ARRIVAL*** DRIFTED w/ 3' x 1-3/4" STEM, 3.69 G-RING, DRIFT FREELY TO 10,000' SLM DRIFTED 40' x 3.70" DUMMY WHIPSTOCK TO 9,555' SLM (target depth 9,960') DRIFTED 20' x 3.70" DUMMY WHIPSTOCK TO 9,555' SLM (target depth 9,960') DRIFTED 45KB PACKER DRIFT (top), 24' STL PIPE, 45KB PACKER DRIFT (btm), (OAL 34'.5") DRIFT FREELY TO 10,000' SLM ***JOB COMPLETE, WELL LEFT S/I*** 11/19/2022 *** WELL FLOWING ON ARRIVAL *** OBJECTIVE: SET 3.70'' BAKER PATCH RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RIH CH/GUN GAMMA/BAKER #10 SETTING TOOL/3.70'' BAKER PATCH WHILE RIH SET DOWN @ 1835 & 1865' BUT ABLE TO WORK THRU BOTH SPOTS (APPEARS TO BE PUSHING SOMETHING DOWNHOLE) CONT IN HOLE BUT SET DOWN IN SSSV AND UNABLE TO WORK UP OR DOWN LRS PUMPED CRUDE AND METH TO TRY AND WORK FREE W/ NO SUCCESS (SEE LRS REPORT) SET PATCH IN THE SSSV AREA TO GET FREE - SET SUCCESSFULLY (BAKER PATCH LEFT IN HOLE W/ EST TOP @ 2210') (OAL = 31.06' / 3.70" OD) ***PATCH DIAGRAM GIVEN TO SLICKLINE FOR FISHING*** RDMO YELLOWJACKET ELINE ***WELL S/I ON DEPARTURE*** 11/19/2022 Freeze Protect flowline with 40 bbls crude. 11/19/2022 T/I/O= 1500/1615/0 (PATCH TUBING / LINER) Assist YJ EL free patch from SSSV nipple, Pumped 67 bbls crude at various rates then 10 bbls neat methanol followed by 33 bbls 160*F crude. EL in control of well upon departure. 11/21/2022 ***WELL S/I ON ARRIVAL*** (patch tubing/liner) DRIFT TBG TO 45KB PATCH @ 2166' SLM w/ 3.83" G-RING JARRED PATCH FREE, MOVED UPHOLE TO 2138' SLM & BEGAN TO STRIP G FN (slipping out w/ 1200# oj lick) STAND BY FOR WIND ***CONTINUED ON 11/21/22 WSR*** 11/22/2022 Assist Slickline (PATCH TUBING / LINER) Get snow removal/ SU/RU/PT ***Job Cont to 11-23-2022 WSR*** 11/22/2022 ***CONTINUED FROM 11/21/22 WSR*** (Patch tubing liner) STAND BY FOR WIND WORK PATCH FROM 2,139' SLM TO 460'SLM w/ 4" G FISHING NECK SPEAR (unable to go back downhole) JAR ON PATCH UP & DOWN FOR 2 HOURS. ***CONTINUED ON 11/23/22 WSR*** Daily Report of Well Operations PBU 05-24A OBJECTIVE: SET 3.70'' BAKER PATCH Daily Report of Well Operations PBU 05-24A 11/23/2022 ***CONTINUED FROM 11/22/22*** (Patch tubing liner) RECOVERED 31' PATCH FROM 651' SLM BRUSH & FLUSH w/ 4 1/2" BLB & 3.60" GAUGE RING TO DEVIATION @ 10,260' SLM DRIFT TBG TO 10000' SLM w/ 30' x 45KB PATCH DRIFT (no issues) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 12/3/2022 RD Intergal and Block valve from OA, Removed VR Plug, RU Gate valve to OA, Torqued to API specs. RD Intergal and Block valve from OA Companion, RU Blind flange w/ alemite fitting to OA Companion, Torqued to API specs. 12/6/2022 ***WELL S/I ON ARRIVAL, DSO NOTIFIED*** (SET PATCH OVER PERFS) RIH W/ BAKER 45 Flo-Gard LOWER PACKER W/ NORTHERN SNAP LATCH RECEPTACLE. CORRELATE TO AK ELINE PPROF 14-OCT-2022. SET LOWER PACKER ELEMENT @ 9962'. TOP OF NORTHERN RECEPTACLE @ 9958.44'. BOTTOM OF MULE SHOE @ 9967'. MIN ID= 2.37". POOH & RIG DOWN ELINE. ***JOB COMPLETE / SL UP NEXT*** 12/15/2022 ***WELL S/I ON ARRIVAL*** HES UNIT 759 R/U. SET UPPER 45KB PACKER & PATCH ASSY TOP @ 9928' SLM ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE DSO NOTIFIED OF STATUS*** SET UPPER 45KB PACKER & PATCH ASSY TOP @ 9928' SLM BOTTOM OF MULE SHOE @ 9967'. POOH & RIG DOWN ELINE SET LOWER PACKER ELEMENT @ 9962'. Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221117 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 05-24A 50029222040100 204218 10/13/2022 AK E-Line PPROF MPU F-73A 50029227440100 200198 11/10/2022 READ CaliperSurvey Please include current contact information if different from above. 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38//(';;13/8*)520 0' :(//6,21'(3$5785( 7,2 7HPS 2$WRSMRESRVWULJ$/3 SVLRQOLQH )RXQG95SOXJLQFRPSDQLRQVLGHRI2$0L[HGJDOORQVRI)LQH&HP3RXUHG JDOORQVRIFHPHQWLQWR2$XQWLOFHPHQWZDVYLVLEOHRQWKHZRUNLQJVLGHRI2$ 5HSODFHGZLUHOHVVJXDJHZDQRORJ)LQDO:+3 V 69 &:966909 2,$2$ 27* '%-0' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221003 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF BRU 222-34 502832018600 222039 9/15/2022 Halliburton CH RBT BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT END 1-45 500292199100 189124 8/11/2022 Halliburton CH PERF KBU 22-06Y 501332065000 215044 8/22/2022 Halliburton CH PPROF KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG MPU L-46 500292355100 215118 9/10/2022 Halliburton CH MFC24 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 NS-10 500292298500 200182 8/18/2022 Halliburton CH WFL- TMD3D NS-32 500292317900 203158 8/17/2022 Halliburton CH WFL- TMD3D PBU 04-30 500292134500 185089 9/17/2022 Halliburton CH RMT3D PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST PBU 11-16 500292158100 186078 9/10/2022 Halliburton CH PPROF PBU 11-27A 500292163801 222036 8/20/2022 Halliburton CH RBT PBU C-24B 500292081602 212063 8/16/2022 Halliburton CH PPROF PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL PBU S-106 500292299900 201012 9/12/2022 Halliburton CH RBT Please include current contact information if different from above. T37103 T37104 T37105 T37106 T37107 T37108 T37109 T37110 T37111 T37112 T37113 T37114 T37115 T37116 T37117 T37118 T37119 T37120 PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 11:39:32 -08'00' 5HJJ-DPHV%2*& )URP3%:HOOV5:2:663%:HOOV5:2:66#KLOFRUSFRP! 6HQW6XQGD\6HSWHPEHU30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& 6XEMHFW7KXQGHUELUG5LJ%23WHVWIRUP'6:HOO$ $WWDFKPHQWV7KXQGHUELUG5LJ[OV[ WůĞĂƐĞƐĞĞĂƚƚĂĐŚĞĚ͘ dŚĂŶŬǇŽƵ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:Thunderbird 1 DATE: 9/18/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2042180 Sundry #322-165 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:2365 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" x 5M P Pit Level Indicators PP #1 Rams 1 2 7/8x5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 4-1/2" x 7"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 1 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 3 3 1/8"P Pressure After Closure (psi)1450 P Check Valve 0NA200 psi Attained (sec)21 P BOP Misc 0NAFull Pressure Attained (sec)131 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 3 @ 2200 P No. Valves 8P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 17 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9/16/2022 16:20 Waived By Test Start Date/Time:9/18/2022 1:00 (date) (time)Witness Test Finish Date/Time:9/18/2022 5:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Hilcorp Tested w/ 2 7/8 and 4 1/2 test mandrels and 7" test mandrel. Fluid used for testing was water. Matt Rivera/ Joshua Noel Hilcorp Alaska LLC. Anthony Knowles/Arvell Bass PBU 05-24A Test Pressure (psi): mrivera@thunderbirdfs.com pbrwowss@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0918_BOP_Hilcorp_Thunderbird1_PBU_05-24A 1RUWK6ORSH//& 9 9 9 9999 9 9 9 9 9 5HJJ-DPHV%2*& )URP3%:HOOV5:2:663%:HOOV5:2:66#KLOFRUSFRP! 6HQW6XQGD\6HSWHPEHU30 7R5HJJ-DPHV%2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ &F3%:HOOV5:2:66 6XEMHFW7KXQGHUELUG5LJ $WWDFKPHQWV7KXQGHUELUG5LJ[OV[ WůĞĂƐĞĨŝŶĚĂƚƚĂĐŚĞĚƚŚĞϭϬͲϰϮϰĨŽƌƚŚĞKWdĞƐƚƉĞƌĨŽƌŵĞĚŽŶϵͬϭϭͬϮϬϮϮŽŶǁĞůůϬϱͲϮϰďǇdŚƵŶĚĞƌďŝƌĚZŝŐηϭ͘ WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨƚŚĞƌĞĂƌĞĂŶǇƋƵĞƐƚŝŽŶƐ͘ ůŝtŝůƐŽŶ tĞůůƐŝƚĞ^ƵƉĞƌǀŝƐŽƌ Ğůů͗ϵϬϳͲϯϰϮͲϵϴϰϬ ZŝŐĐĞůů͗ϵϬϳͲϰϰϰͲϳϮϭϴ ,͗ϯϮ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:Thunderbird 1 DATE: 9/11/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2042180 Sundry #322-165 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/2500 Valves:250/3000 MASP:2365 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" x 5M FP Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 4-1/2" x 7"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 1 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 3 3 1/8"P Pressure After Closure (psi)1400 P Check Valve 0NA200 psi Attained (sec)12 P BOP Misc 0NAFull Pressure Attained (sec)124 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 3 @ 2933 P No. Valves 8P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 12 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:10.5 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9/9/2022 Waived By Test Start Date/Time:9/11/2022 0:00 (date) (time)Witness Test Finish Date/Time:9/11/2022 10:45 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Tested w/ 2 7/8", 4 1/2", and 7" test mandrels. Fluid used for testing was water. Annular failed (changed out annular element and re-test good). Adan Flores/Matt Rivera Hilcorp Alaska LLC. Anthony Knowles/Eli Wilson PBU DS5-24A Test Pressure (psi): bstiffler@thunderbirdfs.com pbrwowss@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0911_BOP_Thunderbird1_PBU_05-24A $ 1RUWK6ORSH//& 99 9999 9 9 9 9 9 9 - 5HJJ Annular failed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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): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well 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: Authorized Title: Authorized Signature with date: Contact Name: Contact Email: Contact Phone: PBU 05-24A Greenstick IC void Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-218 50-029-22204-01-00 12308 Conductor Surface Intermediate Production Liner 8933 80 9380 3087 9215 20" 7" 4-1/2" 8193 31 - 111 26 - 9406 9216 - 12303 31 - 111 26 - 8362 8194 - 8933 12172 470 5410 7500 9215 1490 7240 8430 9942 - 12210 4-1/2" 12.6# 13Cr80 27 - 9228 8729 - 8934 Structural 4-1/2" Baker S-3 Perm 9171 9171 8154 Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com (907)564-4891 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 13.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 0028325 4-1/2" Baker S-3 Perm 27 - 9228 8154 Greenstick IC test void Pumped approximately 12 cups to 3500 psi 340 0 563 0 2291 0 -750 0 309 0 n/a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Senior Pet. Engineer: Senior Res. Engineer: Form 10-404 Revised 3/2020 Submit Within 30 days or Operations By Samantha Carlisle at 8:17 am, Oct 04, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.10.01 15:05:55 -08'00' Bo York DSR-10/5/21 RBDMS HEW 10/7/2021 MGR15OCT2021 SFD 10/6/2021 ACTIVITYDATE SUMMARY 9/6/2021 T/I/O = SSV/40/40. Temp = SI. Green stick IC test void/Depress OA FL w/ N2 (eval SC leak). AL SI @ lateral valve, no IA companion valve. IA FL @ 6309' (sta#3 SO, 110 bbls. OA FL @ 100' (5.8 bbls). Stung into IC test port (38 psi), unable to bleed void to 0 psi. Torqued LDS to 650 lb/ft. Still unable to bleed void to 0 psi. Bled IAP & OAP to OT tank from 40 psi to 0 psi in 1.5 hrs. IC test void tracked OAP. Removed Alemite fittings and installed Hoke valves. Pumped 2.5 loads of Greenstick packing into test void, no returns from off side port. FWHP's = SSV/1/0. SV, WV, SSV = C. MV = O. IA & OA = OTG. 18:00. 9/7/2021 T/I/O = SSV/5/5. Temp = SI. Greenstick IC test void/ Depress OA FL w/ N2 (eval SC leak). AL SI @ lateral valve, no IA companion valve. IAP & OAP increased 5 psi over night. RU to Hoke valve on IC test port. Pumped 1.5 loads of Greenstick no returns from off side port. Switched to off side port, pumped 2 loads of plastic, got returns from off side port. Held 3500 psi on test void for 45 min, no loss of pressure. RU to OA w/ N2. OA FL @ 80'. Start OA FL depress. Used bottles of N2 to depress OA FL to 250'. FWHP's = SSV/7/100. SV, WV, SSV = C. MV = O. IA & OA = OTG. 18:30 9/8/2021 T/I/O = SSV/22/22. Temp = SI. WHP's/ OA FL (post green stick). AL SI @ lat valve. ALP = 22 psi, open @ CV, no IA companion. OA FL @ 114', OA inflowed 136' over night. OAP decreased 77 psi, IAP increased 15 psi over night. SV, WV, SSV = C. MV = O. IA & OA = OTG. 18:00. 9/11/2021 T/I/O = SSV/38/38. Temp = SI. WHP's/ OA FL (post greenstick). AL SI @ lat valve. ALP = 38 psi, open @ CV. No IA companion. IAP & OAP increased 16 psi. OA FL @ 84', OA inflowed 30' since 9/8/21. SV,WV,SSV = C. MV = O. IA & OA = OTG. 17:45. 9/15/2021 T/I/O = SSV/57/57. Temp = SI. Increase IAP to 100 psi (Eval SC leak). No IA companion valve. AL SI @ double plug valve. IA FL @ 6309' (#3, S/O). OA FL @ 140'. Used ALP to increase the IAP to 100 psi. During the IA increase the OAP remained unchanged. The IAP, IA FL, OA FL remained unchanged and the OAP increased 1 psi during the 30 minute monitor. FWPs = SSV/100/58. SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:00 9/26/2021 T/I/O=53/71/91 Load & Test IA / MIT IA to 2250 psi ( Max Appl = 2500 psi ) ( IC Leak / Bubbling @ surface ) Lube & bleed-- Load IA with 9.8# brine (inhibited). Pump diesel to pressure up to 2507 psi, & 3204 psi on tbg (Live GLVs in well) FWHPs=709/23/90. Appears to be thermal issues so DHD to return to attempt MIT again. 9/26/2021 T/I/O = 60/120/100. Temp = SI. Monitor OA FL & IC Test Void (Assist FB). No IA companion. AL SI @ lateral. TBG FL @ 40'. IA FL @ 250' (4.4 bbls). OA FL @ 240'. IC Test Void = 0 psi. Bled IAP to BT from 120 psi to 80 psi in 40 min. IA FL @ 6309' (#3 SO, 110 bbls). Monitored IC void and OA FL while LRS conducted CMIT- TxIA. Final OA FL @ 220'. LRS in control of well upon departure. 17:00 Daily Report of Well Operations PBU 05-24A Daily Report of Well Operations PBU 05-24A 9/27/2021 T/I/O = 860/180/100. Temp = SI. CMIT-TxIA to 2500 psi FAILED (Eval SC/PC leak). No IA companion. AL SI @ lateral. IA FL @ near surface. OA FL @ 220'. Used 4.4 bbls amb Diesel by pumping into the IA to pressure T/IA to 3188/2505 psi. T/IA decreased 89/91 psi in the 1st 15 min, and 46/53 psi in the 2nd 15 min. Extended additional 15 min. T/IA decreased 25/51 psi. Observed fluid drips coming from the IC LDS at the 2 o'clock position. Pressured T/IA to 3182/2500. On the 2nd attempt, T/IA decreased 26/50 psi in the 1st 15 min, and 14/47 psi in the 2nd 15 min for a total of 40/97 psi in 30 min. Bled IAP to 100 psi, torqued leaking LDS to 650 ft/lbs. Grease crew service WV and AL lateral. Used 2.3 bbls amb Diesel to pressure T/IA to 3182/2500 psi. LDS no longer leaking. On the 3rd attempt, T/IA decreaed 14/67 psi in the 1st 15 min, and 12/56 psi in the 2nd 15 min for a total of 26/123 psi in 30 min. Extend test 15 min. T/IA decreased 9/53 psi. Bled IAP to 100 psi (1.7 bbls). Bled TP to 700 psi (2 bbls). OA FL unchanged. Hung tags. Final WHPs = 700/100/100. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:40 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg � E AUG 2 [ 11 2. 2 _i Alaska Oil and Gas Conservation Commission I_ — 1 333 West 7 Avenue a© `T 1L Anchorage, Alaska 99501 o.— �. `Z r' Subject: Corrosion Inhibitor Treatments of GPB DS -05 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 05 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS -05 Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft ' bbls ft gal 05 -01C 1990280 50029201360000 Sealed conductor NA NA N/A N/A NA 05 -02A 2012410 50029201440100 Sealed conductor NA NA N/A N/A NA 05 -03C 2000940 50029201470300 Sealed conductor NA NA N/A N/A NA 05 -04A 1960890 50029201520100 Sealed conductor NA NA N/A N/A NA 05 -05B 1961800 50029201700200 Sealed conductor NA NA N/A N/A NA 05 -06A 1950840 50029201730100 0 NA 0 N/A N/A NA 05 -07 1770130 50029202430000 Sealed conductor NA NA N/A N/A NA 05 -08A 2100550 50029202480100 Sealed conductor NA NA N/A N/A NA 05 -09A 1990140 50029202540100 Sealed conductor NA NA N/A N/A NA 05 -10C 2070980 50029202630300 Sealed conductor NA NA N/A N/A NA 05 -11A 1960970 50029202520100 Sealed conductor NA NA N/A N/A NA 05 -12B 2011800 50029202440200 Sealed conductor NA NA N/A N/A NA 05 -13B 2071460 50029202500200 Sealed conductor NA NA N/A N/A NA 05 -14A 1930820 50029202530100 Sealed conductor NA NA N/A N/A NA 05 -15B 1960230 50029202550200 Sealed conductor NA NA N/A N/A NA 05 -16B 1991000 50029202620200 Sealed conductor NA NA N/A N/A NA 05 -17B 1981040 50029202710200 Sealed conductor NA NA N/A N/A NA 05 -18A 1981740 50029219600100 Split conductor NA NA N/A _ N/A N/A 05 -19 1890780 50029219620000 1.4 NA 1.4 N/A 8.5 4/11/2011 05 -20B 2042340 50029221370200 1.2 NA 1.2 N/A 5.1 4/18/2011 05 -21A 1981180 50029219690100 Dust Cover NA NA N/A N/A N/A 05 -22B 2071260 50029219760200 3.1 NA 3.1 N/A 18.7 4/17/2011 05 -236 2080610 50029219630200 1.2 NA 1.2 N/A 5.1 4/11/2011 .-.-2/ 05 -24A 2042180 50029222040100 1.5 NA 1.5 N/A 10.2 4/11/2011 05 -25C 2091240 50029219880300 6.0 NA 6.0 N/A 44.2 4/18/2011 05 -26A 2012210 50029219840100 0.5 NA 0.5 N/A 3.4 4/12/2011 05 -27B 2081910 50029219790200 Sealed conductor NA NA N/A N/A N/A 05 -28B 2060890 50029222080200 0.6 NA 0.6 N/A 1.7 4/10/2011 05 -30 1911150 50029222130000 1.2 NA 1.2 N/A 10.2 4/11/2011 05-31B 2100850 50029221590200 1.3 NA 1.3 N/A 6.8 4/12/2011 05 -32A 2020010 50029221900100 20.0 6.0 0.5 7/13/2011 3.4 7/23/2011 05 -33B 2100810 50029221680200 4.8 NA 4.8 N/A 37.4 4/27/2011 05 -34A 2080370 50029222170100 3.9 NA 3.9 N/A 18.7 1/4/2012 05 -35A 2081340 50029221720100 2.7 NA 2.7 N/A 18.7 4/18/2011 05 -36A 2050700 50029221820100 2.3 NA 2.3 N/A 13.6 4/12/2011 05 -38 1961850 50029227220000 1.8 NA 1.8 N/A 15.3 4/10/2011 05 -39 1961730 50029227150000 1.3 NA 1.3 N/A 10.2 4/10/2011 05-40 1961590 50029227070000 1.6 N/A _ 1.6 N/A 16.2 1/10/2012 05-41A 2031700 50029226960100 5.0 NA 5.0 N/A 58.7 1/8/2012 STATE OF ALASKA RECEIVED ALAI" OIL AND GAS CONSERVATION COM ION AUG 1 4 2012 REPORT OF SUNDRY WELL OPERATIONS AOGC 1. Operations Abandon ❑ Repair Well U Plug Perforations L Perforate U Other U - Bridge Plug Pull Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ M' (( gee Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 • Exploratory ❑ 204 -218 -0 ' 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22204 -01 -00 ' 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028325 • PBU 05 -24A • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL • 11. Present Well Condition Summary: Total Depth measured 12308 • feet Plugs measured None feet true vertical 8932.58 • feet Junk measured 12172 feet Effective Depth measured 12217 feet Packer measured 9171 feet true vertical 8934.32 feet true vertical 8153.65 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 31 - 111 31 - 111 1490 470 Surface 3854 10 -3/4" 45.5# J -55 30 - 3884 30 - 3513.09 3580 2090 Intermediate None None None None None None Production 9380 7" 26# L -80 26 - 9406 26 - 8361.52 7240 5410 Liner 3087 4 -1/2" 12.6# L -80 9216 - 12303 8194.06 - 8932.67 8430 7500 Perforation depth Measured depth See Attachment feet , ®� i ' ?' ) AUG 2 0 ZU1 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 27 - 9228 27 - 8204.83 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm 9171 8153.65 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 416 21061 260 0 2118 Subsequent to operation: 1072 50221 639 0 968 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory El Development Ei • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 • Gas ❑ WDSPL u 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: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summe ays Title Petrotechnical Data Technician Signatur- , IMAI .Li /� ..... Phone 564 -4035 Date 8/13/2012 Form 10 -404 Revised 10/2010 ReDMS �` ,� ,� /b f� Submit Original Only , t . t 44. • Daily Report of Well Operations ADL0028325 ACTIVITYDATE ( SUMMARY + U U :. cope - pro i e mow ca ica ion. mis art + i mg - - ump we i wi . KCL / safelube.RIH w/ 3.13" ctc,3.13" dcv, 3.13" jars,3.38" disco,3.13 "circ sub,3.13" motor,3.68" junk mill. Dry tagged plug @ 10096' ctm PUH get free spin start milling on CIBP. Milling out CIBP push to bottom. Pushed CIBP to 12185' (down)- ctm. PUH to 10000' RBIH for dry tag of CIBP. Had various tags, worked past, no overpulls. Drifted clear to 12181' down/12172' up. FP coil. POOH. Tag up, 3/14/2012 continued on 03/15/12 WSR. Continued from 03/13/12 WSR. Scope - profile modification. Finish R/U MU Milling BHA. Pump well kill with KCL /safelube.RIH w/ 3.13" ctc,3.13" dcv, 3.13" jars,3.38" disco,3.13 "circ sub,3.13" motor,3.68" junk mill. Dry tagged plug @ 10096' ctm PUH get free spin start milling on CIBP. Milling 3/14/2012 out CIBP push to bottom. Pushed CIBP to 12185' ctm. PUH to 10094' RBIH for dry tag of CIBP Continued from 03/14/12 WSR. Scope - profile modificaiton /mill CIBP. Tag up /rig down. Job is 3/15/2012 complete. Well is ready to POP. Switch to weather standby, due to low ambients. FLUIDS PUMPED BBLS 236 1% KCL with 0.6% SAFELUBE 89 60/40 METH 388 1% SL KCL 713 TOTAL • • • Perforation Attachment ADL0028325 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 05 -24A 2/12/05 APF 9942 9952 8729.07 8735.41 05 -24A 2/9/08 BPS 10081 12210 8753.73 8871.33 05 -24A 4/10/08 BPP 10081 12210 8753.73 8871.33 05 -24A 1/1/09 BPS 10081 10335 8753.73 8853.88 05 -24A 3/14/12 BPP 10081 10335 8753.73 8853.88 05 -24A 11/27/04 PER 10335 10505 8853.88 8869.18 05 -24A 11/27/04 PER 10740 10960 8879.37 8886.76 05 -24A 11/27/04 PER 11000 11040 8887.73 8888.6 05 -24A 11/27/04 PER 11330 11350 8894.4 8892.81 05 -24A 11/27/04 PER 11440 11560 8885.85 8881.61 05 -24A 11/27/04 PER 11800 11930 8879.09 8876.38 05 -24A 11/27/04 PER 12100 12210 8872.56 8871.33 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF P M TREE = FMC III WELLHEAD - FMC "0 NOTES: WELL ANGLE> 70o @ 10222'. ACTUATOR = BAKER C 05-24A "'4 -1M" CHROME TBG"" KB. ELEV = 70' BF.ELEV= ? KOP = 1000' 2178' — 14-12" HES X NIP, ID = 3.813" Max Angle = 95 @ 11371' 1 GAS LIFT MANDRELS Datum ND= 10041' ST MO TVD DEV TYPE VLV LATCH PORT DATE Datum 1VD = 880(Y SS 5 3282 3005 33 KBG -2 DOME BK 16 12/22/04 4 4984 4490 24 KBG -2 SO BK 20 12/22/04 TOP OF CEMENT PLUG (11/06/04) H 3575' t ∎• � ' 3 6309 5663 31 KBG -2 DMY BK 0 11/28/04 110 -3/4" CSG, 45.5 #, J -55, ID = 9.950" H 3891' '., �� D 2 7468 6641 31 KBG -2 DMIY BK 0 1128/04 1 8456 7511 29 KBG -2 MY BK 0 11/28/04 Minimum ID = 3.726" @ 9216' ► * 1 4 -1/2" HES XN NIPPLE % 1 1 . 1 SIDETRACK OFF 17 -5/8" CSG, 29 7 #, .0458 bpf, ID = 6.875" --- — 3950 I ► � � C M T PLUG 3950' 11 111111111. ■•• 111111111 7 -5/8" EZ SV PLUG (11/07/04) --I 4100' ••1.1.1 ".1.1.1.1.1.1.1 'TOP OF CEMENT PLUG (11/08/04) H UNKNOW N? 0......."....0.0 •1 I I 9150' I—{4 1/2" HES X NIP, ID = 3.813" 17-5/8" EZSV PLUG (11/07/04) H 6465' � . 1 1 • Z , ■ I 9171' I-1 X 4 -1 /2" BKR S3 PKR, ID = 3 875" I I 9194' I-14-1/2" HES X NIP, ID = 3.813" I I 9215' H4-1/7' HES XN NIP, ID = 3.725" I I ------ 9 216' 7" X 4 -12" LNR TOP PKR 14-1/2" TBG, 12.6#, 13CRVAM TOP, .0152 bpf, ID = 3.958" H 9228' I 1 TIEBACK SLV, ID = 4.39" 9228' H4-1/2" WL EG, ID = 3.958" 9238' H7" X 5" BKR LNR HNGR, ID = 4 430" I 17' CSG, 26 #, L -80 BTG M( ID = 6.276" H 9406' , ■ 9248' H5" X 4 -112" XO, ID = 3.980" I I PERFORATION SUMMARY REF LOG 777 I ANGLE AT TOP PERF: 51 @ 9942' Note: Refer to Roduction DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 2 -7/8" 6 9942 - 9952 0 02/12/05 I 2 -7/8" 6 10335 - 10505 0 11/28/04 2 -7/8" 6 10740 - 10960 0 11/28/04 I 2 -7/8" 6 11000 - 11040 0 11/28/04 2 -7/8" 6 11330 - 11350 0 1128/04 2 -7/8" 6 11440 - 11560 0 11/28/04 I 2 -7/8" 6 11600 - 11730 0 11/28/04 2 -7/8" 6 11800 - 11930 0 1128/04 I 2 -7/8" 6 12100 - 12210 0 1128/04 ' L 12172' I— FISH - GBP - MILLED & PUSHED PBS 12217' I ••• • TO BOTTOM (03/15/12) 1 4 -112" LNR, 12.6#, L -80 IBT -M, .0152 bpf, ID = 3.958" H 12302' DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 08/22/91 _ ORIGINAL COMPLETION 04 /15/08 KSB/PJC PULL WRP(04 /10/08) WELL. 05 -24A 05/23/93 LAST WORKOVER 01/12/09 JKD/SV SET CIBP (01 /01/09) PERMIT No: 2042180 11130/04 N2ES SIDETRACK (05 -24A) 03/15/12 JKGJMC FISH: MILLED GBP (03/15/12) API No: 50- 029 - 22204 -01 12/23/04 G.;B/PJC GLV GO 03/28/12 PJC DRAWING CORRECTIONS SEC 32, T11 N, R15E 4866.57 FEL 2400.84 FNL 0825100 ITLH DRLG DRAFT CORRECTIONS 02/18/08 TFA/PJC SET WRP (02/09/08 BP Exploration (Alaska) STATE OF ALASKA RECEIVED ALA. OIL AND GAS CONSERVATION COMMIIIIION REPORT OF SUNDRY WELL OPERATIONS AUG 1 4 2012 1. Operations Abandon U Repair Well U Plug Perforations U Perforate ❑ Other LAOGCG Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ill Exploratory ❑ - 204 -218 -0 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50-629-22204-01-00 • 7. Property Designation (Lease Number): ., 8. Well Name and Number: ADL0028325 • PBU 05 -24A . 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): - To Be Submitted PRUDHOE BAY, PRUDHOE OIL • 11. Present Well Condition Summary: Total Depth measured 12308 • feet Plugs measured 10100 feet true vertical 893P.58 , feet Junk measured None feet Effective Depth measured 10081 feet Packer measured 9171 feet true vertical 8816.83 feet true vertical 8153.65 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 31 - 111 31 - 111 1490 470 Surface 3854 10 -3/4" 45.5# J -55 30 - 3884 30 - 3513.09 3580 2090 Intermediate None None None None None None Production 9380 7" 26# L -80 26 - 9406 26 - 8361.52 7240 5410 Liner 3087 4 -1/2" 12.6# L -80 9216 - 12303 8194.06 - 8932.67 8430 7500 Perforation depth Measured depth See Attachment feet klikike AUG20Z r4, True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 27 - 9228 27 - 8204.83 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm 9171 8153.65 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 665 38859 2710 0 1618 Subsequent to operation: 632 35817 2354 0 1635 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development El s Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ' 0 • 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: N/A Contact Nita Summerhays Prepared by Nita Sumemrhays 564 -4035 Printed Name Nita Summerhays Title Petrotechnical Data Technician Si • . ,.. , `'"' 1i. -E.-_. Phone 564 -4035 Date 8/13/2012 i f) \ v Form 10 -404 Revised 10/2010 RB3DMS AUG 15 2,01a01 �'1 Z..-- Submit Original Only 1 ,‘,7 • • Daily Report of Well Operations ADL0028325 ACTIVITYgATE 4l. it -i - ∎ - s 1. - v • T /I /O = 2100/500/100. SET 4.5" EZ DRILL SVB CAST IRON BRIDGE PLUG. 3.66" MAX OD X 25.13" LONG. WITH 5.83' SHORTY SETTING TOOL, CCL, 2.125 WEIGHT, 2.125 WEIGHT, ERS, MH22. MID ELEMENT SET DEPTH = 10100'. WELL SHUT -IN UPON DEPARTURE. VALVES LEFT AS FOUND. DSO NOTIFIED. FINAL T /I /O = 2100/500/0 PSI 1/1/2009 ***JOB COMPLETE* * ** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL • • Perforation Attachment ADL0028325 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth ND Depth Name Date Code Top Base Top Base 05 -24A 2/12/05 APF 9942 9952 8729.07 8735.41 05 -24A 2/9/08 BPS 10081 12210 8753.73 8871.33 05 -24A 4/10/08 BPP 10081 12210 8753.73 8871.33 05 -24A 1/1/09 BPS 10081 10335 8753.73 8853.88 05 -24A 11/27/04 PER 10335 10505 8853.88 8869.18 05 -24A 11/27/04 PER 10740 10960 8879.37 8886.76 05 -24A 11/27/04 PER 11000 11040 8887.73 8888.6 05 -24A 11/27/04 PER 11330 11350 8894.4 8892.81 05 -24A 11/27/04 PER 11440 11560 8885.85 8881.61 05 -24A 11/27/04 PER 11800 11930 8879.09 8876.38 05 -24A 11/27/04 PER 12100 12210 8872.56 8871.33 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF . 0 ~ • • WBS ` 4AJL°T11[YT>!s "C ►f�JMR ;t T11G'" 0,,5-24A �9" A 1022 . tt r Nei Y t= ': i 2 Wr t E. s I % .. S l" . tea eft . .SS t . s 45,3' " H �1� e . , . : , 1 WI _ . :� ::31444' tW`. _ ii,t Mnmwn10 = Ins 4 92,5' ! Y 4 >112" HES XN NILE 41 41:t1,(..:: ; ,ie -Ai Y ?}, i , + 4100' „Y... I Mil 71 •, i 9111' H- ' 4 '- 5, . , I r � ° _ r I r 919 H4 r E. t. 5 I UA 1 [- r _- H s14_ }-- I . I l i . . . , ,. ,._,...,t --- \ I .22ft 1 E_____, I `, v t Y -CR [ 1 /f/2 I ARimYi ill �- low 1---1, '. 'c_ r L - �.� - !� ±7CR VAN TOP. .9TS2sa1 iU =14514' _._..". E'' I1 1 • t '” us.a :15 #.. 9 = "'w 1,t. t .. ;' r{ Nor 11 ' , ;4: r- r, 'At WV?? e ., w: •ae. 3.; „:y.c tt40 4 . tars y ■ _ H I n i . r a ® 1221T i - OWN. 61.011111111110=1011111111101. INEAMMINAMONIIIIIIIISLUM .=, I p aA? tit; Iv sisaj . iiii...miii6j..5 , 4 - amiat:I=miiiiiii , . wislinum z.:.-,,,T, ,-... ,, „: , Questions? Please Contact James Russell 907 -564 -4729 (office) or 208 -596 -1434 (cell) -:~~:" • ~~~~,,> '' MICR.CJFILMED 03/0112008 DO N4T PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\I.aserFict~\CvrPgs_Inserts\Microfilm A~arke~:doc <Àq b~ t- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2042180 Well Name/No. PRUDHOE BAY UNIT 05-24A Operator BP EXPLORATION (ALASKA) INC ) p ~ I Co( t1P\v ~1 API No. 50-029-22204-01-00 MD 1230V'" TVD 8933 /' Completion Date 11/29/2004 Completion Status 1-01L Current Status 1-01L UIC N --- --~-~.~~~~~~ -~,~---,---- --~._-- _._--~------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~~ ~-~-~._~ -~ -~~-~-~..- DATA INFORMATION Types Electric or Other Logs Run: MWD DIR 1 GR 1 RES I PWD, MWD DIR 1 GR 1 RES ABI Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr Data Digital Dataset ~ MedlFrmt Number Name D Asc Directional Survey D Asc Directional Survey ~ Neutron :z D Lis 13207 I nd uction/Resistivity 13207 LIS Verification I c..ÉD C Lis 13371 I nd uction/Resistivity ~ C Lis 13592 I nd uctionlResistivity Well CoreslSamples Information: Interval Name Star! Stop Log Log Run Interval OH/ . Scale Media No Star! Stop CH Received Comments 3884 12308 1/2712005 IIFR -1 3884 12308 1/27/2005 MWD I 2 Slu 9216 10282 2/3/2005 cnllmemory grlccllstp I 3839 12253 Open 717/2005 GR ABI PWD ROP I 3839 12253 Open 717/2005 GR ASI PWD ROP 9265 10276 Case 11/21/2005 GR,CNT,Neutron 22-Dec- 2004 3891 12308 Open 2/22/2006 ROP DGR EWR plus Graphics Sample Set Sent Received Number Comments . Daily History Received? Jrr¡ Formation Tops ~N ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? - Y II.J Analysis ~ Received? -~---"--~~-- ---- ~~------------~~ ~~.~ Comments: - ~--~------'~"- Permit to Drill 2042180 MD 12308 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Well Name/No. PRUDHOE BAY UNIT 05-24A 8933__t~PG-t' . W2912004 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22204-01-00 Completion Status 1-01L Current Status 1-0l.!;[) , UIC N Date: -----0)) 0 "L 2- ~~ ,b . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 1359;). RE: MWD Formation Evaluation Logs 05-24A, 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 05-24A: LAS Data & Digital Log Images: 50-029-22204-01 c9ó4" ~ t} Ô 1 CD Rom (!:fQéilQ-ev >1 dfJ/D& . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 7,2005 RE: MWD Formation Evaluation Logs: 05-24~ AK-MW-3374225 1 LDWG fonnatted Disc with verification listing. API#: 50-029-22204-01 }3¡ò7 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITIAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ Date: I ¥ ~ \_. tLJ Ûj¡~ Signed: )Zl; '-{ - 'Æl P F: 1-<- 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D . STATE OF ALASKA . RECE\VE.O ALASKA OIL AND GAS CONSERVATION CO.SSION , '200'5' .. ~R1 y¡ REPORT OF SUNDRY WELL OPERATION:) " ",,",ísSlon ..A\asKa Oil & GíJ~ COM, \;1) Stimulate L.J Ancho~rD WaiverD Time ExtensionD Re-enter Suspended WellD Repair Well 0 Pull TubingD Operation ShutdownD Pluq PerforationsD Perforate New Pool D Perforate IKJ 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] ExploratoryD 5. Permit to Drill Number: 204-2180 6. API Number 50-029-22204-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (It): 63.10 8. Property Designation: ADL-028325 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: 05-24A 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool Total Depth measured 12308 feet true vertical 8932.6 feet Effective Depth measured 12217 feet true vertical 8934.3 feet Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 31 111 31.0 111.0 1490 470 Liner 20 7 Inch 26 Lb L-80 9216 - 9236 8194.1 - 8212.0 7240 5410 Liner 3067 4·112" 12.6# L-80 9236 - 12303 8212.0 - 8932.7 8430 7500 Production 9380 7" 26# L-80 26 . 9406 26.0 - 8361.5 7240 5410 Surface 3854 10-3/4" 45.5# J-55 30 - 3884 30.0 - 3513.1 3580 2090 Measured depth: 9942 - 9952,10335 -10505,10740 -10960,11000 -11040,11330 -11350,11440 -11560,11800 -11930 True vertical depth: 8729.07 - 8735.41,8916.98 - 8932.28,8942.47 - 8949.86,8950.83 - 8951.7,8957.5 - 8955.91,8948.95 - 8944.71 8942.19 - 8939.48 Tubing ( size, grade, and measured depth): 4-112" 12.6# 13Cr80 @ 27 9228 Packers & SSSV (type & measured depth): 4-112" Baker S-3 Hydro Set Packer @ 9171 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 472 431 Representative Dailv Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 3.6 3102 1900 3.3 2857 1850 Tubing Pressure 217 288 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class alter proposed work: ExploratoryD 16. Well Status alter proposed work: Oil[!] GasD DevelopmentOO ServiceD Contact Printed Name Garry Catron Garry Catron Jdc~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Production Technical Assistant Signature eàÞ~ Phone 564-4657 Date 4/13/05 Form 10-404 Revised 4/2004 Mtrns If (,},9 t3S . . 05-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/12/05 Perforate 9942'-9952' 6 SPF FLUIDS PUMPED BBLS No Fluids Pumped o ITOTAL Page 1 ~ 05-24A Preeent Completio. FROM - D TREE = WELLHEA D = >-··'·'··W_··~,·'mmmnmmm···'····W·Å·_·_·_·_·_¥_m_·n_·_WN"_ A CTUA TOR == KB. ELEV = BF. ELEV = FMC FMC "'Å'_~A-_~-__~=nmmn SA KER C 70' ? 3950' 95@ 11370' 10041' 8800' 55 I. 2, 177' H 4 1/2" 'X' landing nipple, ID == 3.813" , Max Angle == Datum MD = ~~~~ Datum TVD == l1Q.314" CSG.,4S·5#'H 3891' I J-55, ID == 9.950" , 175../8" EZSV Bridge H 4 100' I plug , TOPOFSAND H V 1-- 9000' \75/8", 29.7#, L-BO H Casing to. == 6.875" 1 1 . . - 9583' 151/2", 1~#, 13~r-io'IÎ 10286' I hner tD.-4.892 d DA TE REV BY COMAENTS 08122/91 ORIGINAL COMPLETION 05/23/93 LAST WORKOVER 0~05J02 RNnP CORRECTIONS 03114/04 DAVITlH GLV ClO 05/16/04 fWElKAK DUMP SAND; FISH 05127/04 MJA/KAK CHEtvI CUTTBG DATE 09/22/04 11129/04 12123/04 REV BY I 3,950' HSidetrackOff cement plug GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 5 3282 3004 33 KBG DOME BEl< 16 12/23/04 4 4984 4489 23 KBG SO BK 20 12/23/04 3 6309 5663 31 KBG DMY BK 0 2 7468 6640 30 KBG DMY BK 0 1 8456 7510 29 KBG DMY BK 0 \ o 0........ o 0 o 0 1 9,149' H41/2" 'X' landing nipple, 10 == 3.813" I f 9,170' H 7" X 4 1/2" Baker s..3 packer I 9,193' H41/2" 'X'landing nipple. 10= 3813" 1 9,214' H4 112" 'XN' landing nipple, ID == 3.75" I I 9227' HWLEG41/2".12.6#,13cr-ao,vAMTC I 9,221' 11· 7" X 5" Baker Flex-Lock Lnr hngr I and ZXP pkr w ith TBS ""'~.œ 1-(7',æ#, L-IDBlGM I Jeridntervals @ 6 SPF: 10335' -10505' 10740' -10960'; 11000' -11040'; 11330' -11350'; 11440' -11560'; 11600'-11730'; 11800' - 11930'; 12100' - 12210' o 0 0 0000000 o 0 0 0 0 0 000 o 0 o 0 o 0 I 12,287' H4112". 12.6#, L-80, IBT-Msolid liner I COWMENTS PRUDHOE BA Y UNIT WELL: 05-24A ÆRMIT No: API No: 5Q.029-22204-01 SEe 32, T11 N. R1SE 4866.57 FEL 2400.84 FNL dew Proposed completion RB Present Completion GJB/PJC GLV ClO BP &ploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . Well Job # /r¡/?~I7C C-29A 10715422 /'1'7-1'3; E-25 10715423 !q~~(jz.'J. G-02A 10715424 'liJf,,/W W-27A 10670031 "8-014 D-25A r<_ 10854314 ,:eN-ObI,¡ DS 15-25A' '", 10715428 ~.Ø"'E-39A '\ 10715430 02-16B 10928597 I 9tj- () 11 C-25A 10928598 ;2DL{.~1 E-17A 10928602 1.t:4-ICó~ .C-41A j 10928606 ~~~¡~~ ~~:~~: ~~~~~::~ hfr.i~{ 02-28A 10928607 ''tytf63 - D-11A 10928608 ""'. DS 05-24A 10928609 (Prints~ only-Job not complete) (;¿~?~- :< !;y/ 01/24/05 NO. 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 08/20/04 1 08/21/04 1 08/23/04 1 08/24/04 1 08/27/04 1 09/11/04 1 09/13/04 1 10/02/04 1 10/03/04 1 10/30/04 1 11/24/04 1 12/09/04 1 12/11/04 1 12/11/04 1 12/16/04 1 12/22/04 1 MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL 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: ~~¡0j Alaska Data & Consulting Services 2525 Gambell Street, SUilJY400,' , ,í£ Anchorage, AK~950 2á38 /J) ATTNC ~I ß' 1:/ , / ¡ /,¿,"'" i,' ~ Rece' .i3d by: J't".. . '1// , {I . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 5-24A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 3,884.50' MD 3,891.00' MD 12,308.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE I ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 A1 / 11 Date) ì )""'- -Zt1 \- Signed ~ ûlLI Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 01-Jan-05 ~ a'-/ -).18 . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 5-24A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 3,884.50' MD 3,891.00' MD 12,308.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ') ì J(>" ¡À ~)' Signed ~ o~~j Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 01-Jan-05 ~o tj .., J..{g' ... _ STATE OF ALASKA .. ALAS~IL AND GAS CONSERVATION CO~SION . .. .. ...... .... WELL COMPLETION OR RECOMPLETION REPORT AND LOGRECE,,/ED .IAN 0 '1 2005 1b. Well Class: .. '"', ."'.S¡O';~ II 1000r&tìadíli!lþl&HRõf))'" [:::J~f¡graPhJl'\cQ~ice 12. Permit to Orill Number 204-218 13. API Number 50- 029-22204-01-00 14. Well Name and Number: PBU 05-24A 15. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool No. of Completions 1a. Well Status: Da Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2203' NSL, 1194' EWL, SEC. 32, T11N, R15E, UM Top of Productive Horizon: 3109' NSL, 530' EWL, SEC. 33, T11N, R15E, UM Total Depth: 1697' NSL, 1774' EWL, SEC. 33, T11N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 698282 y- _~..!3.!8~97 Zone- ASP4 TPI: x- 702870 y- 5949426 Zone- ASP4 Total Depth: x- 704155 y- 5948048 Zone- ASP4 ---.-~_.~-- 18. Directional Survey Da Yes DNo 21. Logs Run: MWD DIR 1 GR 1 RES 1 PWD, One Other 5. Date Comp., Susp., or Aband. 11/29/2004 6. Date Spudded 11/12/2004 7. Date T.D. Reached 11/25/2004 8. KB Elevation (ft): 63.10' 9. Plug Back Depth (MD+ TVD) 12217 + 8934 10. Total Depth (MD+TVO) 12308 + 8933 11. Depth where SSSV set (Nipple) 2178' MD 19. Water depth, if offshore N/A MSL CASING SIZE 20" 10-3/4" MWD DIR 1 GR / RES ABI CASING, LINER AND CEMENTING RECORD SETtiNG DEPTH MD SElTINGDEPTK TVÖ HOLE Top BOTTOM 'lOP BOTTOM SiZe: Surface 110' Surface 110' 30" Surface 3891' Surface 3519' 13-1/2" 29' 9406' 29' 8362' 8-3/4" 9216' 12303' 8194' 8933' 6-1/8" 22. WT. PER FT. 91.5# 45.5# 26# 12.6# GRADE H-40 J-55 L-80 L-80 7" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Gun Diameter, 6spf MD TVD MD TVD 10335' - 10505' 8917' - 8932' 10740' - 10960' 8942' - 8950' 11000' - 11040' 8951' - 8952' 11330' - 11350' 8958' - 8956' 11440' - 11560' 8949' - 8945' 11600' - 11730' 8944' - 8944' 11800' - 11930' 8942' - 8939' 12100' - 12210' 8936' - 8934' 26. Date First Production: December 13, 2004 Date of Test Hours Tested 1/1/2005 6 Flow Tubing Casing Pressure Press. 261 1,320 24. SIZE 4-1/2", 12.6#, 13Cr80 25. Ft Ft 16. Property Designation: ADL 028325 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 11 Yards Arcticset 1300 sx CS III, 350 sx 'G', Top Job: 184 sx CS II 271 sx Class 'G', 198 sx 'G' 370 sx Class 'G' TUBING Re:OORD DEPTH SET (MD) 9228' PACKER SET (MD) 9171' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oil -BBl GAs-McF W A TER-BBl 105 695 464 PRODUCTION FOR TEST PERIOD + CALCULATED + 24-HoUR RATE Oll-BBl 422 GAs-McF 2,781 WATER-BBl 1,855 CHOKE SIZE I GAS-Oil RATIO 90.22 6,598 Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None {'(>, '. ø4¥~ !.Vf1iÎ:/ Form 10-407",i~f4fJfi:t2f2Ðo3 OR \ G\ NAL CONTINUED ON REVERSE SIDE RBDMS BFL JAN -0 2005 f~ l0 28. GEOLOGIC MARK. 29. .FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 9402' 8358' None Shublik 9437' 8388' Sadlerochit 9519' 8455' Top CGL / Zone 3 9745' 8605' Base CGL 1 Zone 2C 9830' 8658' 23SB 1 Zone 2 Bu 9959' 8740' 22TS 1 Zone 2 BI 9989' 8759' 21TS 1 Zone 2A 10062' 8805' Zone 1B 10165' 8867' TDF / Zone 1A 10300' 8911' Base Sadlerochit 11136' 8955' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~.Mù ~ ~ Title Technical Assistant PBU 05-24A 204-218 Well Number Date Qt !O&, (05 Permit NO.1 Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None.". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Name: 05-24 Common Name: 05-24 11/12/2004 FIT 11/18/2004 FIT 2,292 (psi) 12.53 (ppg) 4,474 (psi) 10.30 (ppg) . . Printed: 12/6/2004 10:55:19 AM 500 (psi) 826 (psi 9.80 (ppg) 8.40 (ppg) 3,520.0 (ft) 8,360.0 (ft) 3,945.0 (ft) 9,426.0 (ft) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 10/31/2004 05:30 - 00:00 18.50 MOB P PRE Blow Down And Disconnect Utilities Between Pit Complex And Sub Base - Move Cuttings Tank - Lower Cattle Shoot - Lay Mast Over And Pull Sub Base Off Of Well - Have Pre-Job Safety Meeting With Security, CPS, And Rig Team. Move rig to 5-24A 11/1/2004 00:00 - 04:30 4.50 MOB P PRE Transport sub from J Pad to DS 5. Prep and spot sub. Camp and pits left J Pad at 01 :30. 04:30 - 06:00 1.50 RIGU P PRE Set welding shop. Set mats and pits. 06:00 - 10:00 4.00 RIGU P PRE Troubleshoot SCR's. 10:00 - 12:00 2.00 RIGU P PRE Raise and pin derrick. Raise cattle shoot. Bridal down. Spot shop. 12:00 - 15:00 3.00 RIGU P PRE Spot cuttings tank and berm same. Rig up floor, spot shop landings. 15:00 - 15:30 0.50 P DECOMP Hold pre-operation HSE and PJS meeting with WSL, TP and all crew/drivers. Rig accepted for well work at 15:00 hours. 15:30 - 16:00 0.50 RIGU P DECOMP Install gauges and take pressure readings. OA = 0 psi IA = On Vac. Tbg = 0 psi 16:00 - 16:30 0.50 WHSUR P DECOMP Rig up DSM lubricator. Pull BPV. Rig down DSM. 16:30 - 20:30 4.00 CLEAN P DECOMP Rig up and test lines to 3,500 psi. Reverse circ 35 bbls fresh water. No retums noted. Change lines to pump down tubing. Pump 45 bbl soap spacer down tubing and displace well to 9.8 NaCI at 4 bpm. Taking all retums through choke to cuttings tank. Had retums during circulation. After shutting pumps down, tubing and well on vacuum. 20:30 - 21 :00 0.50 EVAL P DECOMP FMC dry rod BPV. Attempt to test from below. Filled void at 5 bpm at 200 psi. At 11 bbls away noted a 100 psi increase. Observed BPV and no leaks seen. Shut pumps down. 21 :00 - 22:30 1.50 WHSUR P DECOMP Bleed off control line pressure. Nipple down tree and adapter and remove same from cellar. Screw XO into hanger. 22:30 - 00:00 1.50 BOPSUR P DECOMP Install blanking plug. Install DSA and nipple up BOPE. 11/2/2004 00:00 - 01:30 1.50 BOPSUR. P DECOMP Continue Nipple Up BOPE. 01 :30 - 08:00 6.50 BOPSUR. P DECOMP Make uplLay down 4.5" test joint. Test BOPE to 250 psi Low 1 3,500 psi High, Annular tested to 250 psi Low - 2,500 psi High. Tested stack with both 4.5" and 3.5" test joints. Test witnessed by AOGCC Rep., John Crisp. 08:00 - 08:30 0.50 BOPSUR. P DECOMP Blow down all lines. Pull blanking plug. Break and lay down test joints. 08:30 - 09:30 1.00 WHSUR P DECOMP Make up lubricator. Pull BPV. Lay down lubricator. 09:30 - 10:30 1.00 PULL P DECOMP Rig up to pull completion tubing. 10:30 - 11 :00 0.50 PULL P DECOMP Make up landing joint and make up to hanger. 11 :00 - 13:30 2.50 PULL P DECOMP Attempt to pull tubing free. No success. Max pull 225K. Hole fill on fresh water. 13:30 - 15:00 1.50 PULL P DECOMP Land hanger. Lay down drill pipe landing joint. Change out bales and elevators. Pick up 4.5" tubing landing joint. Make up XO's and safety valve. Make up landing joint to hanger. 15:00 - 16:00 1.00 PULL P DECOMP Establish overpulllstretch measurements. Pick up and set slips. 165K Up Weight. 50K overpull. Circulate over top of hole with fresh water with hole fill pump. Losses average 1 Printed: 12/6/2004 10:55:25 AM Legal Welf Name: Common Welf Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 . REENTER+C<DMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 11/2/2004 15:00 - 16:00 1.00 PULL P DECOMP BPH. 16:00 - 18:30 2.50 PULL P DECOMP PJSM with SWS and crew. Rig up e-line tools. 18:30 - 20:00 1.50 PULL P DECOMP Run in hole with chemical cutter. Make cut at 8,830'. E-line had good indication of cutter firing, no reaction at surface. 20:00 - 21 :30 1.50 PULL P DECOMP POOH with chemical cutter. PJSM prior to laying down cutter head. When tool out of hole noted half of firing head and bottom centralizer left in hole. Length of fish -2.5'. 21 :30 - 22:30 1.00 PULL P DECOMP Make up XO and TDS. Work tubing with 225K maximum up weight. Tubing not free. Break circulation at 6 BP, 300 psi and continue to work pipe. No success. Disconnect and blow down TDS. 22:30 - 23:30 1.00 PULL P DECOMP PJSM. Rig up SWS to RIH with free point. 23:30 - 00:00 0.50 PULL P DECOMP RIH on e-line with free point BHA. Problem with e-line rubbing TDS. Note: Losses at midnight averaging 1 BPH 11/3/2004 00:00 - 02:30 2.50 PULL P DECOMP SWS wire rubbing TDS due to close proximity of entry sub to TDS. POOH with wireline. Break entry sub and XO's. Make up side entry sub. 02:30 - 03:30 1.00 PULL P DECOMP RIH with free point tools to 3,200' and calibrate. 03:30 - 04:30 1.00 PULL N DFAL DECOMP SWS tool failure. Anchors not setting properly. POOH to change out tool. 04:30 - 07:30 3.00 PULL N DFAL DECOMP SWS troubleshooting tools. Tools OK. Found dead ground in wire. Troubleshooting same. 07:30 - 13:30 6.00 PULL P DECOMP SWS running free point. Established 100% stuck at 6,895' and 98% free at 6,825'. 13:30 - 14:30 1.00 PULL P DECOMP POOH with wireline and lay down free point tools. 14:30 - 15:30 1.00 PULL P DECOMP Break off and lay down side entry sub and DP single. 15:30 - 16:30 1.00 PULL P DECOMP Make up SWS tubing punch tools. 16:30 - 19:30 3.00 PULL P DECOMP RIH with tubing punch tools and perf 3.5" tubing from 8,470' to 8,472.5'. POOH and lay down punch tools. 19:30 - 22:00 2.50 PULL P DECOMP PJSM. Make up string shot tools. 22:00 - 23:30 1.50 PULL P DECOMP SWS RIH with string shot. Top of shot at 8,439', bottom at 8,451'. POOH and lay down string shot tools. 23:30 - 00:00 0.50 PULL P DECOMP Pull string into tension and set in slips with 150K up weight. Make up chemical cutter tools. Note: All depths are ELM Zero BPH losses. 11/4/2004 00:00 - 01 :30 1.50 PULL P DECOMP PJSM. SWS make up chemical cutter assembly. 01 :30 - 04:00 2.50 PULL P DECOMP RIH with chemical cutter. Correlate depths. Set cutter head on depth, 8,450'. Fire cutter. Positive indication of cutter firing in SWS control cab, no indication of tubing free at surface. POOH and lay down cutter assembly. 04:00 - 04:30 0.50 PULL P DECOMP Connect TDS. Attempt to pull completion tubing. Work tubing with 225K maximum up weight. Tubing not free. 04:30 - 05:30 1.00 PULL P DECOMP SWS make up 2.68" Jet Cutter assembly. 05:30 - 08:00 2.50 PULL P DECOMP SWS RIH with Jet Cutter assembly to 6,800'. Fire cutter. POOH and lay down cutter tools. Pull 105K, pipe free. 08:00 - 09:00 1.00 PULL P DECOMP Rig down wireline. Clear floor of all tools. 09:00 - 09:30 0.50 PULL P DECOMP Rig up to pull and lay down tubing and spool control lines. 09:30 - 10:00 0.50 PULL P DECOMP Pull hanger to floor. Disconnect chemical injection and control lines. Break off and lay down hanger and landing joint. Printed: 12/6/2004 10:55:25 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 1114/2004 10:00 - 11 :00 1.00 PULL P DECOMP Change out bails. Connect control lines to spooler. 11:00 -17:30 6.50 PULL P DECOMP POOH laying down 4.5" tubing. Spooling control line and chemical injection line. Recovered 69 joints of tubing, SSSV, 2 flow couplings and 2 pups, 69 4.5" clamps and 3 SS bands. 17:30 - 20:00 2.50 PULL P DECOMP Change out elevators, clear and clean rig floor. POOH laying down 3.5" tubing and spooling chemical injection line to first GLM. Hole not taking proper fill. Monitor well, slight flow. 20:00 - 21 :30 1.50 PULL P DECOMP Make up circulating sub. Circulate hole volume at 3,000' with 9.5 ppg salt water at 12 bpm, 690 psi. Stop circulation and monitor well. Hole now taking fluid. Control line spool full, change out same. 21 :30 - 00:00 2.50 PULL P DECOMP Continue laying down 3.5" tubing from 3,000' to 1,260' while spooling chemical injector line. Static losses=20 bph. 11/5/2004 00:00 - 01 :30 1.50 PULL P DECOMP Continue POOH laying down 3.5" tubing. Found one hole in 3.5" tubing calculated to have been at 6,301' MD. Total 3.5" out - 119 joints, 2 GLM's, 1 cut joint (15.08'). Retrieved 6,790 feet of chemical injection line, 10 SS bands and 105-1/2 clamps. Top offish estimated at 6,781'. 01 :30 - 03:00 1.50 PULL P DECOMP Lay down control line tools and spooler. Clear and clean rig floor. Rig up to test BOP with 4" drill pipe. 03:00 - 05:00 2.00 FISH P DECOMP Drained stack to run test joint and test plug. Could see several clamps laying across spool. Make up magnet and retrieve 12-1/2 clamps. Total 3.5" clamps recovered = 118. 05:00 - 06:30 1.50 BOPSUR P DECOMP Rig up and test BOP with 4" drill pipe. Test rams to 250 psi low - 3,500 psi high. Test annular preventer to 250 psi low- 2,500psi high. 06:30 - 07:00 0.50 BOPSUR P DECOMP Install wear bushing, lay down test joint. 07:00 - 07:30 0.50 BOPSUR P DECOMP Clean rig floor 07:30 - 09:30 2.00 FISH P DECOMP Pick up wash pipe BHA assembly to 442'. 09:30 - 14:00 4.50 FISH P DECOMP Pick up 4" drill pipe from 442' to 5,878'. Tagged obstruction. 14:00 - 15:30 1.50 FISH P DECOMP Rotate from 5,878' to 5,946'. 80-100 RPM, 5K-6K Torque. 15:30 - 16:00 0.50 FISH P DECOMP POOH 9 stands to 5,105' to pick up singles to get back to 5,800'. 16:00 - 16:30 0.50 FISH P DECOMP Pick up drill pipe singles to 5,631'. Problem with TDS lube oil pump. 16:30 - 18:00 1.50 FISH N RREP DECOMP Replace lube oil switch on top drive. 18:00 - 00:00 6.00 FISH P DECOMP RIH with wash pipe from 5,631' to 6,747'. Pump and ream as required. Ream: 6,156' to 6,165' 6,257' to 6,263' 6,357' to 6,747' 135K UP, 115K DN, 130K ROT, 90 RPM, 10K WOB, 5K-10K TORQ, 70 SPM, 170 GPM, 350 PSI 11/6/2004 00:00 - 01 :30 1.50 FISH P DECOMP Washing and reaming from 6,747' to 6,748'. 135K UP, 115K DN, 130K ROT, 90 RPM, 10K WOB, 5K-10K TORQ, 70 SPM, 170 GPM, 350 PSI 01:30 - 04:30 3.00 FISH P DECOMP Pump slug, blow down TDS. POOH to examine wash over shoe from 6,478' to BHA at 442'. 04:30 - 05:00 0.50 FISH P DECOMP Rack back drill collars. Printed: 12/6/2004 10:55:25 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 11/6/2004 05:00 - 06:30 1.50 FISH P DECOMP Pull wash over shoe to surface. 2.99' of the shoe was missing. Remainder of shoe and wash pipe packed with SS control line. Lay down shoe and wash pipe. Lay down and clean out boot baskets. 06:30 - 07:30 1.00 FISH P DECOMP Pick up new shoe and one joint of wash pipe. RIH with BHA to 441'. 07:30 - 09:00 1.50 FISH P DECOMP RIH to 6,400'. 09:00 - 10:00 1.00 FISH P DECOMP Slip and cut drill line. 10:00 - 10:30 0.50 FISH P DECOMP Service TDS. 10:30 - 12:00 1.50 FISH N RREP DECOMP Traction motor caliper brakes not working. Install hose, repair brake fluid reservoir fitting, test systems. 12:00 - 12:30 0.50 FISH P DECOMP RIH from 6,400' to 6,744'. 12:30 - 18:30 6.00 FISH P DECOMP Reaming junk from 6,744' to 6,758'. 8K WOB 100 RPM 5K-12K TQ 98 SPM 240 GPM 550 PSI Shoe wom out. 18:30 - 21 :00 2.50 FISH P DECOMP POOH from 6,758' to 441' 21 :00 - 22:30 1.50 FISH P DECOMP Lay down shoe and wash pipe. 1.5' of shoe wom away. Lay down boot baskets and clean. Slivered pieces of SS control line in boot baskets. 22:30 - 23:30 1.00 FISH P DECOMP Make up boot baskets, new joint of 5-9/16" ID wash pipe and 6.75" OD shoe. RIH with drill collars to 441'. 23:30 - 00:00 0.50 FISH P DECOMP Pick up drill pipe singles, RIH to 908' 11/7/2004 00:00 - 01 :30 1.50 DHB P DECOMP Continue RIH picking up drill pipe from 908' to 3,428'. 01 :30 - 02:30 1.00 DHB P DECOMP RIH with stands from derrick from 3,428' to 6,489'. Tagged obstruction. Set down 30K, no movement. 02:30 - 03:00 0.50 DHB P DECOMP Attempt to work through obstruction. No success. Discuss with Anchorage team. 03:00 - 04:30 1.50 DHB P DECOMP Detected pit gain with pumps off. Flow cheek, well flowing. Weighting up to 9.4 ppg salt water. With 9.4 ppg salt water around, well static. 04:30 - 06:30 2.00 DHB P DECOMP Blow down TDS. POOH from 6,489' to 441'. Encountered tight spot at 6,150', pulled through with 50K. 06:30 - 08:30 2.00 DHB P DECOMP Lay down BHA. Clear and clean rig floor. 08:30 - 09:30 1.00 DHB P DECOMP Make up RTTS and RIH to 1,503'. 09:30 - 10:00 0.50 DHB P DECOMP Lubricate rig, service TDS. 10:00 - 11 :30 1.50 DHB P DECOMP RIH from 1,503' to 4,105'. 11 :30 - 12:00 0.50 DHB P DECOMP Set RTTS and test 7-5/8" casing to 3,500 psi for 15 minutes, good test. Unseat RTTS. 12:00 - 13:00 1.00 DHB P DECOMP RIH from 4,105' to 6,470'. 13:00 - 13:30 0.50 DHB P DECOMP Set RTTS and test 7-5/8" casing to 3,500 psi for 30 minutes, good test. 13:30 - 15:00 1.50 DHB P DECOMP Bring pump up slowly to 5 BPM. Establish injection rate. 5 BPM @ 500 psi. Unseat RTTS. Blow down TDS. 15:00 - 17:30 2.50 DHB P DECOMP POOH and lay down RTTS. 17:30 - 18:00 0.50 DHB P DECOMP Make up running tool and EZSV. 18:00 - 21 :00 3.00 DHB P DECOMP RIH with EZSV to 6,465'. 21 :00 - 22:00 1.00 DHB P DECOMP Make up cement head. Break circulation. Set EZSV at 6,465' with 35 right hands tums. Establish injection rate at 3 BPM @ 400 psi. 22:00 - 23:00 1.00 DHB P DECOMP Rig up Dowell. Hold PJSM. Pump 5 bbls fresh water. Test lines to 4,500 psi, good test. Mix and pump 40 BBLS (200 sx), Class G 15.8 PPG cement. Displace with Dowell, using 9.2 Printed: 12/6/2004 10;55;25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 11/712004 22:00 - 23:00 1.00 DHB P DECOMP PPG brine. Total pipe displacement 64.5 BBLS. At 60.6 BBLS displacement away, pressure reached 2,500 PSI. Shut down pumping. Release from EZSV. Dump remaining 4 BBLS cement on top of EZSV. POOH from 6,465' to 5,998'. 23:00 - 00:00 1.00 DHB P DECOMP Circulate bottoms up at 5.5 BPM, 600 PSI. Lay down cementing equipment. 11/8/2004 00:00 - 03:00 3.00 DHB P DECOMP Install saver sub. POOH and lay down EZSV running tool. 03:00 - 03:30 0.50 DHB P DECOMP Test 7.625" casing to 3,500 psi for 30 minutes. Record on circular chart, good test. 03:30 - 05:30 2.00 DHB P DECOMP Make up running tool and EZSV. RIH to 4,100' 05:30 - 06:00 0.50 DHB P DECOMP Set EZSV with 35 right hand turns. Release from EZSV and check set. 06:00 - 07:30 1.50 DHB P DECOMP POOH from 4,100'. Lay down EZSV running tool. 07:30 - 09:30 2.00 CASE P DECOMP Change out 3.5" X 6" variable rams to 7.625". Pull wear bushing, set test plug. Test doors seals to 3,500 psi, good test. Pull test plug, set wear bushing and rig down test equipment. 09:30 - 11 :30 2.00 CASE P DECOMP Make up 7.625" string cutter to 1 0'. RI H with drill pipe to 4,000'. Install blower hose. 11 :30 - 12:30 1.00 PULL P DECOMP Locate collar and position cutters at 3,975', 5' below a collar. Pumps up to 1,500 psi. Cut 7.625" casing. 12:30 - 13:00 0.50 PULL P DECOMP Attempt to circulate. Unsuccessful. 750 psi max. 13:00 - 14:30 1.50 PULL P DECOMP POOH from 3,975'. Lay down cutter assembly. 14:30 - 15:30 1.00 PULL P DECOMP Make up 7.625" casing spear assembly. Pull wear bushing. 15:30 - 16:00 0.50 PULL P DECOMP Spear and latch onto 7.625" casing. Back out lock down screws. Attempt to pull casing, unsuccessful. Maximum hook weight, 375K. 750 psi on pumps. 16:00 - 17:30 1.50 PULL P DECOMP POOH and lay down spear assembly. 17:30 - 20:30 3.00 PULL P DECOMP Make up 7.625" cutter assembly with new knives. RIH and locate collar at 3,888'. Pull up to 3,853' (5' below collar). Cut 7.625" casing. When cutters through, OA pressure increased to 400 psi. 20:30 - 21 :00 0.50 PULL P DECOMP Circulate 7.625" X 10.75" annulus at 6 bpm at 1,100 psi until returns cleaned up. Total 185 bbls dumped to cuttings tank. 21 :00 - 23:30 2.50 PULL P DECOMP Blow down all lines and cap all valves. POOH from 3,853'. Lay down cutting assembly. 23:30 - 00:00 0.50 PULL P DECOMP Make up spear assembly, RIH and engage 7.625" casing below well head. Back out lock down screws. Pull casing free with 135K up weight. Pull hanger to floor. 11/9/2004 00:00 - 00:30 0.50 PULL P DECOMP Lay down hanger and clear rig floor. 00:30 - 01 :30 1.00 PULL P DECOMP Rig up to pull 7.625" casing. 01 :30 - 05:00 3.50 PULL P DECOMP Pull and lay down 7.625" casing. Hanger, 1 pup joint, 90 full joints, 1 cutoff joint (8.37) layed down. 05:00 - 06:30 1.50 PULL P DECOMP Rig down casing equipment. Clear and clean the floor. 06:30 - 08:30 2.00 FISH P DECOMP MU Baker Fishing Spear BHA to 322'. 08:30 - 09:30 1.00 FISH P DECOMP RIH with spear to the top of the 7-5/8" casing stub @ 3,853'. PU - 105K, SO - 9OK. 09:30 - 11 :30 2.00 FISH P DECOMP RIH to 3,891' to the stop ring and engage the top of the casing stub. Jar on casing stub - unsuccessful. Fire Jars - 300K, Max Pull after firing - 400K. 11:30 -12:00 0.50 FISH P DECOMP Perform visual inspection of the derrick and the top drive. 12:00 - 13:30 1.50 FISH P DECOMP POH wI 4" DP from 3,853' to 322'. 13:30 - 14:00 0.50 FISH P DECOMP LD Spear BHA from 322'. Printed: 12/6/2004 10:55:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 11/9/2004 14:00 - 14:30 0.50 FISH P DECOMP MU 7-5/8" Cutting BHA and RIH to 3,936'. 14:30 - 15:30 1.00 FISH P DECOMP RIH w/4"DP to 3,936'. 15:30 - 16:00 0.50 FISH P DECOMP RIH with pupms on and locate collar @ 3,971'. PU and cut 7-5/8" casing @ 3,936' - 65 rpm, 296 gpm, 200 psi, Rot - 85K, PU - 95K, SO - 80K. 16:00 -17:30 1.50 FISH P DECOMP POH from 3,936'. LD Cutting BHA. 17:30 - 18:30 1.00 BOPSUR P DECOMP Change top set of rams to 3-1/2" x 6" variable rams. MU test joint and set test plug. 18:30 - 22:30 4.00 BOPSUR P DECOMP Test BOPE to 250 psil 3500 psi. Test annular to 250 psi/2500 psi. Witness of the BOP test was waived by Jeff Jones of the AOGCC. 22:30 - 23:00 0.50 FISH P DECOMP MU Spear BHA to 322'. 23:00 - 23:30 0.50 FISH P DECOMP RIH from 322' to top of the casing stub @ 3,853'. RIH to 3,891 to the stop ring and engage the spear. 23:30 - 00:00 0.50 FISH P DECOMP Jar on casing stub - unsuccessful. Fire Jars - 300K. Max Pull after firing - 400K. 11/10/2004 00:00 - 00:30 0.50 FISH P DECOMP Jar on casing stub @ 3,853' - unsuccessful. Fire Jars - 300K. Max Pull after firing - 400K. 00:30 - 01:00 0.50 FISH P DECOMP Inspect the derrick and top drive. 01 :00 - 02:00 1.00 FISH P DECOMP Slip and cut drilling line. Inspect brakes 02:00 - 04:00 2.00 FISH P DECOMP POH wI 4" DP from 3,853' to 322'. LD spear BHA. Clear floor. 04:00 - 04:30 0.50 FISH P DECOMP PU 7-5/8" Cutting BHA. 04:30 - 05:30 1.00 FISH P DECOMP RIH with 4" DP to top of the tubing stub @ 3,853'. Install Blower hose. PU - 90K, SO - 80K, Rot - 85K. 05:30 - 06:30 1.00 FISH P DECOMP RIH and cut 7-5/8" casing @ 3,893' -13 bpm, 1,500 psi. 06:30 - 08:00 1.50 FISH P DECOMP Pump dry job and remove the blower hose. POH w/4" DP from 3,893'. LD casing cutter. 08:00 - 09:00 1.00 FISH P DECOMP MU spear assembly w'6.767" grapple. RIH with Spear BHA to 322'. 09:00 - 10:30 1.50 FISH P DECOMP Change out the elevators and RIH with 4" DP from 322' to 3,853'. 10:30 - 11 :00 0.50 FISH P DECOMP Engage the top of the 7-5/8" casing stub @ 3,853'. PU - 108K, SO - 91K. RIH to the stop ring @ 3,861'. PU to 200K and bleed off jars. Straight pull to 325K. Fish started to drag out of the hole. Once fish was free, PU - 11 OK. 11 :00 - 12:30 1.50 FISH P DECOMP POH with 4" DP from 3,853' to 322'. Change out elevators. Stand back BHA from 322' to 32'. 12:30 - 13:00 0.50 FISH P DECOMP Break off and LD 39.87' of 7-5/8" fish + 1 centralizer from casing cut @ 3,893'. LD fishing tools and clear the floor. 13:00 - 14:00 1.00 FISH P DECOMP MU Metal Muncher Milling BHA to 317'. 14:00 - 15:30 1.50 FISH P DECOMP RIH with 4" DP to 3,893'. 15:30 - 16:00 0.50 FISH P DECOMP Displace well over to hi-visc milling fluid. 16:00 - 00:00 8.00 FISH P DECOMP Mill on 7-5/8" casing stub from 3,893' to 3,926'. TO on - 7K, TO off - 5K, 115 rpm, 5k WOB. 475 gpm. 11/11/2004 00:00 - 06:00 6.00 FISH P DECOMP Mill on 7-5/8" casing stub from 3,926' to 3,945'. TO on -7K, TO off - 5K, 115 rpm, 5k WOB. 475 gpm. 06:00 - 07:30 1.50 FISH P DECOMP Pump Super Sweep. CBU. Work pipe @ 3,945'. 11 bpm, 600 psi. Monitor well - static. Pump dry job and remove the blower hose. Blow down surface equipment. 07:30 - 09:00 1.50 FISH P DECOMP POH w/4" DP from 3,945' to 316'. Change out handling equipment. 09:00 - 09:30 0.50 FISH P DECOMP Stand back BHA from 316' to 26'. LD BHA. Clean and clear the floor. Printed: 12/6/2004 10:55:25 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 11/11/2004 09:30 - 10:30 1.00 FISH P DECOMP Flush the stack and all surface equipment of metal cuttings. Blow down all surface equipment. 10:30-11:00 0.50 FISH P DECOMP Service and set the wear ring. 11 :00 - 13:00 2.00 REMCM-P WEXIT MU Mule Shoe on 4" DP. RIH to 2,900'. Pipe not taking the proper fill. Break circulation. RI H w/4" DP from 2,900' to 4,100' - wash and ream @ 3,943' and 4,060'. 13:00 - 14:00 1.00 REMCM-P WEXIT Circulate nut plug sweep @ 4,090'. POH to 3,925' to clear 7-5/8" casing stub. RIH to 4,090' 14:00 - 15:30 1.50 REMCM-P WEXIT Rig up Schlumberger cementers. Pump 5 bbls water and test lines to 4,500 psi. Batch mix and pump 45 bbls of 17 ppg cement kick of plug. Displace cement w/32 bbls 8.4 ppg mud and balance plug in place. CIP @ 1500 hrs. 15:30 - 16:30 1.00 REMCM-P WEXIT POH to 3,457'. CBU. 16:30 - 18:00 1.50 REMCM-P WEXIT POH from 3,457'. LD Mule Shoe. 18:00 - 18:30 0.50 STWHIP P WEXIT Bring 8-3/4" BHA components to the rig floor. 18:30 - 19:00 0.50 STWHIP P WEXIT Service the top drive. 19:00 - 22:30 3.50 STWHIP P WEXIT PU 8-3/4" BHA to 1,595'. Orient and upload MWD. 8-3/4" BHA: Hughes HCM605, 7" motor w/6 stg and 7/8 lobe @ 1.5 bend, non-mag pony collar, 8-5/8 sleeve type stabilizer, non-mag float sub, 6-3/4" GRlRES/PWD, 6-3/4" DM HOC, 6-3/4" TM HOC, 3 x non-mag dc's, 9 x dc's, 15 x hwdp, jar, 8 x hwdp, 12 x 5" DP, Weatherford Ghost Reamer, xo. 22:30 - 23:00 0.50 STWHIP P WEXIT RIH w/4" DP to 2,715'. 23:00 - 00:00 1.00 STWHIP P WEXIT Hole not taking proper fill, circulate bottoms up. Well static. 11/12/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT RIH from 2,715' to 3,367'. PU - 145K, SO - 105K. Connect I blower hose and fill pipe. 01 :00 - 01 :45 0.75 STWHIP P WEXIT Wash down from 3,367' and tag the top of cement @ 3,575' - 2 bpm, 300 psi. 01:45 - 02:30 0.75 REMCM-P WEXIT Pressure test 10-3/4" J-55 casing to 2,500 psi and hold for 30 minutes - good test. 02:30 - 03:00 0.50 STWHIP P WEXIT Drill cement from 3,575' to 3,675'. Clabbered up mud at the shakers. 03:00 - 05:00 2.00 STWHIP P WEXIT Circulate and condition mud @ 3,675'. 05:00 - 10:30 5.50 STWHIP P WEXIT Drill cement and 20' new formation to 3,965'. 10:30 - 13:00 2.50 STWHIP P WEXIT Displace well over to 9.8 ppg LSND drilling fluid. Clean I I beneath shakers. 13:00 - 13:30 0.50 STWHIP P WEXIT Perform FIT to 12.5 ppg. 13:30 - 00:00 10.50 DRILL P INT1 Drill Directionally from 3,965' to 5,230'. AST - 2.69, ART - 3.41, PU - 165K, SO - 115K, ROT - 140K, TO on - 9K, TO off- 8K 11/13/2004 00:00 - 12:00 12.00 DRILL P INT1 Drill Directionally from 5,230' to 6,353'. PU - 190K, SO - 125K, ROT - 155K, TO on - 13K, TO off - 12K. AST - 0.95, ART- 7.15. 12:00 - 00:00 12.001 DRILL P INT1 Drill Directionally from 6,353' to 7,253'. PU - 200K, SO - 135K, ROT -165K, TO on -12K, TO off -11K. AST - 1.88, ART- 7.02. 11/14/2004 00:00 - 11 :00 11.00 DRILL P INT1 Drill 8-3/4" Directionally from 7,253' to 7,951'. PU - 215K, SO- 140K, ROT - 175K, TO on - 15K, TO off - 13K. AST - 0.59, ART - 6.96. 11 :00 - 11 :30 0.50 DRILL N RREP INT1 Washout of valve and seat on #1 mud pump. Changeout valve and seat. 11 :30 - 00:00 12.50 DRILL P INT1 Drill Directionally from 7,951' to 8,675'. PU - 230K, SO - 145K, Printed: 12/6/2004 10:55:25 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 11/14/2004 11 :30 - 00:00 12.50 DRILL P INT1 ROT - 185K, TO on - 18K, TO off - 14K. AST - 1.72, ART- 8.19. 11/15/2004 00:00 - 19:30 19.50 DRILL P INT1 Drill 8-3/4" Directionally from 8,675' to 9,395'. PU - 260K, SO - 165K, ROT - 200K, TO on - 19K, TO off - 15K. AST - 4.88, ART -11.0 19:30 - 20:30 1.00 DRILL P INT1 Circulate bottoms up for samples - 505 gpm, 4,150 psi. 20:30 - 21 :00 0.50 DRILL P INT1 Drill from 9,395' to 9,406' (TD). 21 :00 - 22:00 1.00 DRILL P INT1 Circulate bottoms up for samples and condition mud @ 500 gpm, 4,150 psi. Monitor well - static. Blow down top drive. 22:00 - 00:00 2.00 DRILL P INT1 POH from 9,406' to 6,260' - no problems. Max overpull - 35K. 11/16/2004 00:00 - 01 :30 1.50 DRILL P INT1 POH from 6,260' to 3,835'- no problems. Max overpull - 35K. 01 :30 - 03:30 2.00 DRILL P INT1 Slip and cut drilling line. Service the top drive. 03:30 - 05:30 2.00 DRILL P INT1 RIH from 3,835' to 9,406' - precautionary wash and ream last stand to bottom. Fill pipe every 3,000'. 05:30 - 08:30 3.00 DRILL P INT1 Circulate a high visc sweep around @ 480 gpm, 4,180 psi. Circulate and condition the mud. Pump dry job. 08:30 - 12:00 3.50 DRILL P INT1 POH from 9,406' to top of the BHA @ 1,595'. 12:00 - 17:00 5.00 DRILL P INT1 LD BHA from 1,595' to 95'. Flush MWD tools. Blow down the top drive and download the MWD tools. LD BHA from 95'. Clean and clear the floor. Pull wear ring. 8-3/4" HCM 605 graded: 5/4/BT/A/X/1/CTITD Note: Recovered three -7116" OD heads off of Allen screws from the bit. 2 of them were directly plugging nozzles. 17:00 - 18:30 1.50 BOPSUR P INT1 Change out the top set of rams from 3-1/2" x 6" variables to 7" rams. MU test joint and set test plug. Test 7" rams to 250 psi I 3,500 psi. RD test joint. 18:30 - 19:00 0.50 WHSUR P INT1 MU hanger and landing joint. Make a dummy run with hanger. 19:00 - 22:00 3.00 CASE P LNR1 MU Franks fill-up tool and install 15' bails. RU 350 ton elevators. RU 7" casing handling equipment. 22:00 - 00:00 2.00 CASE P LNR1 RIH with 7" float equipment - bakerloc'd. Check floats - good. PU 7" 26# L-80 BTC-M casing and RIH to 820' Optimum torque - 8,800 ft-Ibs. Best-O-Life 2000 used on all connections. 11/1712004 00:00 - 03:15 3.25 CASE P LNR1 PU 7" 26# L-80 BTC-M casing and RIH to 3,848' Optimum torque - 8,800 ft-Ibs. Best-O-Life 2000 used on all connections. 03:15 - 04:00 0.75 CASE P LNR1 Circulate at the shoe prior to running into the open hole - 6 bpm, 400 psi. 04:00 - 11 :00 7.00 CASE P LNR1 RIH wl7" 26#, L-80 BTC-M casing from 3,848' to 9,406'. Float Shoe @ 9,406' Float Collar @ 9,320' 11 :00 - 12:00 1.00 CASE P LNR1 Remove the Franks fill up tool and MU cement head. 12:00 - 14:00 2.00 CEMT P LNR1 Break circulation and stage up the pumps while circulating 3 x OH annular volume @ 7 bpm, 980 psi. Hold Cement job PJSM while circulating. RU Schlumberger Cementers. 14:00 - 16:30 2.50 CEMT P LNR1 Pump 5 bbls of water ahead. Shut Down and test lines to 4,500 psi. Pump 15 bbls CW100 Unweighted Spacer @ 5 bpm - 580 psi initial, 580 psi final. Shut down. Mix 11.2 ppg Mudpush Spacer. Pump 40 bbls 11.2 ppg Spacer @ 5 bpm, 640 psi initial, 540 psi final. Printed: 1216/2004 10:55:25 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7131/1991 End: 11/29/2004 11/17/2004 14:00 - 16:30 2.50 CEMT P LNR1 Shut down. Mix 12.0 ppg Lead Slurry. Drop bottom plug. Pump 115 bbls 12.0 ppg Class G + adds Lead Slunry @ 5 bpm, 600 psi initial, 320 psi final. Pump 41 bbls 15.8 ppg Class G + adds Tail Slunry @ 5 bpm, 350 psi initial, 250 psi final. Shut down. Drop top plug. Pump 10 bbls water to drop plug. Shut down and switch over to the rig for remainder of displacement. Caught cement @ -97 bbls pumped @ 7 bpm, 470 psi. Observed pressure increase as heavier fluid went around the shoe. Drop rate to 5 bpm to bump plug. Bumped the plug with 357 bbls @ 5 bpm - 1,200 psi Increase pressure to 3,500 psi and hold for 5 minutes - good test. Bleed off pressure and check floats - holding. CIP @ 1606 hours 11/17/2004. Observed good lift pressure and retum flow line indication throughout the entire job. 16:30 - 18:00 1.50 CEMT P LNR1 LD cement head. Flush and drain the stack. Clean floor. 18:00 - 22:30 4.50 CASE P LNR1 Split the stack. PU 375K straight pull and set the emergency slips. Cut 7" casing with the Wach's cutter. LD 20' pup and 15.32' cut joint. Install 7" packoff. NU BOP stack. Run in lock down screws. Test the packoff to 4,328 psi - good test. Clean cellar area. 22:30 - 00:00 1.50 BOPSUR P LNR1 Change out the 7" top rams to 3-1/2" x 6" variable rams. MU test joint and set the test plug, 11118/2004 00:00 - 01 :30 1.50 BOPSUR P LNR1 Test 3-1/2" x 6" variable rams and stack body to 250 psi 13,500 psi - good test. Install the wear ring. 01 :30 - 04:00 2.50 DRILL P PROD1 PJSM. MU 6-1/8" BHA to 361'. 6-1/8" BHA: 6-118" Hughes MX20, 4-3/4" 7/8 - 2 stg motor, non-mag float sub, 4-3/4" GR/Res, 4-3/4" DM HOC, 4-3/4" TM HOC, 3 x non-mag flex collars, circ sub, 3 x HWDP, Dailey DNT jar, 2 x HWDP, xo, single joint of DP. 04:00 - 04:30 0.50 DRILL N DFAL PROD1 Troubleshoot ABI, no response 04:30 - 05:30 1,00 DRILL N DFAL PROD1 POH, cycle ABI tool, surface test tool, good signal for ABI 05:30 - 06:00 0.50 DRILL N DFAL PROD1 RIH wI BHA to 391'. 06:00 - 06:30 0.50 DRILL P PROD1 PU 4" DP from 391' to 1,295', 06:30 - 08:00 1.50 DRILL P PROD1 Surface test MWD - good test. PU 4" DP from 1,295' to 3,162', 08:00 - 11 :00 3.00 DRILL P PROD1 RIH from 3,162' to the top of the float collar @ 9,320'. Fill pipe every 3,000'. Simops: Freeze protect OA with 120 bbls of dead crude while RIH @ 4 bpm, 1,250 psi. Shut in the OA with 1,000 psi. 11 :00 - 12:30 1.50 CASE P LNR1 Pressure test the 7", 26# L-80 BTC-M casing to 3,500 psi and hold for 30 minutes - good test. Blow down the surface equipment. 12:30 - 13:30 1.00 DRILL P PROD1 Drill Float collar and cement from 9,320 to top of the float shoe @ 9,404' 13:30 - 15:00 1.50 DRILL P PROD1 Pump 100 bbl water spacer, 45 bbls high visc sweep, and displace the well over to 8.4 ppg FloPro drilling fluid @ 290 Printed: 12/6/2004 10:55:25 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 11/1S/2004 13:30 - 15:00 1.50 DRILL P PROD1 gpm, 2,120 psi. 15:00 - 15:30 0.50 DRILL P PROD1 Drill float shoe and 20' of new formation to 9,426'. Pull back into the casing. 15:30 - 16:00 0.50 DRILL P PROD1 Perform FIT to 10.3 ppg EMW using 8,4 ppg FloPro and 826 psi surface pressure @ 8,360' TVD. Blow down surface equipment. 16:00 - 00:00 8.00 DRILL P PROD1 Drill 6-1/8" directionally from 9,426' to 9,692'. AST - 4.03, ART - 2.48, PU - 1S0K, SO - 135K, ROT - 155K, TO on - 5K, TO off -4K. 11/19/2004 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6-1/8" directionally from 9,692' to 10,OS5'. PU - 185K, SO - 135K, ROT - 160K, TO on - 6K, TO off - 5K. AST - 1.38, ART -S,49 12:00 - 00:00 12.00 DRILL P PROD1 DriIl6-1/S" directionally from 10,085' to 10,392. PU - 190K, 50 - 135K, ROT - 160K, TO on -7K, TO off - 5K. A5T - 6.65, ART - 2.04 11/2012004 00:00 - 05:00 5.00 DRILL P PROD1 DriIl6-1/S" directionally from 10,392 to 10,452'. PU - 190K, SO - 135K, ROT - 165K, TO on - 7K, TO off - 5K. AST - 2.74, ART - 1.21 05:00 - 06:00 1.00 DRILL P PROD1 Circulate sweep prior to trip out of hole. Monitor well - stable. 06:00 - 07:00 1.00 DRILL P PROD1 POH from 10,452' to 9,318'. Maximum overpull- 225K. Drop dart. 07:00 - 07:30 0.50 DRILL P PROD1 Open circ sub and circulate bottoms up - 500 gpm, 2,100 psi. Pump dry job. 07:30 - 10:00 2.50 DRILL P PROD1 POH from 9,318' to 361'. 10:00 - 11 :00 1.00 DRILL P PROD1 Handle BHA. LD circ sub, LD HOC, LD float sub. Break bit and LD motor. Bit Graded: 1 \ 2 \ ER \ A \ E \I \ cn BHA 11 :00 - 15:00 4.00 BOPSUR P PROD1 MU test joint. Pull wear ring. Install test plug and test BOPE - 250 psi I 3,500 psi. Test annular - 250 psi 12,500 psi. Pull test plug, install wear ring. LD test joint. Witness of the BOP test was waived by John Crisp of the AOGCC. 15:00 - 17:00 2.00 DRILL P PROD1 MU BHA #3 to 363'. Change out to 5" high speed motor w/1. 76 bend. Orient and upload MWD. Surface test - good. BHA #3: 6-1/S" Security FM3641, 5" motor 6/7 - 6 stg, non-mag float sub, 4-3/4" GRlRes, 4-3/4" DM HOC, 4-3/4" TM HOC, 3 x non-mag flex collars, circ sub, 3 x HWDP, jar, 2 x HWDP, xo. 17:00 - 20:30 3.50 DRILL P PROD1 RIH with 4" DP from 363' to 9,320'. Fill pipe every 3,000'. 20:30 - 22:00 1.50 DRILL P PROD1 Cut off 102' of drilling line. Service top drive. 22:00 - 00:00 2.00 DRILL N RREP PROD1 Troubleshoot and repair high drum clutch on draw works. 11/21/2004 00:00 - 16:30 16.50. DRILL N RREP . PROD1 Troubleshoot high drum clutch on draw works. Bypass high drum clutch 16:30 - 19:00 2.50 DRILL N RREP PROD1 PU 1 stand of 4" DP and RIH so that the bit was -4' out of the casing shoe @ 9,410'. Cir 250 gpm 1,400 psi and rotate-7 rpm. Inspect condition of the low drum clutch - good shape. Replace friction pads.. 19:00 - 20:00 1.00 DRILL P PROD1 RIH with low clutch only to 10,452' 20:00 - 00:00 4.00 DRILL P PROD1 Drill 6-1/8" hole directionally from 10,452' to 10,590'. ART- 0.42, AST - 1.68, PU - 190K, SO - 135K, ROT - 160K, TOon- 7K, TO off - 6K. 11/22/2004 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6-1/8" hole directionally from 10,590' to 10,7S0'. PU- I Printed: 12/6/2004 10:55:25 AM , . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 11/22/2004 00:00 - 12:00 12.00 DRILL P PROD1 185K, SO - 130K, ROT - 160K, TO on - 7K, TO off - 6K. AST- 5.33, ART - 1.13 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6-118" hole directionally from 10,780' to 11,040'. PU- 185K, SO - 135K, ROT - 160K, TO on - 7K, TO off - 6K. AST- 5.33, ART 0.48 11/23/2004 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6-1/8" hole directionally from 11,040' to 11,188'. PU- 190K, SO - 135K, ROT - 160K, TO on - 7 -9K, TO off - 6K. WOB - 5-10. GPM - 315. AST = 4.08. ART = .57 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6-1/8" hole directionally from 11,188' to 11 ,412'. PU- 190K, SO - 135K, ROT - 160K, TO on - 7 -9K, TO off - 7K. WOB - 5-10. GPM - 315. AST = 5.8 ART = 1.36 11/24/2004 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6-1/8" hole directionally from 11,412' to 11,590'. PU- 193K, SO - 132K, ROT - 160K, TO on - 6-9K, TO off - 6-7K. WOB - 5-10. GPM - 315. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6-1/8" hole directionally from 11,590' to 11,803'. PU- 190K, SO - 135K, ROT - 160K, TO on - 6-9K, TO off - 6-7K. WOB - 5-10. GPM - 315. Lesson Learned: The use of 10 skslbbl nut plug in 25 bbl sweeps as needed to aid in hole cleaning/lubricity followed by trickling nut plug into the suction at 4-5 skslhr has brought sliding ROP through shales from <9 fph to >25-30 fph. This procedure eliminated a trip and allowed us to keep in the hole drilling ahead. Also the use of coarse glass beads (acceptable for MWD tools) in sweeps of 10 skslbbl has also aided in giving lubricity while sliding through sands. Care should be given to the size of the nut plug. Coarse grain runs the risk of plugging MWD tools. Medium grain seems to be the best choice in this application as we have not experienced any MWD problems. 11/25/2004 00:00 - 13:30 13.50 DRILL P PROD1 Drill 6-1/8" hole directionally from 11,803' to 12,308'. PU- 190K, SO - 130K, ROT - 160K, TO on - 8-109K, TO off - 6-7K. WOB - 5-10. GPM - 315. RPM 30-60 13:30 - 15:00 1.50 DRILL P PROD1 Circulate hi vis sweep around. 325 GPM at 2,300 psi. Hole cleaned up. 15:00 - 16:30 1.50 DRILL P PROD1 POOH from 12,308' to 9,320'. 25K overpull @ 10,087'. 30k overpull @ 9,788'. 16:30 - 17:00 0.50 DRILL P PROD1 Service TDS. 17:00 - 20:30 3.50 DRILL N RREP PROD1 Repair drawworks high drum clutch. Install new hub. 20:30 - 22:00 1.50 DRILL P PROD1 RIH from 9,320 to 12,308. No problems or obstructions. 22:00 - 00:00 2.00 DRILL P PROD1 Circulate Hi Vis sweep around. 325 GPM @ 2,300 psi. Hole cleaned up. Spot liner running pill (120 bbls). 11/26/2004 00:00 - 01 :00 1.00 DRILL P PROD1 POOH from 12,308' to 9,325'. No problems or obstructions encountered. 01 :00 - 02:00 1.00 DRILL P PROD1 Drop dart, open circulation sub. Circ bottoms up, 500 GPM at 1,200 psi. Pump dry job. 02:00 - 04:30 2.50 DRILL P PROD1 POOH from 9,325' to BHA. 04:30 - 07:00 2.50 DRILL P PROD1 Lay down BHA, flush tools with fresh water and download MWD. Clean and clear rig floor. 07:00 - 08:00 1.00 CASE P PROD1 PJSM. Rig up 4.5" liner equipment. 08:00 - 08:30 0.50 CASE P PROD1 Make up float equipment and check floats. Floats holding. 08:30 - 11 :00 2.50 CASE P PROD1 Make up and run 4.5", 12.6#, L-80, IBT-M liner to 3,049'. 11 :00 - 12:00 1.00 CASE P PROD1 Make up hanger and packer assy. Rig down handling Printed: 12/6/2004 10:55:25 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 11/26/2004 11 :00 - 12:00 1.00 CASE P PROD1 equipment. RIH with one 15' drill pipe pup joint and one full drill pipe stand to 3,202'. 12:00 - 12:30 0.50 CASE P PROD1 Circulate a liner volume at 5 BPM, 360 psi. 65K UP wt. 60K DN weight. 12:30 - 14:00 1.50 CASE P PROD1 RIH from 3,202' to 5,851' filling every 10 stands. String not taking proper fill. 14:00 - 15:00 1.00 CASE P PROD1 Pump 35 bbls fresh water to determine if hanger or floats not holding. Got water back at calculated surface to surface strokes. Determined that floats were not holding completely. 15:00 - 16:30 1.50 CASE P PROD1 RIH with another 10 stands. Fill pipe. Took correct fill. Floats now holding. Continue to RIH to 9,362'. 16:30 - 17:00 0.50 CASE P PROD1 Lay down 2 drill pipe singles. Circulate drill pipe and liner volume at the 7" shoe. 185K UP weight. 125K DN weight. 17:00 - 18:30 1.50 CASE P PROD1 Run liner into open hole on drill pipe from 9,300' to 12,281' without problem or difficulty. 18:30 - 19:00 0.50 CASE P PROD1 Make up cement head and one drill pipe single. Make up TDS and tag bottom at 12,308' 19:00 - 20:30 1.50 CEMT P PROD1 Stage pumps up to 5.5 BPM at 1,260 psi. Circulate and I recriprocate pipe while batching up cement. 210K UP weight. 120K DN weight. Hold PJSM with all personnel involved in cement job. 20:30 - 23:00 2.50 CEMT P PROD1 Shut Down And Tum Over To Dowell - Pump 5 BBLS Water - Test Surface Lines And Equipment To 5,000 Psi. (Test Good) - Pump 20 bbls of CW100 - Pump 35 BBLS 9.5 PPG Mud Push, Followed With 77 BBLS (332 Sacks) 15.8 PPG Class "G" Tail Cement At 5.5 BPM - Wash Up Lines To Floor - Drop Dar! And Displace With 8.6 PPG Mud At 5.5 BPM With 450 Psi. - Slow Rate And Latch Liner Wiper Plug With 88.25 BBLS Pumped Away - Increase Rate To 5 BPM Continue To Displace - Slow Rate To 3.4 BPM With Final Circulating Pressure At 1,634 Psi. - Bump Plug With A Total Of 133.7 BBLS Pumped. Increase Pressure To 3,200 Psi. To Set Baker Liner Hanger - Slack Off And Increase Pressure to 4,200 PSI to Release HRD Running Tool. Bleed Off Pressure And Check Floats (Floats Held)- Cement In Place At 21 :30 Hours - Pressure Up Down Drill Pipe To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To 6.4 BPM. Slack Off String With 70,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process Several Times. Clear Indication at Surface Of Packer Setting. Increase Pump Rate At 11.3 BPM And Continue To Circulate Out Cement. Estimated 18 BBLS. Back To Surface. Displaced well to Seawater. TOL @ 9221' TZXP Packer @ 9240' TFlex Lock Liner Hgr @ 9253 Landing Collar @ 12222' Float Collar @ 12262' Float Shoe @ 12308' 23:00 - 23:30 0.50 CEMT P PROD1 Lay down cement head and clear rig floor. 23:30 - 00:00 0.50 CEMT P PROD1 POOH from 9,222' to 8,282'. 11/27/2004 00:00 - 03:00 3.00 CEMT P PROD1 POOH from 8,282' to surface. Lay down liner running tools. I I I Printed: 12/6/2004 10:55:25 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 11/2712004 03:00 - 03:30 0.50 CEMT P PROD1 Rig down liner running and cementing equipment. Clean and clear rig floor. 03:30 - 04:00 0.50 PERFOB P OTHCMP Rig up perf handling equipment. 04:00 - 04:30 0.50 PERFOB P OTHCMP Service TDS 04:30 - 05:00 0.50 CASE P PROD1 Rig up and pressure test liner to 3,500 psi for 30 minutes. Good test. 05:00 - 08:00 3.00 PERFOB P OTHCMP Hold pre-job safety meeting regarding perforation gun handling operation - Bring Schlumberger handling tools to rig floor for perf guns. Pick up perf guns and RIH to 1,917'. 08:00 - 10:30 2.50 PERFOB P OTHCMP Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment. Pick up and RIH with 2.875" PAC to 3,042'. Clear rig floor. 10:30 - 13:30 3.00 PERFOB P OTHCMP Install Cross Overs - RIH With 2.5" HSD Perforation Guns On 4" HT -40 Drill Pipe From To 12,222' (Top Of Landing Collar) 13:30 - 14:00 0.50 PERFOB P OTHCMP Place Perf Guns On Depth wI Bottom Shot At 12,210', Top Shot At 10,335', Spaced Out Throughout The Interval wI 940 Feet 38C Clean-PACK Charges Loaded With 6 SPF At 60 Degree Phase - Close Annular Preventer - Pressure Up To 3,000 Psi. And Fire Perf Guns. Good surface Indication Of Perf Guns Firing - Bleed Pressure To 0 Psi. - Open Annular. Perforated Intervals: 10,335' To 10,505' 10,740' To 10,960' 11,OOO'To 11,040' 11,330' To 11,350' 11,440' To 11,560' 11,600'To 11,730' 11,800' To 11,930' 12,100' To 12,210' 14:00 - 16:00 2.00 PERFOB P OTHCMP POH With Perf Guns Above Top Shot At 10,335' - From 12,210' To 10,241' - Well On Vacuum. Lay Down Drill Pipe From 10,241' to 9,100'. 16:00 - 17:00 1.00 PERFOB P OTHCMP Slip and Cut Drill Line. Static Losses 1.5 BPH. 17:00 - 21 :00 4.00 PERFOB P OTHCMP Continue POOH laying down drill pipe from 9,100' to 3,042'. 21 :00 - 23:00 2.00 PERFOB P OTHCMP Rig up and Lay Down 2-7/8" PAC Drill Pipe from 3,042' to 1,917'. 23:00 - 00:00 1.00 PERFOB P OTHCMP PJSM. Change out handling equipment and lay down perf guns. NOTE: Total Losses Since Firing Perf Guns - 29 BBLs. 11/28/2004 00:00 - 05:00 5.00 PERFOB P OTHCMP Continue POH laying down perf guns Note: Losses 0 BPH 05:00 - 06:00 1.00 PERFOB P OTHCMP Rig down. Clear rig floor of all running tools. 06:00 - 08:00 2.00 PERFOB P OTHCMP RIH with drill pipe from derrick to 4,760' 08:00 - 11 :30 3.50 PERFOB P OTHCMP POH laying down all drill pipe. 11 :30 - 12:30 1.00 RUNCOtvP RUNCMP Make up landing joint and place in pipe shed. Pull wear ring. 12:30 - 14:00 1.50 RUNCOtvP RUNCMP Hold Pre-Job Safety Meeting Regarding Chrome Tubing Running Operation. Rig Up 41/2" Chrome Tubing Handling Tools, Power Tongs And Equipment. 14:00 - 00:00 10.00 RUNCOtvP RUNCMP Run 4 1/2" Completion - Pick Up Tail Pipe Assembly Baker Printed: 12/6/2004 10:55:25 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/1/2004 11/29/2004 Spud Date: 7/31/1991 End: 11/29/2004 11/28/2004 14:00 - 00:00 10.00 RUNCOrvP RUNCMP Lock Connections Below Baker S -3 Packer - RIH With 4 1/2" 13 CR80 12.6 lb. Vam Top Tubing To 8,067' -Torque To 4,440 ftIlbs. 11/29/2004 00:00 - 01 :30 1.50 RUNCOrvP RUNCMP Run 4 1/2" 13 CR80 12.6 lb. Vam Top Tubing From 8,067' To Tag Top Of Liner Tie-Back at 9,222' -Torque To 4,440 ftIlbs. 01 :30 - 02:00 0.50 RUNCOrvP RUNCMP Space Out 4 1/2" Completion String - Lay Down 1 Joints Of 4 1/2" Tubing - Make Up FMC Tubing Hanger - Up Weight At 148,000 Ibs. Down Weight At 100,000 Ibs. - Top Of Liner Tie Back Sleeve At 9,222' - Wire Line Entry Guide At 9,227'. Land FMC Tubing Hanger - Run In Lock Down Studs 02:00 - 02:30 0.50 RUNCOrvP RUNCMP Rig down handling tools and equipment. 02:30 - 04:30 2.00 RUNCOrvP RUNCMP Reverse Circulate 141 bbls Sea Water And 105 bbls Sea Water with Corrosion Inhibitor At 3 BPM. 04:30 - 04:45 0.25 RUNCOrvP RUNCMP Drop 1 7/8" ball/rod assy down tubing to RHC-M plug set in XN nipple at 9216', pressured up to 3500 psi, set S-3 packer at 9170' 04:45 - 06:00 1.25 RUNCOrvP RUNCMP Test 41/2" tubing to 3500 psi for 30 minutes, bleed pressure off to 1500 psi, switched over to tbg annulus, test 41/2" x 7" annulus to 3500 psi for 30 minutes, released pressure from tubing, sheared DCK valve in GLM at 3281' 06:00 - 06:30 0.50 RUNCOrvP RUNCMP Set two way check valve. Test from below to 1,000 psi. 06:30 - 07:00 0.50 RUNCOrvP RUNCMP Blow down all lines 07:00 - 08:00 1.00 BOPSURP RUNCMP Nipple down BOP's and adapter flange. 08:00 - 10:00 2.00 WHSUR P RUNCMP Nipple up adapter flange and tree. Test same to 5,000 psi for 15 minutes. Good test. 10:00 - 11 :00 1.00 WHSUR P RUNCMP Rig up DSM lubricator and pull two way check valve. 11 :00 - 14:00 3.00 WHSUR P POST Rig up Little Red Hot Oil. Test Surface Lines At 3,500 Psi. (Test Good) - Reverse Circulate 75 BBLS Diesel Freeze Protection Down Inner Annulus At 3 BPM With 950 Psi. U Tube Diesel Into Tubing 14:00 - 14:30 0.50 WHSUR P POST FMC dry rod BPV and test from below to 1,000 psi. Good test. 14:30 - 15:00 0.50 RIGD P POST Break Down Surface Equipment - Remove Secondary Annulus Valve -Install Tree Cap And Gauges - Secure Well Rig Released From Well Work On DS 5-24A To Y-03A At 15:00 Hours On 11/29/2004 Printed: 12/6/2004 10:55:25 AM 0" BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA 05-24A . Job No. AKZZ3374225, Surveyed: 25 November, 2004 Survey Report 13 December, 2004 Your Ref: API 500292220401 Surface Coordinates: 5948396.67 N, 698282.17 E (70015' 47.1952" N, 148023' 48.6910" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 63. 10ft above Mean Sea Level SpE!f'""f'"":V-SUI! p·...la..:a..:lI\ÏG SERVlc:ê15 A Halliburton Company Survey Ref: svy4457 BP EXPLORA TION (ALASKA) INC. " Survey Report for 05-24A Your Ref: API 500292220401 Job No. AKZZ3374225, Surveyed: 25 November, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Verticat Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3884.50 32.250 79.780 3450.41 3513.51 235.55 N 1412.45 E 5948669.34 N 699687.92 E 930.59 Tie On Point MWD+IIFR+MS 3891.00 32.280 79.800 3455.91 3519.01 236.17 N 1415.86 E 5948670.04 N 699691.32 E 0.491 932.81 Window Point 3938.08 30.200 70.480 3496.18 3559.28 242.36 N 1439.41 E 5948676.85 N 699714.70 E 11.165 946.87 3970.38 31.730 64.850 3523.89 3586.99 248.68 N 1454.76 E 5948683.58 N 699729.88 E 10.138 954.56 . 4001.47 33.180 59.980 3550.12 3613.22 256.41 N 1469.53 E 5948691.69 N 699744.44 E 9.610 960.91 4029.48 33.640 56.010 3573.51 3636.61 264.59 N 1482.60 E 5948700.21 N 699757.29 E 7.974 965.67 4061.95 35.320 51.840 3600.28 3663.38 275.42 N 1497.44 E 5948711.43 N 699771.84 E 8.921 970.07 4094.63 36.910 47.820 3626.68 3689.78 287.85 N 1512.15E 5948724.24 N 699786.21 E 8.729 973.35 4121.88 36.740 45.190 3648.49 3711.59 299.08 N 1523.99 E 5948735.78 N 699797.76 E 5.818 975.20 4157.02 34.270 44.420 3677.10 3740.20 313.56 N 1538.38 E 5948750.63 N 699811.75 E 7.143 976.91 4188.38 32.680 43.710 3703.26 3766.36 325.99 N 1550.41 E 5948763.37 N 699823.45 E 5.222 978.14 4216.14 31.520 44.670 3726.77 3789.87 336.57 N 1560.69 E 5948774.22 N 699833.45 E 4.565 979.22 4250.13 28.800 47.200 3756.16 3819.26 348.45 N 1572.94 E 5948786.42 N 699845.39 E 8.831 980.97 4281.25 26.130 49.350 3783.77 3846.87 358.01 N 1583.64 E 5948796.26 N 699855.84 E 9.151 983.02 4309.70 24.210 50.970 3809.52 3872.62 365.76 N 1592.93 E 5948804.26 N 699864.92 E 7.169 985.15 4341.65 23.440 52.370 3838.74 3901.84 373.77 N 1603.05 E 5948812.53 N 699874.82 E 2.990 987.75 4375.20 23.420 53.060 3869.53 3932.63 381.85 N 1613.67 E 5948820.88 N 699885.22 E 0.820 990.69 4404.37 23.380 56.980 3896.30 3959.40 388.49 N 1623.15 E 5948827.77 N 699894.53 E 5.338 993.69 4437.80 23.170 64.900 3927.02 3990.12 394.90 N 1634.67 E 5948834.48 N 699905.88 E 9.376 998.40 4497.50 24.000 74.580 3981.75 4044.85 403.11 N 1657.02 E 5948843.28 N 699928.00 E 6.628 1010.24 4590.92 24.100 74.190 4067.06 4130.16 413.36 N 1693.69 E 5948854.49 N 699964.39 E 0.201 1031.74 . 4682.86 23.840 73.320 4151.07 4214.17 423.80 N 1729.55 E 5948865.87 N 699999.96 E 0.477 1052.49 4775.56 23.500 80.360 4235.99 4299.09 432.28 N 1765.72 E 5948875.30 N 700035.90 E 3.069 1074.76 4869.41 23.700 80.160 4321.99 4385.09 438.63 N 1802.75 E 5948882.63 N 700072.75 E 0.230 1099.04 4962.62 23.260 80.360 4407.48 4470.58 444.92 N 1839.35 E 5948889.87 N 700109.17 E 0.480 1123.04 5056.00 24.960 81.790 4492.72 4555.82 450.82 N 1877.04 E 5948896.76 N 700146.68 E 1.925 1148.11 5149.60 24.770 81.150 4577.64 4640.74 456.66 N 1915.96E 5948903.62 N 700185.44 E 0.352 1174.18 5243.13 26.470 80.210 4661.97 4725.07 463.22 N 1955.86 E 5948911.23 N 700225.16 E 1.869 1200.53 5336.65 26.220 79.960 4745.78 4808.88 470.36 N 1996.74 E 5948919.45 N 700265.83 E 0.292 1227.25 5430.27 28.380 80.860 4828.96 4892.06 477.50 N 2039.08 E 5948927.70 N 700307.97 E 2.349 1255.09 5521.96 28.420 80.770 4909.62 4972.72 484.46 N 2082.13 E 5948935.80 N 700350.82 E 0.064 1283.60 5615.73 27.930 80.520 4992.28 5055.38 491.66 N 2125.82 E 5948944.14 N 700394.30 E 0.538 1312.44 5709.48 27.610 80.370 5075.23 5138.33 498.91 N 2168.89 E 5948952.52 N 700437.17 E 0.349 1340.77 5803.11 27.000 80.060 5158.43 5221.53 506.21 N 2211.22 E 5948960.93 N 700479.29 E 0.669 1368.51 5896.13 29.280 82.090 5240.45 5303.55 512.98 N 2254.55 E 5948968.85 N 700522.43 E 2.658 1397.35 13 December, 2004 - 17:38 Page 2 of 7 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. .. Survey Report for 05·24A Your Ref: API 500292220401 Job No. AKZZ3374225, Surveyed: 25 November, 2004 North Slope Alaska BPXA Measured True 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) (O/100ft) 5989.07 29.190 81.890 5321.55 5384.65 519.31 N 2299.50 E 5948976.35 N 700567.20 E 0.143 1427.71 6082.47 29.230 81.660 5403.07 5466.17 525.83 N 2344.61 E 5948984.06 N 700612.12 E 0.128 1458.08 6175.28 28.680 82.600 5484.28 5547.38 531.99 N 2389.12 E 5948991.39 N 700656.45 E 0.769 1488.22 6267.61 29.850 84.890 5564.83. 5627.93 536.89 N 2433.98 E 5948997.47 N 700701.17 E 1.754 1519.43 6361.31 32.200 85.180 5645.12 5708.22 541.06 N 2482.09 E 5949002.91 N 700749.15 E 2.513 1553.60 . 6454.40 32.580 85.120 5723.73 5786.83 545.28 N 2531.78 E 5949008.43 N 700798.71 E 0.410 1588.96 6547.74 33.040 85.300 5802.18 5865.28 549.50 N 2582.18 E 5949013.98 N 700848.98 E 0.504 1624.85 6641.72 33.330 85.190 5880.83 5943.93 553.76 N 2633.44 E 5949019.59 N 700900.11 E 0.315 1661.38 6735.56 33.410 84.130 5959.20 6022.30 558.57 N 2684.83 E 5949025.75 N 700951.36 E 0.627 1697.66 6830.03 34.490 78.020 6037.59 6100.69 566.78 N 2736.88 E 5949035.33 N 701003.18 E 3.787 1732.25 6921.98 35.370 76.990 6112.97 6176.07 578.18 N 2788.28 E 5949048.07 N 701054.26 E 1.152 1764.30 7014.49 34.980 76.900 6188.59 6251.69 590.22 N 2840.20 E 5949061.48 N 701105.84 E 0.425 1796.33 7107.50 32.360 78.180 6265.99 6329.09 601.36 N 2890.54 E 5949073.94 N 701155.87 E 2.918 1827.73 7199.93 29.380 78.340 6345.32 6408.42 611.01 N 2936.96 E 5949084.81 N 701202.02 E 3.225 1857.09 7293.49 29.510 77.520 6426.79 6489.89 620.63 N 2981.94 E 5949095.61 N 701246.73 E 0.453 1885.37 7386.66 30.090 77.610 6507.64 6570.74 630.60 N 3027.16 E 5949106.77 N 701291.67 E 0.624 1913.59 7479.74 30.720 76.680 6587.92 6651.02 641.08 N 3073.08 E 5949118.46 N 701337.30 E 0.845 1942.04 7572.98 30.690 76.860 6668.09 6731.19 651.98 N 3119.43E 5949130.57 N 701383.35 E 0.104 1970.54 7667.35 27.860 79.190 6750.40 6813.50 661.59 N 3164.55 E 5949141.37 N 701428.20 E 3.232 1998.92 7759.49 27.160 78.620 6832.12 6895.22 669.78 N 3206.31 E 5949150.65 N 701469.73 E 0.812 2025.65 7852.81 26.550 77.790 6915.38 6978.48 678.39 N 3247.58 E 5949160.35 N 701510.76 E 0.767 2051.73 7947.10 26.590 77.010 6999.71 7062.81 687.59 N 3288.74 E 5949170.63 N 701551.66 E 0.372 2077.34 . 8039.90 28.280 83.310 7082.09 7145.19 694.82 N 3330.82 E 5949178.97 N 701593.54 E 3.617 2104.93 8133.17 27.480 83.360 7164.53 7227.63 699.89 N 3374.14 E 5949185.17 N 701636.71 E 0.858 2134.86 8227.42 27.570 82.180 7248.11 7311.21 705.37 N 3417.35 E 5949191.79 N 701679.76 E 0.586 2164.44 8320.99 29.440 81.240 7330.34 7393.44 711.82 N 3461.53 E 5949199.40 N 701723.76 E 2.055 2194.14 8415.50 29.170 80.990 7412.75 7475.85 718.96 N 3507.24 E 5949207.74 N 701769.26 E 0.314 2224.56 8509.35 28.560 79.860 7494.94 7558.04 726.49 N 3551.91 E 5949216.45 N 701813.72 E 0.872 2253.94 8603.45 27.720 79.780 7577.92 7641.02 734.34 N 3595.59 E 5949225.44 N 701857.17 E 0.894 2282.36 8697.31 26.530 79.700 7661.45 7724.55 741.96N 3637.70 E 5949234.17 N 701899.07 E 1.268 2309.72 8788.81 25.660 79.670 7743.63 7806.73 749.17 N 3677.30 E 5949242.41 N 701938.46 E 0.951 2335.42 8882.62 25.650 79.170 7828.19 7891.29 756.62 N 3717.22 E 5949250.92 N 701978.18 E 0.231 2361.21 8974.17 24.100 78.480 7911.24 7974.34 764.08 N 3755.00 E 5949259.37 N 702015.75 E 1.722 2385.36 9067.88 23.480 77.200 7996.99 8060.09 772.04 N 3791.95 E 5949268.30 N 702052.47 E 0.861 2408.55 9160.61 25.980 79.130 8081.21 8144.31 779.96 N 3829.92 E 5949277.22 N 702090.22 E 2.833 2432.54 13 December, 2004 - 17:38 Page 3 of 7 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-24A Your Ref: API 500292220401 Job No. AKZZ3374225, Surveyed: 25 November, 2004 North Slope Alaska BPXA Measured True 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) (0/100ft) 9254.32 26.310 77. 720 8165.33 8228.43 788.25 N 3870.37 E 5949286.57 N 702130.44 E 0.751 2458.20 9321.25 29.060 81.690 8224.60 8287.70 793.75 N 3900.95 E 5949292.88 N 702160.87 E 4.945 2478.09 9409.51 29.800 80.480 8301.47 8364.57 800.48 N 3943.79 E 5949300.73 N 702203.52 E 1.075 2506.58 9438.21 32.140 80.130 8326.08 8389.18 802.97 N 3958.35 E 5949303.60 N 702218.00 E 8.177 2516.13 9470.31 33.770 79.750 8353.01 8416.11 806.02 N 3975.54 E 5949307.10 N 702235.11 E 5.119 2527.34 . 9502.79 38.070 79.200 8379.31 8442.41 809.50 N 3994.27 E 5949311.08 N 702253.74 E 13.276 2539.45 9531.09 39.200 78.000 8401.41 8464.51 813.00 N 4011.59 E 5949315.03 N 702270.96 E 4.791 2550.47 9565.18 45.000 76.940 8426.70 8489.80 817.97 N 4033.89 E 5949320.58 N 702293.12 E 17.141 2564.36 9596.50 50.330 74.820 8447.78 8510.88 823.63 N 4056.33 E 5949326.83 N 702315.40 E 17.736 2577.91 9623.85 50.510 72.300 8465.21 8528.31 829.59 N 4076.54 E 5949333.33 N 702335.45 E 7.132 2589.56 9658.52 49.650 71.560 8487.46 8550.56 837.84 N 4101.82 E 5949342.24 N 702360.50 E 2.972 2603.62 9689.57 49.750 73.070 8507.54 8570.64 845.03 N 4124.38 E 5949350.02 N 702382.87 E 3.723 2616.28 9717.18 52.560 72.930 8524.86 8587.96 851.32 N 4144.94 E 5949356.85 N 702403.26 E 10.185 2627.99 9751.49 52.100 72.710 8545.83 8608.93 859.34 N 4170.89 E 5949365.55 N 702428.98 E 1 .434 2642.71 9782.98 51.390 71.680 8565.32 8628.42 866.90 N 4194.43 E 5949373.73 N 702452.32 E 3.418 2655.89 9810.94 51.170 77.590 8582.82 8645.92 872.68 N 4215.45 E 5949380.06 N 702473.18 E 16.507 2668.27 9905.47 50.230 79.290 8642.70 8705.80 887.34 N 4287.11 E 5949396.60 N 702544.42 E 1.710 2713.74 10000.38 51.250 77.870 8702.76 8765.86 901.90 N 4359.14 E 5949413.05 N 702616.04 E 1.580 2759.56 10093.37 50.170 79.040 8761.65 8824.75 916.31 N 4429.64 E 5949429.31 N 702686.15 E 1.516 2804.31 10128.33 53.600 84.170 8783.23 8846.33 920.29 N 4456.84 E 5949434.01 N 702713.23 E 15.146 2822.58 10159.47 58.350 89.100 8800.66 8863.76 921.78 N 4482.59 E 5949436.17 N 702738.93 E 20.114 2841.35 . 10187.94 63.660 92.260 8814.46 8877.56 921.46 N 4507.47 E 5949436.51 N 702763.81 E 21.023 2860.62 10221.93 70.220 95.230 8827.77 8890.87 919.40 N 4538.66 E 5949435.27 N 702795.04 E 20.905 2885.83 10253.54 74.580 98.390 8837.33 8900.43 915.82 N 4568.56 E 5949432.48 N 702825.03 E 16.763 2911.04 10280.76 77.500 100.550 8843.89 8906.99 911.47 N 4594.61 E 5949428.82 N 702851 .19 E 13.205 2933.79 10313.39 79.830 102.790 8850.31 8913.41 905.00 N 4625.94 E 5949423.17 N 702882.67 E 9.813 2961.95 10345.89 81.830 105.540 8855.49 8918.59 897.15 N 4657.04 E 5949416.14 N 702913.97 E 10.375 2990.83 10374.08 80.950 105.040 8859.71 8922.81 889.80 N 4683.93 E 5949409.50 N 702941.04 E 3.581 3016.15 10407.25 84.120 106.430 8864.01 8927.11 880.88 N 4715.58 E 5949401.42 N 702972.92 E 10.421 3046.13 10438.19 87.470 104.740 8866.28 8929.38 872.59 N 4745.30 E 5949393.92 N 703002.84 E 12.120 3074.22 10465.57 87.780 106.950 8867.42 8930.52 865.12 N 4771.61 E 5949387.15 N 703029.34 E 8.144 3099.18 10497.39 87.220 109.480 8868.81 8931.91 855.18 N 4801.81 E 5949378.01 N 703059.79 E 8.136 3128.69 10531.36 87.220 112.870 8870.45 8933.55 842.93 N 4833.44 E 5949366.59 N 703091.74 E 9.968 3160.81 10560.02 87.590 115.890 8871.75 8934.85 831.11 N 4859.51 E 5949355.47 N 703118.11 E 10.605 3188.38 10591.23 88.640 118.380 8872.78 8935.88 816.89 N 4887.27 E 5949341.98 N 703146.24 E 8.654 3218.78 13 December, 2004 - 17:38 Page 4 of 7 DrillQuest 3.03.06.006 BP EXPLORATION (ALASKA) INC. Survey Report for 05-24A Your Ref: API 500292220401 Job No. AKZZ3374225, Surveyed: 25 November, 2004 North Slope Alaska BPXA Measured True 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) (0/100ft) 10624.58 87.220 121.800 8873.98 8937.08 800.18 N 4916.10 E 5949326.03 N 703175.50 E 11.097 3251.61 10652.98 87.220 123.580 8875.36 8938.46 784.86 N 4939.98 E 5949311.35 N 703199.76 E 6.260 3279.74 10686.53 87.660 125.510 8876.86 8939.96 765.86 N 4967.58 E 5949293.08 N 703227.86 E 5.895 3313.11 10717.86 87.280 126.950 8878.24 8941.34 747.36 N 4992.83 E 5949275.25 N 703253.59 E 4.749 3344.34 10744.88 86.790 127.910 8879.64 8942.74 730.96 N 5014.26 E 5949259.42 N 703275.44 E 3.985 3371.29 . 10779.96 88.640 131.520 8881.04 8944.14 708.56 N 5041.21 E 5949237.74 N 703302.98 E 11 .556 3406.34 10811.07 89.010 133.620 8881.68 8944.78 687.52 N 5064.12 E 5949217.32 N 703326.43 E 6.853 3437.41 10838.82 88.640 134.220 8882.25 8945.35 668.28 N 5084.10 E 5949198.60 N 703346.91 E 2.540 3465.09 10873.35 87.590 136.620 8883.38 8946.48 643.70 N 5108.32 E 5949174.67 N 703371.77 E 7.583 3499.44 10904.83 87.290 139.000 8884.79 8947.89 620.40 N 5129.44 E 5949151.94 N 703393.50 E 7.613 3530.60 10932.85 88.030 142.240 8885.93 8949.03 598.76 N 5147.20 E 5949130.77 N 703411.82 E 11.851 3558.11 10967.86 88.580 147.430 8886.97 8950.07 570.17 N 5167.35 E 5949102.72 N 703432.71 E 14.901 3591.92 10998.27 88.700 150.860 8887.69 8950.79 544.07 N 5182.94 E 5949077.04 N 703448.99 E 11.283 3620.64 11027.17 88.830 153.160 8888.31 8951.41 518.56 N 5196.50 E 5949051.90 N 703463.21 E 7.969 3647.43 11059.67 88.150 156.350 8889.17 8952.27 489.18 N 5210.35 E 5949022.89 N 703477.84 E 10.033 3676.93 11090.99 87.470 158.390 8890.37 8953.47 460.29 N 5222.40 E 5948994.33 N 703490.63 E 6.861 3704.72 11118.34 87.410 159.340 8891.59 8954.69 434.81 N 5232.25 E 5948969.11 N 703501.15 E 3.477 3728.65 11152.06 87.350 162.820 8893.13 8956.23 402.95 N 5243.17 E 5948937.55 N 703512.91 E 10.311 3757.49 11183.96 86.420 167.230 8894.87 8957.97 372.18N 5251.40 E 5948907.02 N 703521.94 E 14.108 3783.57 11212.01 87.650 169.620 8896.32 8959.42 344.74 N 5257.02 E 5948879.73 N 703528.29 E 9.572 3805.51 11246.77 89.570 169.360 8897.16 8960.26 310.58 N 5263.36 E 5948845.75 N 703535.52 E 5.574 3832.33 . 11277.80 91.730 168.880 8896.81 8959.91 280.11 N 5269.21 E 5948815.44 N 703542.18 E 7.131 3856.40 11306.54 92.530 168.660 8895.74 8958.84 251.94 N 5274.80 E 5948787.43 N 703548.51 E 2.887 3878.79 11340.57 94.700 167.560 8893.59 8956.69 218.71 N 5281.80 E 5948754.40 N 703556.38 E 7.146 3905.51 11370.97 95.070 167.360 8891.01 8954.11 189.14 N 5288.38 E 5948725.01 N 703563.73 E 1.382 3929.55 11398.97 94.570 164.880 8888.65 8951.75 162.06 N 5295.07 E 5948698.11 N 703571.14 E 9.005 3952.09 11432.93 93.520 162.630 8886.26 8949.36 129.54 N 5304.55 E 5948665.85 N 703581.47 E 7.296 3980.25 11464.11 91.730 162.740 8884.83 8947.93 99.80 N 5313.82 E 5948636.37 N 703591.52 E 5.752 4006.47 11491.39 91.910 161.570 8883.96 8947.06 73.85 N 5322.17 E 5948610.65 N 703600.55 E 4.337 4029.55 11525.78 92.160 160.940 8882.74 8945.84 41 .30 N 5333.22 E 5948578.41 N 703612.45 E 1.970 4058.93 11556.90 91.670 157.840 8881.70 8944.80 12.20 N 5344.16 E 5948549.60 N 703624.16 E 10.080 4086.03 11584.82 90.860 157.380 8881.09 8944.19 13.61 S 5354.80 E 5948524.08 N 703635.47 E 3.336 4110.76 11618.99 90.190 156.700 8880.77 8943.87 45.07 S 5368.12 E 5948492.98 N 703649.62 E 2.794 4141.19 11649.25 89.070 153.600 8880.97 8944.07 72.53 S 5380.84 E 5948465.87 N 703663.05 E 10.892 4168.58 11677.98 89.320 153.900 8881.37 8944.47 98.29 S 5393.54 E 5948440.45 N 703676.43 E 1.359 4194.88 13 December, 2004 - 17:38 Page 5 of 7 DrillQuest 3.03.06.006 BP EXPLORATION (ALASKA) INC. Survey Report for 05-24A Your Ref: API 500292220401 Job No. AKZZ3374225, Surveyed: 25 November, 2004 North Slope Alaska BPXA Measured True 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 11 OOft) 11712.40 90.430 151.240 8881.45 8944.55 128.84 S 5409.40 E 5948410.33 N 703693.09 E 8.374 4226.66 11743.59 91.230 147.530 8880.99 8944.09 155.67 S 5425.28 E 5948383.92 N 703709.67 E 12.167 4256.07 11771.63 91.980 145.600 8880.21 8943.31 179.06 S 5440.72 E 5948360.95 N 703725.72 E 7.382 4282.93 11805.44 92.660 141 .850 8878.84 8941.94 206.29 S 5460.70 E 5948334.25 N 703746.41 E 11.263 4315.74 11837.73 91.360 139.900 8877.71 8940.81 231.33 S 5481.07 E 5948309.76 N 703767.43 E 7.255 4347.43 . 11865.37 90.930 138.530 8877.15 8940.25 252.25 S 5499.12 E 5948289.32 N 703786.02 E 5.194 4374.71 11898.17 90.120 133.680 8876.85 8939.95 275.88 S 5521.85 E 5948266.30 N 703809.37 E 14.991 4407.31 11929.37 91.540 131.970 8876.40 8939.50 297.08 S 5544.73 E 5948245.71 N 703832.80 E 7.124 4438.47 11957.31 92.350 128.660 8875.45 8938.55 315.15 S 5566.02 E 5948228.21 N 703854.56 E 12.190 4466.39 11991.65 91.920 124.260 8874.17 8937.27 335.53 S 5593.61 E 5948208.56 N 703882.68 E 12.865 4500.63 12022.88 91.540 123.530 8873.23 8936.33 352.94 S 5619.52E 5948191.84 N 703909.04 E 2.634 4531.67 12050.73 90.190 121.610 8872.81 8935.91 367.93 S 5642.99 E 5948177.47 N 703932.89 E 8.427 4559.28 12144.02 90.560 121.720 8872.20 8935.30 416.90 S 5722.39 E 5948130.61 N 704013.55 E 0.414 4651.58 12238.65 91.110 121.590 8870.82 8933.92 466.56 S 5802.93 E 5948083.09 N 704095.38 E 0.597 4745.20 12308.00 91.110 121.590 8869.48 8932.58 502.88 S 5861.99 E 5948048.33 N 704155.37 E 0.000 4813.79 Projected Survey All data is in Feet (US Survey) 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 Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 130.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12308.00ft., . The Bottom Hole Displacement is 5883.52ft., in the Direction of 94.903° (True). 13 December, 2004 - 17:38 Page 6 of 7 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-24A Your Ref: API 500292220401 Job No. AKZZ3374225, Surveyed: 25 November, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3884.50 3891.00 12308.00 3513.51 3519.01 8932.58 235.55 N 236.17 N 502.88 S 1412.45 E 1415.86 E 5861.99 E Tie On Point Window Point Projected Survey . Survey tool program for 05-24A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 3884.50 0.00 3884.50 3513.51 12308.00 3513.51 BP High Accuracy Gyro (05-24) 8932.58 MWD+IIFR+MS (05-24A) . 13 December, 2004 - 17:38 Page 7 of 7 DrillQuest 3.03.06.006 05-24A Pr.ent Comp,',leti. ~;~~""".._.._~.;~ AGTUA TOR "" BAKER G "KB ELEV " 70' . FROM CTD/DRLG = DRAFT~F. ELEV =.. ? KOP" 3950' ~)(,.A:.0!!!!..:'.~._,.~~~!1.37~:. Datum MO" 10041' ·5ãtumTVD~;~--· aãòO' ss , l1G-S/4" CSG, 45.5#, H.. 'I J-55, ID "" 9.950" I I J,891 17518" EZSV Bridge 'H" 4 'I P~9 ,100 rOPOfSÀNO'H i 7518,'" 29.7'# , L-aoH"'" 9583' Casìng I.D. " 6.875" l~n~~~~~;~r~°:J1 10286' DATE REV BY coMMENTs "Ï18122Í91, ÕRÎGINALCOM PLErION '05123193 LAST WORKOVER 02io5l02RNI'I'P CORRECTIONS i 03114104 DAV/TLH GLV C/O , 05116/04 FWElKA ¡ç DUMP SA NO; FISH , 05127/04 MJAIKAK CHEM CUT TBG , I 2, 177'H4112" 'X' landing nipple, ID" 3.813" I r' 3,,950' HSidÏàtrackOff cement plug \ \ GA S LIFT MA NORELS ST MD lYO OEV TYPE '5 3281'3004' 3341/2" Xi" K8&2 4 4983 4489 2341/2" Xi" K8&2 3 6308 5663 31 4112" Xi" KB&2 2 .7467 .6640 3041/2" X 1" KB&2 1 8455 7510. 29 4 1/2" Xi" KBG-2 VALVE DCK DV OV DV OV LA TCH BEl< SK SK SK Sf< ,.- I 9.149' H4 112" 'X' landing nipple, ID" 3.813" ,I 9,110" H7" X 4 112" Baker $-3 packer I 9,193" H4 111" 'x' landing nipple, 10= 3.813" I (9,214" H4 1/2" 'XN' landing nlpple,ID "I 3.75" I I 9227' HWlEG 4112",12.6#,130-80, VAM TC I .11 7" X, 5" Baker Flex-Lock Lnr hngr I 9,221', andZXPpkrwithTBS . . ~!\4B H?~:B#, L-IDB1GM 1 ':terfelntervals @ 6 SPF: 10335' -10505' 10740' -10960'; 11000' -11040'; 11330' -11350" 11440' -11560" 11600'-11730" . . J ., . , 11800' -11930'; 12100' -12210' ,~ (I ~ I. ~ H41f?", 12.6#, L-80.IBT-Msolîd liner I \~~ DATE .09112/04 , 11/29104 REv BY , col\M\llEN1"s . dew \Proþosedco~lêtlon RB "Present CoJT4)letion ): .~ ""'''' PRUDHOEBA Y UNIT welL 05-24A PERMIT No: API No: So-029-22204-01 SEe 32, T11 N, R15E 4865.57 FEL 2400.84 FNI.. - BP Exploration (Alaska) -- e @~@~t rtJì'-cJ r~-_®@-/l® II @ _ W _ 1: lW f}1j ---' LrJ æ) _ ~ flU FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS / CONSERVATION COMMISSION / ¡ 333 W. -r" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 05-24A BP Exploration (Alaska) Inc. Permit No: 204-218 Surface Location: 2203' NSL, 1194' EWL, SEC. 32, TIIN, RI5E, UM Bottomhole Location: 1800' NSL, 1743' EWL, SEC. 33, TIIN, RI5E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission itness any required test. Contact the Commission's petroleum field inspector at 07) 5~ 6 ager). S' 1 BY ORDER OF THE COM ION DATED thisLday of /)~ cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1i-J6Á- 10 ill (l£I04- o Drill aD Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. location of Well (Governmental Section): Surface: 2203' NSL, 1194' EWl, SEC. 32, T11N, R15E, UM Top of Productive Horizon: 3125' NSl, 718' EWl, SEC. 33, T11N, R15E, UM Total Depth: 1800' NSL, 1743' EWl, SEC. 33, T11N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 698282 y- 5948397 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 3950 feet Maximum Hole Angle: 93 . STATE OF ALASKA I ALAS~/L AND GAS CONSERVATION C . MISSION PERMIT TO DRILL 20 MC 25.005 ocr ~~ lUU~ 1b. Current Well Class . . 0 Exp'?ratory aD Developmel}t.Qil¡,:, QMlJl~{>J~.~oJ')~ o Stratigraphic Test 0 ServIce 0 DevelopmeFltiêá9Ci I9SmgreZons·· . 5. Bond: !HI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 12288 TVD 8935 7. Property Designation: ADL 028325 11. Well Nam;~~d o~~;':::'i;: ~~i-J04 12. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. land Use Permit: 13. Approximate SP~d. D , Novemb 1, 2Ó04 ¿: 14. Distance to Nearest Property: 31,000' 9. Acres in Property: 2560 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 63.1 feet 11-05A is 485' away at 11285' MD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3230 Surface: 2350 / Hole 8-3/4" 6-1/8" Casing 7" 4-1/2" Weight 26# 12.6# Grade L-80 L-80 Coupling length MD TVD MD TVD (including stage data) BTC-M 9403' Surface Surface 9403' 8358' 270 sx Class 'G', 198 sx 'G' ", IBT-M 3034' 9253' 8223' 12287' 8935' 356 sx Class 'G' (" ............ . ",' " ',.: ': :;'c" :"::,:,<,:",,:,::,,.\ 19. PRESENT WEll CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) . Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD 10290 9100 9000 9000 7943 Structural Conductor 110' 20" 11 cu yds Arcticset 110' 110' Surface 3892' 10-3/4" 1300 sx CS III, 350 sx 'G', T J 184 sx CS II 3892' 3521' Intermediate 9583' 7-5/8" 675 sx Class 'G', 265 sx Class 'G' 9583' 8462' Production liner 1006' 5-1/2" 120 sx Class 'G' 9280' - 10286' 8193' - 9096' 20. Attachments !HI Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8744' - 8964' !HI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report !HI Drilling Fluid Program !HI 20 AAC 25.050 Requirements Perforation Depth MD (ft): 9902' - 10144' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Isaacson Title Senior Drilling Engineer Date: Contact Dave Wesley, 564-5153 Phone Permit APPlti I Date: Mud log Re ui ec. Directional Survey Required See cover letter for other requirements DYes ~No }šYes 0 No PermitTo Drill Number: 2.0 7'- 2/ ~ 50- 029-22204-01-00 Conditions of Approval: Samples Required 0 Yes ~No Hydrogen Sulfide Measures ~Yes 0 No Other: Tes.t BOPE' ":;00 f\;.t', Appmved avo Ú Form 10-401 Revised 1)6/2004 APPROVED BY THE COMMISSION Dme 'i~t~;caœ . . I Well Name: I 5-24A Planned Well Summary Well 5-24A Well Type Horizontal Sidetrack Producer Target Objective Zone 1 A/1 B I AFE Number: I PBD 4P2299 I I API Number: I 50-029-22204-01 Surface I Northing I Easting I Offsets I TRS I Location 5,948,396.67 698,282.17 2,202' FSL 11,194' FWL 11 N, 15 E, 32 /' Target I Northina I Easting I Offsets Location 5,949,447.00 703,056.00 2,154' FNL 1718' FWL I TRS 11 N, 15 E, 33 Bottom I Northing I Eastina Location 5,948,150.00 704,120.00 I Offsets I TRS I 1,800' FSL/1,743' FWL 11 N, 15 E, 33 ./ I Planned KOP: I 3,950' md 1 3,568' tvd I Planned TD: 112,288' md 1 8,935' tvd I Rig: I Nabors 2ES I / I CBE: 134.60' I RTE: /63.10' . Proximity Issues: Directional Proaram Wp06 I Exit point: I 3,9S0' md /3,SOS' sstvd -93.00 from -11,SOO' to -11,700' in the planned 61/8" production section. There is one close approach issue in drilling S-24A. Well 05-0SA has a / center-te-center distance of 354' feet at 12,287'md, which is planned TO. This well bore, 5-0SA, is plugged and abandoned. All other surrounding wells pass major risk criteria. Standard MWD with IIFR / Cassandra. We/l11-0SA, with center-te-center distance of -48S' at 11,28S' md. 31,000' to the nearest PBU property line. Approved Well plan: Maximum Hole Inclination: Survey Program: Nearest Well within pool: Nearest Property Line S-24A Sidetrack Page 1 Hole Section: 8 %" intermediate: 6 1/8" production: Cased Hole: Open Hole: . . Loaaina Proaram Required Sensors / Service Real time MWD Dir/GRlRes/PWD throughout the interval Real time MWD Dir/GRlRes/ABI throughout the interval. Two sample catchers. None planned None planned Mud Proaram Type lSND Hole Section / operation: I Density (ppg) I Viscosity I PV 9.5 -10.0 45 - 55 12 -16 Kick off from cement plug, drill 8 %" interval to BHRZ YP I Tau 0 I API FL I pH 22 - 28 3 - 7 5 - 7 9.0 Hole Section / operation: I Density ~~.g) Viscosity I 10.0U- I 45-55 Hole Section I operation: I Density (ppg) I Viscosity I 8.5 - 8.6 45 - 55 Type lSND Type Flo-Pro PV 12 - 16 Drilling 8 3/4" interval from BHRZ to section TD YP I Tau 0 I API FL I pH 22 - 28 3 - 7 4 - 5 9.0 PV 8-12 Drilling 6 1/8" production interval YP I MBT I API FL ~-~ ~ 4-6 pH 9.0-9.5 Casina I Tubina Proaram Hole CasinglTubing wt. Grade Conn~ion Length Top Size Size ./ md/tvd 83/4" 7" 26.0# l-80 BTC-M 9,403' Surface 61/8" 4 Y2" 12.6# l-80 IBT-M 3,034' 9,253' I 8,223' Tubing 4 Y2" 12.6# 13Cr-80 VAM TOP 9,253' Surface Cementina Proaram Casing String: Slurry Design Basis: Fluids Sequence / Volume: Casing String: Slurry Design Basis: Fluids Sequence / Volume: 5-24A Sidetrack Bottom md/tvd 9,403' I 8,358' 12,287' I 8,935' 9,253' I 8,223' 7",26#, l-80, BTC-M long string lead slurry: -3,053' of 7" X 8 3/4" annulus with 40% excess. Tail slurry: 1,000' of 7" X 8 3/4" annulus with 40% excess, plus -86' of 7", 26.0#, shoe track. Pre-Flush None planned Spacer 45bbls MUdPUS~2PP9 ~) Lead Slurry 115.0bbl/646 cf / .. sx Class 'G', 12.0pp·. cf/sk. Tail Slurry 41.0bbll 230cf I ,9 sx Class 'G', 15.8PP9·~cf/Sk. 4 1/2", 12.6#, l-80, IBT-M solid production liner Lead slurry: none planned Tail slurry: 2,885' of 41/2" X 61/8" annulus with 40% excess, plus 85' of 4 1/2", 12.6# shoe track, plus 150' of 7" X 4 Y2" liner lap, plus 200' of 7" X 4" drill pipe annulus. Pre-Flush 25bbls CW 1 00 Spacer 35bbls MudPUSH at 9.6ppg lead Slurry None planned . L) ~) Tail Slurry 76.0bbl/427 cf /~ßx Class 'G', 15.8ppg; !3~f/Sk. Page 2 . Test 103/4" casing (J-55) 10 :X" casing shoe 7" casing 7" casing shoe 4 W' production liner . Casina I Formation Intearitv Testina Test Point Cement plug to surface 20' new form. beyond casing stub Float equipment to surface 20' new formation beyond shoe Float equipment to surface Test pressure 2,500psi surface 12.0ppg EMW 3,500psi surface 10.0ppg EMW 3,500psi surface -"- Test Type 30 min recorded FIT 30 min recorded FIT 30 min recorded Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: Maximum anticipated BHP: Maximum surface pressure: Calculated kick tolerance: Planned BOPE test pressure: BOPE configuration for 7" intermediate casing. Well Interval: Maximum anticipated BHP: Maximum surface pressure: Calculated kick tolerance: Planned BOPE test pressure: Planned completion fluid: 8 :X" intermediate interval 3,050psi at 8,295' sstvd. æ' psi (based upon BHP and a full column of gas from TD@0.1 0 psi/ft) ;" o Is with 12.0ppg EMW FIT Opsi low / 3,500psi high - 7 day test cycle (Pre drilling phase) Will C/O to 7" pipe rams. 6 1/8" production interval 3,230psi at 8,800' sstvd. 2,3gDpsi (based upon BHP and a full column of gas from TD @ 0.10 pSi/ft) /' InfÍniWwith 10.~MW FIT. 250þsi low / :t5Q.Df1Ši high - 14 day test cycle (Drilling operations) 8.4ppg seawãfér / 7.1 ppg Diesel Disposal No annular injection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at 05-04. Any metal cuttings should be sent to the North Slope Borough. All drilling and completion fluids and other Class II wastes are to be hauled to 05-04 for injection. All Class I wastes are to be hauled to Pad 3 for disposal. Annular Injection: Cuttings Handling: Fluid Handling: 5-24A Sidetrack Page 3 . . Geoloaic Proanosis Formation MD TVDbkb TVDss Comments SV1 UG4 4,745 UG4A UG3 4,900 UG1 5,635 WS2 6,155 WS1 6,350 CM3 6,615 CM2 7,070 CM1 7,660 THRZ 8,807 BHRZ 8,255 ID.L LCU TKNG TJG TJF TJE TJD TJC TJB TJA 8,275 TSGR 8,295 TSHU TSAD (TZ4) 8,403 TCGL (TZ3) 8,568 BCGL (TZ2C) 8,616 23SB (TZ2Bu) 8,682 22TS (TZ2BI) 8,719 22N 8,733 21TS (TZ2A) 8,769 ~,&, TZ1B 8,821 -3,300psi (7.2ppg EMW) TDF (TZ1A) 8,870 BSAD @ landing 8,888 TD Criteria I TD Criteria: I Planned TD will be the given coordinates. The end of the polygon is a hard line due to close proximity with a fault beyond planned TD. Fault Proanosis Fault Fault #1 Formation Encountered CM2 MD Intersect 8,075' TVDss Intersect -7,120' Estimated Throw -20' Direction of Throw Down 1 Up Uncertainty +/- 100' 5-24A Sidetrack Page 4 . . Operations Summary Pre-Ria Operations: 1. Well was secured with a sand-back on 2/29/2004, after T X IA communication and a PC leak was suspected. PC leak confirmed, but location uncertain. 2. MIT - T to 3,000psi failed, with LLR of 3.0bpm at 1 ,000psi on 3/16/2004. 3. MIT-OA failed to 3,000psi failed on 5/5/2004. The 10 %" shoe was not cementedf'Arctic packed". 4. PPPOT-IC failed on 5/14/2004. LOS were tight; functioned all LOS and re-torque to 450 ft-Ibs. 5. The 3112" tubing has been chemical cut at -8,930'md on 5/27/2004. 6. The latest drift/tag stopped at -8,890'. May be tubing cut. Approximately 1 gallon sand recovered from bailer on 6/5/2004. 7. Circulate the well to brine, as necessary to balance, by circulating down the tubing through the tubing cut. Circulation may 'short circuit' at suspected tubing leak at -7,441'. Freeze protect to -2,200' MD with diesel. 8. Function all 7 5/8" casing and tubing Lock Down Screws; repair or replace as needed. The 7 5/8" casing will be cut and pulled and the tubing spool will likely be changed out during the work-over. 9. Bleed casing and annulus pressures to zero. 10. Set a BPV. Secure the well. Level the pad as necessary. Ria Operations: 1. Mil RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to 9.8ppg brine. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. RlU. Pull the 4%" X 3 112" tubing from the cut at -8,930'md and above. Be prepared to spool up the Chemical Injection line. The CI mandrel is at 8,889'md. 5. Be prepared to RlU SWS E-line and run a 'Free-Point' if the tubing will not pull free from the tubing cut at 8,930'md. It is possible the tubing string is sanded in on the backside. If it becomes necessary to run the free-point tool, a second chemical cut will be made above the stuck point. An EZSV and cement plug will be set as deep as possible. 6. RlU e-line. RIH with a GRlJB to the tubing stump at -8,930'md. POOH. 7. Alternatively, M/U a milling assembly and RIH, P/U 4" drill pipe. Tag the tubing stump and circulate hole clean. POOH. 8. RlU SWS E-line. M/U a HES 7 5/8" EZSV. RIH and set the bridge plug at the tubing stump. POOH. 9. RIH with 4" drill pipe and a cementing stinger assembly. 10. RlU Dowell and place a -20bbl cement P&A plug on top of the EZSV. The 20bbl cement plug will fill -435' of the 7 5/8", 29.7ppf casing. POOH. 11. RlU SWS E-line. 12. M/U a HES 7 5/8" EZSV bridge plug. RIH and set the EZSV at -4,100'md. POOH. RID E-line. 13. M/U a Baker 7 5/8" casing cutting assembly. RIH to -4,000'md. Cut the 7 5/8" casing per Baker representative instructions. POOH and UD assembly. 14. RlU a casing spear assembly and unseat the casing. Circulate the annulus with brine. Pull the 7 5/8" casing from the cut at -4,000'. 15. M/U a cementing stinger. RIH and place a 45bbl cement kick off plug on top of the EZSV. The top of cement should be approximately 3,800'md. POOH. 16. M/U an 8 %" Dir/GRlRes/PWD drilling assembly. 17. RIH to the top of the cement plug. Test the 10 %", J-55 casing to 2,500 psi for 30 minutes and record. -18. Dress off cement to the 10 %" casing shoe at 3,891'md. / T k s t V ~ 4- 0 I a.f P YO ¡j t>...1. ý 5-24A Sidetrack Page 5 . . 19. Initiate kick off, per directional plan, just below the 10 %" surface shoe. Drill 20 feet of new formation beyond the lower casing stub. Conduct an FIT to 12.0ppg EMW. / 20. Drill section to TD, according to directional proposal. 21. Condition hole, as needed, in preparation for running 7", 26#, L-80, BTC-M casing. 22. RIU and run -9,405' of 7" casing to the top of the Sag River formation. /' 23. Cement the casing, as recommended, by Dowell. 24. Freeze protect the 10 =X" X 7" annulus, once the cement has reached 500psi compressive strength. 25. M/U a 6 1/8" Dir/GRlRes/ABI drilling assembly. RIH to the plugs/float equipment. Test the 7" casing to / 3,500psi for 30 minutes. Record the test. 26. Drill out the float equipment to the 7" casing shoe. / 27. Displace the well to 8.5ppg Flo-Pro drilling fluid. 28. Drill out the shoe plus approximately 20' of new formation. Circulate the well bore clean. 29. Pull up into 7" casing and attempt an FIT to 10.0ppg EMW. 30. Drill ahead, per directional proposal, to -10,185'md. This should place the well bore below the / conglomerate, and at the beginning of the 15°/100' build and turn section. POOH for bitlBHA. 31. M/U assembly, per SSDS recommendation, to achieve the directional requirement. 32. RIH and drill ahead to the end of the 15°/100' directional interval. Trip as required for the final, horizontal BHA. 33. RIH and drill ahead, per directional proposal, to section, well TD. / 34. Condition hole for running 4 1/2", 12.6#, L-80, IBT-M liner. 35. Run and cement the 4 W production liner, extending the liner lap to -9,250'md. POOH. 36. P/U and RIH with Schlumberger 2 W DPC perforating guns. Perforate approximately 1,000' of Z1A/1B interval, per subsurface team. POOH. . . 37. RIU and run a 4 1/2", 12.6#, 13Cr-80, VAM TOP completion, stinging into the 4 1/2" liner tie back / sleeve. 38. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 39. Install a TWC. 40. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. / 41. Freeze protect the well to -2,200'. Install BPV. Secure the well. 42. Rig down and move off. / Post-Ria Operations: 1. Mil RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Mil RU SWS E-line. RIH and perforate approximately 10' of Z2C interval, per subsurface team. 3. Install gas lift valves. 4. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 10/20/04 Estimated Spud Date: 11/01/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 5-24A Sidetrack Page 6 . . Phase 1: Move In I Ria UP I Test BOPE Planned Phase Time 28 hours Planned Phase Cost $70,207 Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto 05-24. However, 05-04 is 60.0' to the North, and 05-27 is 60.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. ~ During MI/RU operations, the 5-24 well bore will be secured with the following barriers: o Tubing: the sand back plug, brine, and a BPV. o IA: Annulus valves and brine. o OA: Annulus valve and kill weight fluid. MIT-OA to 3,000psi on 5/05/2004 failed. ~ Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. ~ The 7 5/8" casing has a leak, but the exact location is unknown. ~ During ND/NU BOPE operations, the 5-24 well bore will be secured with the following barriers: o Tubing: the sand back plug, brine, and a BPV. o IA: Annulus valves and brine. o OA: Annulus valve and kill weight fluid. MIT-OA to 3,000psi, on 5/05/2004, failed. ~ DS 05 is.!!21designated as an HzS site. However, Standard Operating Procedures for HzS precautions should be followed at all times. Recent HzS data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 5-04 12ppm 5-05B 27ppm 5-27A 11ppm 11-05A 7ppm The maximum level recorded of H2S on the pad was 27ppm, in 11/1990. .,..., ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud 5-24A Sidetrack Page 7 . . .Phase 2: De-complete Well Planned Phase Time 133 hours Planned Phase Cost $477,859 Reference RP .:. "De-completions" RP Issues and Potential Hazards ~ Monitor the well to ensure the fluid column remains static, prior to pulling the completion. ~ Have all wellhead and completion equipment NORM-tested;1i retrieval. ~ Note that this wellhead is a FMC At;coSlim-hol~<J.1~~Thru . The tubing hanger is 11" X 4 Y:z" FMC hanger, with 9" LH Acm .. .-. nee the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. ~ There is a 4Y:z" Otis HRQ landing nipple with dual W control lines, and a chemical injection mandrel with a single 3/8" injection line. There were 65 - 4 Y2" clamps, 193 - 3 Y2" clamps, and 17 stainless steel bands used in securing the control lines and chemical injection line. ~ The 3 W', 9.2#, L-80 tubing has been chemical cut at -8,930'md. This was done 5/27/2004, in preparation for a RWO. The lower half of the chemical cutter severing head was left in the hole and could not be fished. ~ Due to the fish, on top of the sand back plug, a pre rig coil tubing cement P&A was not possible. The well bore will be abandoned with an EZSV and cement plug following de-completion to the tubing cut. Phase 5: Drill 8 3/4" Intermediate Hole Interval Planned Phase Time 125 hours Planned Phase Cost $683.272 Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards ~ This well bore will exit the original well into the SV sand below the surface casing shoe. This well bore will drill the Ugnu, Colville, HRZ and the Kingak, to the top of the Sag River formation. Previous DS 05 wells drilled the Kingak with 9.8 to 10.6ppg mud weights. For this well. the HRZ and the Kingak will require a mud weight of 10.2ppg. Maintain mud weight at 10.2ppg, minimally, from above the Kingak to the 7" casing point. Follow all shale drilling practices to minimize potential problems. 5-24A Sidetrack Page 8 . . ~ KICK TOLERANCE: In the worst-case scenario of 9.8ppg pore pressure at the Ugnu depth, a fracture gradient of 12.0ppg at the 10 3/4" casing shoe, and 9.6ppg mud in the hole, the kick tolerance is 40bbls. Phase 6: Run and Cement 7" Intermediate CasinQ Planned Phase Time 34 hours Planned Phase Cost $413,868 Reference RP .:. "Intermediate Casing and Cementing Guidelines" RP .:. "Freeze Protecting an Outer Annulus" RP .:. "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab I surge pressures could initiate Kingak instability problems. ~ Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. ~ Ensure that a Frank's casing fill up tool is on location prior to PU 7" casing. ~ Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor before running casing. ~ During cement displacement of the original 7 5/8" intermediate casing string, returns were marginal at 25%. All returns were lost during the last 60bbls displacement. ~ It will be necessary to freeze protect the 7" X 10 %" annulus, by down squeeze, following the cement job. Ensure the intermediate casing cement has reached at least a 500psi compressive strength prior to freeze protecting annulus. After freeze protecting this OA with 115 bbls of dead crude (-2,400'md, 2,200'tvd), the hydrostatic pressure may be less than the formation pressure immediately below the shoe. Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 155 hours Planned Phase Cost $864,869 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards ~ The parent well, 5-24, experienced no lost circulation events during drilling operations. 5-24A Sidetrack Page 9 . . ~ There were no significant lost circulation events in any of the near surrounding wells. ~ The planned well, 5-24A, is expected to cross no faults while drilling the production interval. There is an existing fault to the SW of the planned trajectory. The planned well path will pass the tip out of this fault with approximately 150 feet of separation. Additionally, there is a mapped fault approximately 450 feet beyond planned well TO. Phase 9: Run 4%" Production Liner Planned Phase Time 30 hours Planned Phase Cost $239,529 Reference RP .:. "Modified Conventional Liner Cementing" RP Issues and Potential Hazards » The completion design is to run a 4 W, 12.6#, L-BO solid liner throughout the production interval. » Differential sticking is possible. The B.6ppg Flo-Pro will be -600psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. » Sufficient 4 W' liner will be run to extend -150' back up into the 7" liner shoe. » Ensure the 4 W' liner top packer is set prior to POOH. Phase 10: DPC Perforate Planned Phase Time 35 hours Planned Phase Cost $309,543 Reference RP .:. "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards » The well will be DPC perforated, -600psi overbalanced, after running the 4 %" liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. » Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Phase 12: Run 4 %" 13Cr-80 Completion Planned Phase Time 26 hours Planned Phase Cost $503,436 Reference RP .:. "Completion Design and Running" RP .:. "Handling and Running 13 Chrome" RP .:. "Tubing connections" RP 5-24A Sidetrack Page 10 . . Issues and Potential Hazards Þ- Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Þ- The completion, as designed, will be to run a 4%",12.6#, 13Cr-80, VAM TOP production tubing string, stinging into the 4 W liner tieback sleeve. Phase 13: ND/NU/Release Ria Planned Phase Time 15 hours Planned Phase Cost $49,111 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards Þ- No wells will require shut-in for the rig move onto 05-24. However, 05-04 is 60.0' to the North, and 05-27 is 60.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. 5-24A Sidetrack Page 11 Plan: 05-24A wp06 (0 CreatedBy: Troy Jakðbosky Checked: WELL DETAILS Tool MVlD Nære 05-24 Slot 24 Date: Laritude Longítude 70"15'47.2(![N 148"23'48.699W f-asting; 69828IJW Northing 5948397.24 +E!·W &&4.00 TVD +NI..s 169.83 SURVEY PROGR..\M Sun'CyiPlan P1nnncd;(¡5.24A~-p06V2: I Name [}epthFm DepthTQ 3949.40 ] 2287.5 J REFERENCE INFORMATION COMPAN\' DETAILS BP Arnooo Shape FORMA nON TOP DETAILS No. TVDPath MDPath Formation I 8358.10 9402.91 TSGR Size CASING DETAILS MD Name 7" 4 TVD No. I 2 05-24A T! rev 05·24A T2 rev 05·24A Well Separation Easting Northing SECTION DETAILS +NI-S +EI-W DLeg TARGET DETAILS +NI-S +EI-W Target VSee TFacc TVD Azi lne MD 112' lrtl 05-24A T3 rev 05-24A n.5 05·24A T4 -9 -9 -2: -3" -4( II See I 2 3 4 5 6 7 8 9 10 ¡¡ 12 13 14 15 16 17 18 19 200 r;¡ :§ <:> <:> ~ :£ -" 1:: o ~ -" S o '" '" .n ,:)- 9001 00 - 600 reI 11t.t 000 o "'- .- 7200 I ¡ i I , 6000 ¡ I I í ¡ , 5400 I , I T í i "',., i .... ,.,." ,., 4800 ¡ 3600 30!J0 I I ¡ ¡ 1800 I - . BP BP Planning Report . Company: Field: Site: WeD: Wellpath: I Plan: Principal: BP Amoco Prudhoe Bay PBDS05 . 05-24 05-24A 05-24A wp06 Yes Date Composed: Version: Tied-to: 8/3012004 28 From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre bggm2004 Site: PB DS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5947204.70 ft 697428.91 ft Latitude: Longitude: North Reference: Grid Convergence: 70 15 35.696 N 148 24 14.424 W True 1.50 deg Well: 05-24 Slot Name: 24 05-24 Well Position: +N/-S 1169.83 ft Northing: 5948397.24 ft Latitude: 70 15 47.201 N +EI-W 884.00 ft Easting : 698281.89 ft Longitude: 148 23 48.699 W Position Uncertainty: 0.00 ft Casing Points MD TV» Diameter Hole Size Name ft ft in in 9402.91 8358.10 7.000 8.500 7" 12287.00 8935.10 4.500 6.125 4 1/2" Formations MD TV» Formations UtItology Dip DiJ'eetion ft ft -.- dég 9402.91 8358.10 TSGR 0.00 Targets Map Map Name Description TV» +N/-8 +EI-W Northing Easting Dip. Dir. ft ft ft ft ft 05-24A T1 rev 8753.10 838.50 4350.60 5949349.97 702608.66 70 15 55.435 N 148 21 42.079 W 05-24A T4 8935.10 -40Q.92 5829.90 5948150.00 704120.00 70 15 43.236 N 148 20 59.054 W 05-24A T3.5 8935.10 -222.00 5436.00 5948318.48 703721.55 70 15 44.998 N 148 21 10.512 W 05-24A T2 rev 8946.10 923.98 4800.00 5949447.25 703055.63 70 15 56.273 N 148 21 28.998 W 05-24A T3 rev 8946.10 66.00 5245.00 5948601.33 703523.04 70 15 47.832 N 148 21 16.064 W 05-24A Well Separation 8946.10 361.51 5179.72 5948895.00 703450.00 70 15 50.739 N 148 21 17.956 W Plan Section Information MD Incl Azim TV» +N/-8 +EI-W DLS BuIld Turn TF'O Target- ft deg deg ft ft ft degl100ft degt100ft degl100ft· deg 3949.40 32.16 79.88 3568.28 241.76 1446.90 0.00 0.00 0.00 0.00 4299.40 34.77 54.78 3861.64 316.06 1621.00 4.00 0.75 -7.17 -90.00 4669.04 28.00 80.31 4178.40 391.88 1793.61 4.00 -1.83 6.91 127.56 9421.64 28.00 80.31 8374.64 767.58 3993.08 0.00 0.00 0.00 0.00 9933.89 58.70 78.00 8742.71 834.95 4333.89 6.00 5.99 -0.45 -3.86 9953.89 58.70 78.00 8753.10 838.50 4350.60 0.00 0.00 0.00 0.00 05-24A T1 rev 10085.25 59.33 68.83 8820.83 870.62 4458.35 6.00 0.48 -6.98 -87.77 10184.39 59.33 68.83 8871.40 901.41 4537.87 0.00 0.00 0.00 0.00 . . BP BP Planning Report Com,...y: BP ArnOCô Field: PriJdhœ f3âY Sitè: PBOS os WeD: ô5'24 W.th: ô5'24A Plan Section Information MÐ Ind A2:ifu TV» +N/..;S +EI-W DLS , BûiId 17ørø T.F0 ft (leg (leg ft ft ft d~1O:Oft ~100ft~100ft (leg" 10464.10 90.00 99.00 8946.10 923.98 4800.00 15.00 10.96 10.78 48.73 05-24A T2 rev 10911.26 90.00 166.07 8946.10 638.65 5110.99 15.00 0.00 15.00 90.00 11196.79 90.00 166.07 8946.10 361.51 5179.72 0.00 0.00 0.00 0.00 05-24A Well Separation 11254.13 90.00 171.23 8946.10 305.31 5190.99 9.00 0.00 9.00 90.00 11353.14 90.00 171.23 8946.10 207.45 5206.08 0.00 0.00 0.00 0.00 11500.18 90.00 158.00 8946.10 66.00 5245.00 9.00 0.00 -9.00 -90.00 05-24A T3 rev 11593.53 93.07 150.18 8943.60 -17.86 5285.74 9.00 3.29 -8.38 -68.51 11654.67 93.07 150.18 8940.33 -70.83 5316.11 0.00 0.00 0.00 0.00 11848.43 90.00 133.00 8935.10 -222.00 5436.00 9.00 -1.58 -8.86 -99.82 05-24A T3.5 12179.17 90.00 103.23 8935.10 -376.12 5724.44 9.00 0.00 -9.00 -90.00 12287.51 90.00 103.23 8935.10 -400.92 5829.90 0.00 0.00 0.00 0.00 05-24A T4 Survey MD IDd ~ TV» Sys TV» NIS EIW DLS MapN ~'pÈ' ft (leg (leg ft ft ft ft ~100ft ft ,ft' " 3949.40 32.16 79.88 3568.28 3505.18 241.76 1446.90 0.00 5948677.01 699721.84 Start Dir 4/100 4000.00 32.22 76.08 3611.11 3548.01 247.38 1473.25 4.00 5948683.31 699748.03 MWD 4100.00 32.66 68.67 3695.54 3632.44 263.61 1524.28 4.00 5948700.88 699798.61 MWD 4200.00 33.53 61.51 3779.35 3716.25 286.61 1573.70 4.00 5948725.17 699847.41 MWD 4300.00 34.76 54.81 3862.13 3799.03 316.26 1621.28 3.95 5948756.07 699894.19 MWD 4400.00 32.46 60.73 3945.43 3882.33 345.82 1668.01 4.00 5948786.84 699940.12 MWD 4500.00 30.47 67.39 4030.75 3967.65 368.69 1714.84 4.00 5948810.94 699986.33 MWD 4600.00 28.86 74.79 4117.67 4054.57 384.78 1761.55 4.00 5948828.25 700032.60 MWD 4669.04 28.00 80.31 4178.40 4115.30 391.88 1793.61 4.00 5948836.20 700064.46 End Dir : 4669 4700.00 28.00 80.31 4205.73 4142.63 394.33 1807.94 0.00 5948839.02 700078.72 MWD 4800.00 28.00 80.31 4294.02 4230.92 402.24 1854.22 0.00 5948848.14 700124.77 MWD 4900.00 28.00 80.31 4382.32 4319.22 410.14 1900.50 0.00 5948857.26 700170.82 MWD 5000.00 28.00 80.31 4470.61 4407.51 418.05 1946.78 0.00 5948866.38 700216.87 MWD 5100.00 28.00 80.31 4558.91 4495.81 425.95 1993.06 0.00 5948875.50 700262.93 MWD 5200.00 28.00 80.31 4647.20 4584.10 433.86 2039.33 0.00 5948884.62 700308.98 MWD 5300.00 28.00 80.31 4735.49 4672.39 441.76 2085.61 0.00 5948893.74 700355.03 MWD 5400.00 28.00 80.31 4823.79 4760.69 449.67 2131.89 0.00 5948902.86 700401.08 MWD 5500.00 28.00 80.31 4912.08 4848.98 457.57 2178.17 0.00 5948911.98 700447.14 MWD 5600.00 28.00 80.31 5000.37 4937.27 465.48 2224.45 0.00 5948921.11 700493.19 MWD 5700.00 28.00 80.31 5088.67 5025.57 473.38 2270.73 0.00 5948930.23 700539.24 MWD 5800.00 28.00 80.31 5176.96 5113.86 481.29 2317.01 0.00 5948939.35 700585.29 MWD 5900.00 28.00 80.31 5265.25 5202.15 489.19 2363.29 0.00 5948948.47 700631.35 MWD 6000.00 28.00 80.31 5353.55 5290.45 497.10 2409.57 0.00 5948957.59 700677.40 MWD 6100.00 28.00 80.31 5441.84 5378.74 505.00 2455.85 0.00 5948966.71 700723.45 MWD 6200.00 28.00 80.31 5530.13 5467.03 512.91 2502.13 0.00 5948975.83 700769.50 MWD 6300.00 28.00 80.31 5618.43 5555.33 520.81 2548.41 0.00 5948984.95 700815.56 MWD 6400.00 28.00 80.31 5706.72 5643.62 528.72 2594.68 0.00 5948994.07 700861.61 MWD 6500.00 28.00 80.31 5795.01 5731.91 536.62 2640.96 0.00 5949003.19 700907.66 MWD 6600.00 28.00 80.31 5883.31 5820.21 544.53 2687.24 0.00 5949012.31 700953.71 MWD 6700.00 28.00 80.31 5971.60 5908.50 552.43 2733.52 0.00 5949021.43 700999.77 MWD 6800.00 28.00 80.31 6059.90 5996.80 560.34 2779.80 0.00 5949030.55 701045.82 MWD 6900.00 28.00 80.31 6148.19 6085.09 568.24 2826.08 0.00 5949039.67 701091.87 MWD 7000.00 28.00 80.31 6236.48 6173.38 576.15 2872.36 0.00 5949048.79 701137.92 MWD 7100.00 28.00 80.31 6324.78 6261.68 584.05 2918.64 0.00 5949057.91 701183.97 MWD 7200.00 28.00 80.31 6413.07 6349.97 591.96 2964.92 0.00 5949067.03 701230.03 MWD 7300.00 28.00 80.31 6501.36 6438.26 599.86 3011.20 0.00 5949076.15 701276.08 MWD 7400.00 28.00 80.31 6589.66 6526.56 607.77 3057.48 0.00 5949085.27 701322.13 MWD 7500.00 28.00 80.31 6677.95 6614.85 615.67 3103.76 0.00 5949094.39 701368.18 MWD 7600.00 28.00 80.31 6766.24 6703.14 623.58 3150.03 0.00 5949103.51 701414.24 MWD 7700.00 28.00 80.31 6854.54 6791.44 631.48 3196.31 0.00 5949112.64 701460.29 MWD . . BP BP Planning Report Survey 7800.00 28.00 80.31 6942.83 6879.73 639.39 3242.59 0.00 5949121.76 701506.34 MWD 7900.00 28.00 80.31 7031.12 6968.02 647.29 3288.87 0.00 5949130.88 701552.39 MWD 8000.00 28.00 80.31 7119.42 7056.32 655.20 3335.15 0.00 5949140.00 701598.45 MWD 8100.00 28.00 80.31 7207.71 7144.61 663.10 3381.43 0.00 5949149.12 701644.50 MWD 8200.00 28.00 80.31 7296.01 7232.91 671.01 3427.71 0.00 5949158.24 701690.55 MWD 8300.00 28.00 80.31 7384.30 7321.20 678.91 3473.99 0.00 5949167.36 701736.60 MWD 8400.00 28.00 80.31 7472.59 7409.49 686.82 3520.27 0.00 5949176.48 701782.66 MWD 8500.00 28.00 80.31 7560.89 7497.79 694.72 3566.55 0.00 5949185.60 701828.71 MWD 8600.00 28.00 80.31 7649.18 7586.08 702.63 3612.83 0.00 5949194.72 701874.76 MWD 8700.00 28.00 80.31 7737.47 7674.37 710.53 3659.11 0.00 5949203.84 701920.81 MWD 8800.00 28.00 80.31 7825.77 7762.67 718.44 3705.38 0.00 5949212.96 701966.87 MWD 8900.00 28.00 80.31 7914.06 7850.96 726.34 3751.66 0.00 5949222.08 702012.92 MWD 9000.00 28.00 80.31 8002.35 7939.25 734.25 3797.94 0.00 5949231.20 702058.97 MWD 9100.00 28.00 80.31 8090.65 8027.55 742.15 3844.22 0.00 5949240.32 702105.02 MWD 9200.00 28.00 80.31 8178.94 8115.84 750.06 3890.50 0.00 5949249.44 702151.07 MWD 9300.00 28.00 80.31 8267.23 8204.13 757.96 3936.78 0.00 5949258.56 702197.13 MWD 9400.00 28.00 80.31 8355.53 8292.43 765.87 3983.06 0.00 5949267.68 702243.18 MWD 9402.91 28.00 80.31 8358.10 8295.00 766.10 3984.41 0.00 5949267.95 702244.52 7" 9421.64 28.00 80.31 8374.64 8311.54 767.58 3993.08 0.00 5949269.66 702253.15 Start Dir 6/100 9500.00 32.69 79.72 8442.24 8379.14 774.45 4032.05 6.00 5949277.56 702291.93 MWD 9600.00 38.68 79.16 8523.42 8460.32 785.16 4089.37 6.00 5949289.77 702348.94 MWD 9700.00 44.68 78.73 8598.07 8534.97 797.92 4154.60 6.00 5949304.24 702413.81 MWD 9800.00 50.67 78.38 8665.38 8602.28 812.59 4227.03 6.00 5949320.81 702485.82 MWD 9900.00 56.67 78.09 8724.59 8661.49 829.01 4305.87 6.00 5949339.31 702564.19 MWD 9933.89 58.70 78.00 8742.71 8679.61 834.95 4333.89 6.00 5949345.98 702592.05 End Dir : 9933 9953.89 58.70 78.00 8753.10 8690.00 838.50 4350.60 0.00 5949349.97 702608.66 05-24A T1 rev 10000.00 58.85 74.77 8m.01 8713.91 847.78 4388.91 6.00 5949360.25 702646.71 MWD 10085.25 59.33 68.83 8820.83 8757.73 870.62 4458.35 6.00 5949384.91 702715.52 End Dir : 1008 10100.00 59.33 68.83 8828.35 8765.25 875.20 4470.18 0.00 5949389.80 702727.22 MWD 10184.39 59.33 68.83 8871.40 8808.30 901.41 4537.87 0.00 5949417.78 702794.20 Start Dir 15/1 0 10200.00 60.89 70.85 8879.17 8816.07 906.07 4550.57 15.00 5949422.78 702806.77 MWD 10300.00 71.47 82.50 8919.62 8856.52 926.71 4639.35 15.00 5949445.74 702894.97 MWD 10400.00 82.68 92.75 8942.01 8878.91 930.54 4736.44 15.00 5949452.13 702991.92 MWD 10464.10 90.00 99.00 8946.10 8883.00 923.98 4800.00 15.00 5949447.25 703055.63 05-24A T2 rev 10500.00 90.00 104.38 8946.10 8883.00 916.71 4835.14 15.00 5949440.91 703090.95 MWD 10600.00 90.00 119.38 8946.10 8883.00 879.54 4927.67 15.00 5949406.19 703184.42 MWD 10700.00 90.00 134.38 8946.10 8883.00 819.69 5007.43 15.00 5949348.47 703265.72 MWD 10800.00 90.00 149.38 8946.10 8883.00 741.24 5068.98 15.00 5949271.67 703329.31 MWD 10900.00 90.00 164.38 8946.10 8883.00 649.53 5108.12 15.00 5949181.02 703370.85 MWD 10911.26 90.00 166.07 8946.10 8883.00 638.65 5110.99 15.00 5949170.22 703374.01 End Dir : 1091 11000.00 90.00 166.07 8946.10 8883.00 552.51 5132.35 0.00 5949084.68 703397.63 MWD 11100.00 90.00 166.07 8946.10 8883.00 455.45 5156.42 0.00 5948988.30 703424.24 MWD 11196.79 90.00 166.07 8946.10 8883.00 361.51 5179.72 0.00 5948895.00 703450.00 05-24A Well Sep 11200.00 90.00 166.36 8946.10 8883.00 358.39 5180.48 9.00 5948891.91 703450.85 MWD 11254.13 90.00 171.23 8946.10 8883.00 305.31 5190.99 9.00 5948839.13 703462.75 End Dir : 1125 11300.00 90.00 171.23 8946.10 8883.00 259.97 5197.98 0.00 5948793.99 703470.94 MWD 11353.14 90.00 171.23 8946.10 8883.00 207.45 5206.08 0.00 5948741.70 703480.42 Start Dir 9/100 11400.00 90.00 167.02 8946.10 8883.00 161.45 5214.92 9.00 5948695.95 703490.46 MWD 11500.00 90.00 158.02 8946.10 8883.00 66.17 5244.94 9.00 5948601.49 703522.97 MWD 11593.53 93.07 150.18 8943.60 8880.50 -17.86 5285.74 9.00 5948518.58 703565.97 End Dir : 1159 11600.00 93.07 150.18 8943.25 8880.15 -23.47 5288.95 0.00 5948513.06 703569.33 MWD 11654.67 93.07 150.18 8940.33 8877.23 -70.83 5316.11 0.00 5948466.43 703597.72 Start Dir 9/100 . BP BP Planning Report . Survey 11700.00 92.36 146.15 8938.18 8875.08 -109.29 5339.99 9.00 5948428.61 703622.60 MWD 11800.00 90.78 137.29 8935.43 8872.33 -187.68 5401.85 9.00 5948351.89 703686.51 MWD 11848.43 90.00 133.00 8935.10 8872.00 -222.00 5436.00 9.00 5948318.48 703721.55 05-24A T3.5 11900.00 90.00 128.36 8935.10 8872.00 -255.60 5475.10 9.00 5948285.92 703761.52 MWD 12000.00 90.00 119.36 8935.10 8872.00 -311.26 5558.05 9.00 5948232.46 703845.90 MWD 12100.00 90.00 110.36 8935.10 8872.00 -353.26 5648.69 9.00 5948192.87 703937.61 MWD 12179.17 90.00 103.23 8935.10 8872.00 -376.12 5724.44 9.00 5948172.01 704013.93 End Dir : 1217 12200.00 90.00 103.23 8935.10 8872.00 -380.89 5744.72 0.00 5948167.78 704034.32 MWD 12287.00 90.00 103.23 8935.10 8872.00 -400.80 5829.41 0.00 5948150.10 704119.50 4 112" 12287.51 90.00 103.23 8935.10 8872.00 -400.92 5829.90 0.00 5948150.00 704120.00 05-24A T4 FMC FMC ~.... BAKffic 70' 05-24 Pre Ri' J SAÆTYNOTE5: -cIfiJME5-1/2" LNR&2-7/S" TBG*"" . TREE = WELLHEAD = ACTUATOR = ( KB. EtËV = u__'.u<_____...·____.u.·__'..u'_____... BF. ELEV = ? KOP= 1000' Max Angle = 33 @ 2900' oafum MD~~--'~ "1' Ö041-" Datum ND = 8800' SS /4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" -i TOPOF 3-1/2" TBG H 110-3/4" CSG, 45.5#, J-55, ID = 9.950" H 2966' 2966' 3891' fFISH - CHEM CUTTER (05/16/04) H 8930' I CHEM CUT TBG (05/27104) H 8930' Minimum ID = 2.25" @ 9961' 2-7/8" OTIS XN NO-GO NIPPLE TOPOF SAND H 9000' 13-1/2" TBG, 9.2#, L-80, .00870 bpf, ID = 2.992" H 9142' TOPOF 2-7/8" TBG H 9142' I TOP OF 5-1/2" LNR H 9279' 17-5/8" CSG, 29.7#,10 = 6.875" l-i 9583' ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/13/91 ANGLE AT TOP ÆRF: 26 @ 9902' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 4 9902 - 9922 C 08/18/91 2-1/8" 4 10098 - 10144 C 09/07/91 I PBTD - 10242' 15-112" LNR, 17#, 13·CR, .0232 bpf, ID = 4.892" - 10286' DA TE REV BY COMMENTS OS/22/91 ORIGINAL COMPLETION 05/23/93 LAST WORKOVER 02/05/02 RNlTP CORRECTIONS 03/14/04 DAVITLH GLV ClO 05/16104 FWElKAK DUMP SAND; FISH 05/27104 MJA/KAK CHEM CUT TBG CD I ~ --- --L C L I - I~ ~ . /fff!!!ã 11 ~ DA TE REV BY 2250' H4-1/2" OTIS HRQ SSSV NIP, 10 = 3.813" 2966' H4-1/2" X 3-112" XO .....c f GAS LIFT MANDRELS ST MD NO DEV TYÆ VLV LATCH PORT DATE 1 3259 2987 33 MC-FMHO DMY RK 0 03/07104 2 6157 5475 32 MC-FMHO DMY RK 0 3 8674 7652 28 MC-FMHO DMY RK 0 4 8766 7733 27 MC-FMHO DMY RK 0 CHEMICAL INJECTION MANDRELS ISTI MD ND DEV TYÆ VLV LATCH PORT DATE 1 8889 7773 26 CA-KBUG-L T DV BK-5 05/24/93 A .....c I 8913' H3-1/2"PARKERSWSNIP,ID=2.813" I I 8976' -7-5/8"X4-1/2"BAKERSABL-3PKR I 9020' H3-1/2" OTIS XN NO-GO NIP, ID = 2.75" PRODUCTION MANDRELS ST MD ND DEV TYÆ VLV LATCH PORT DATE 1 9063 7929 27 CA-MMG-2 DV RK 05/24/93 2 9123 7982 27 CA-MMG-2 RK 0.250 10/16/95 9142' -3-1/2" X 2-718" XO I . 9898' JTOPOF 2-7/8" BLAST JOINT I 9938' H BOTTOM OF 2-7/8" BLAST JOINT I 9948' 1-i5-1/2" X 3-1/2" BAKER SABL-3 PKR 9961' H2-7/8" OTIS XN NO-GO NIP, 10 = 2.25" I 9964' - 27/8",6.4#, 13CR-80 tubing. I.D. = 2.441" I 10144' HFISH - 1.5" HES-0-20R-RK (LOST 10/16/95) I COMMENTS PRUDHOE BAY UNIT WELL: 05-24 PERMIT No: 1911050 API No: 50-029-22204-00 SEe 32, T11 N, R15E 4866.57 FEL 2400.84 FNL BP Exploration (Alaska) 05-24A preposed Compl.on 110-314" CSG, 45.5#, 1-1 3,891' I J-55, ID = 9.950" I I ;U~8" EZSV Bridge 11 4,100' I TOPOFSAND H 9000' 1- ~ . - . . /75/8",29.7#, L-80 /1 9583' Casing I.D. = 6.875" . T 151/2",17#, 13Cr-80, /1 10286' I ~ liner 1.0.=4.892" DA TE REV BY COMMENTS 08/22/91 ORIGINAL COMPLETION 05/23/93 LAST WORKOVER 02/05/02 RN/TP CORRECTIONS 03/14/04 OAV/TLH GLV C/O 05/16/04 FWElKAK OUMPSANO; FISH 05/27104 MJA/KAK CHEM CLTT TBG DATE 09/22/04 I 2,200' H4 1/2" 'X'landing nipple, 10 = 3.813" I TREE = WELLHEAD = AcTUATOR:: kS.B::Ð7;;;"" BF.ELÐ7 ';;.. KOP= Max Angle = oaïum /lAD = ~"".~ ..~----~. .", . Datum TVO = FMC FMC BAKER C 70' ? 1000' ,-- ~--. "... ,,-- " 33 @ 2900' 10041' 8800'SS 3,950' H Sidetrack off cement plug 9,190' H4 1/2" 'X'landing nipple, ID = 3.813" I 9,205' H 7" X 4 1/2" Baker S-3 packer 1 9,225' H4 1/2" 'X' landing nipple, ID = 3.813" 1 9,235' ~l4 1/2" 'XN' landing nipple, ID = 3.75" 9248' H41/2", 12.6#, 13Cr-80, VAMTOP I I I I I 9,250' 11 7" X 5" Baker HMC Lnr hngr and I ZXP pkr with TBS / 9,405' H 7", 26#, L-80 BTC-M Orlg liner 1 I 12,287' H4 1/2", 12.6#, L-80, IBT-~Iiner I REV BY COMMENTS dew A-oposed corrpletion PRUDHOE BA Y UNfT WELL: 05-24A ÆRMfT No; API No: 50-029-22204-01 SEe 32, T11 N, R15E 4866.57 FEL 2400.84 FNL BP Exploration (Alaska) · POST THIS NOTICE IN THE DOGHISE .. 5-24A Rig site Summary of Drilling Hazards ./ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 27 ppm, measured ifl- November 1990. ./ NORM test all retrieved well head and completion equipment. ./ One well, 5-05A, fails to pass major risk criteria. This well encroaches the area of allowable separation within the reservoir, and only within the last 50 feet of drilling. This well is currently plugged and abandoned, thus creating minimal danger. ./ The closest neighboring wells, at surface, are 05-04 and 05-27. Well 05-04 is approximately 60' to the North. Well 05-27 is approximately 60' to the South. No shut-in should be required, but care should be taken during rig MIRUand RDMO. Use spotters as necessary. ./ There is one planned fault crossing in the intermediate interval of this well. A small fault, with a throw of approximately 20 feet, is expected in the CM2. No losses are expected. The original well had no trouble in crossing this fault. The lost circulation decision tree should be followed if lost fluid returns are encountered. ./ There are no planned fault crossings in drilling the production interval. However, there is a known fault tip approximately 150 feet to the SW of the planned horizontal trajectory. Additionally, there is a fault approximately 450 feet beyond the planned TD of the well. ./ Differential sticking may be encountered. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE OS 05 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 05-24A . . ':'.,'"",,':; , :';"""'- -""""...- -".:,-""."'''-''-',..'- '..': .' '-'0 ,..: '.::""."""'" :,": -.<"., ·;'1·'······,···,,:.·_,·..····· :':.. , .,., ., -. -; ',:, '..' \"', ': '.:,' .'" -,:"-,.-,, .,'~.' ..,':, - " -",,' ::'_ ."_.",:,,,,: _.._L,.,: '. "" ,"'.' ' PAY TO THE ,. A ,. " . , ORDER OJ; ~ r:J>é-;(l C -:-. .,. ,. '. OV)~"" ".~~cwl·~~'~ " , . ~rq , First National ank Alaska ' , .. · A~~';r;j~ :.,.11 c:: . ~~ MEMO+" O~\,..JL 1 ~'1 , .,. ,.. '.", ~ I:~ 25200n.bUI:~ t¡ ~I. ~'lb.2 2 7"1<15 Þ I.UII! 0 ~ ....~ .~ . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Ita o,1J-~tjA PTD# 20,/- 21 '6 x Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTJ LATERAL (1f APJ number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn The permit is for a new weHbore segment of existing well·. . Permit No, .' API No. Production. should continue to be reported as a function' of tbe original API number. stated above. BOLE In accordance with 20 AAC 25.005(f), aU records, data and logs acquired for the piJot bole must be dearJy differentiated In both Dame (name on permit plus PH) and API number (50 70/80) from records, data and Jogs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTJON DRY DITCH SAMPLE The permit is approved subject ·to fun compJiance witb 20 AAC 25..0SS~ Approval to perforate and produce is contingent upon issuance of 1'! conservation order approving a spacing e:sception. (Company Name) assumes tbe Jiability of any protest to the spacing .e~ceptioD tbat may occur. AlJ dry ditch sample sets submitted to tbe Commission must be in no greater 1baD 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample iIiter=va)s tbrough target zOnes. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 05-24A ~Program _DEV Well bore seg 0 PLORATION (ALASKA) INC - Initial ClassfType DEV 11~GeoArea 890 Unit 11650 On/Off Shore ßn _ Annular Disposal 0 Administration 'attache!:t _ Yes 2 Lease _number .appropri<lte _ _ _ Yes 3 .U.niquewelln..ame.aod numb.er . . _ . . . . _ . . _ . _ _. . . _ . . . . .... _... Yes - - - - - - - - - - - - - - - - - - - - .. . 4 Well IOC<lted [n.a ctefinedppol. - - - - - _ Yes - - - -- 5 WelUoc<lted proper distance_ from driJling unitb_oundary_ _ Yes 6 Wen JOC<lted prpper .distance. from otber wells_ _ . _ Yes 7 S.utficient <lcreage_aYail<lble in.dJilling unjt · Yes 8 Jtdevìated, js_ weJlbore plaUncJu.ded . _ Yes 9 _Qperator only affected party. _ Yes 10 _Operator has_apprppriateJ~ond i.nJQrce . . . . _ . . _ . _ . _ . . _ . . . _.. _. _. Yes - - - - - - - - - - - - - - - - - - - - . - . 11 Permit can be issued witbout ço.nservation order. . Yes Appr Date 12 Permit c:ao be issued witbout actministratille_apprpval . _ . _ Yes - - - - -- . RPC 10/26/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUoc¡¡ted within area and.str¡¡t¡¡authQrized by.lojectipo Order #I (PutlO# in.cpmmeots>-(For. _NA - - - - - - - - 15 _All welJs. wit]1iJU l4Jnile .area_of reyiew ideotified (Fpr servjce w.e!! only). . _ . . . _ _ . . . . _ . . .NA - - - - - - - - - - - - - - - - - - - - - .. 16 Pre-producect iojector; durJ1tion_of pre-productiplJ less than.. 3 montbs. (For_service well onJy) _ . NA - - - - - - - -- 17 ACMP. Finding of COl1si~tenGY. has been issued for. this Project _ _ .NA Engineering 18 _C90du_ctor string.pJovided _ . _ · NA 19 _S.urface .c¡¡singpJotecJs all.known.. USQWs _ _ NA 20 _CMT. vpl adequate. to circJJlate. oJ1.cPlJd.uçtpr_ & SUJt csg . _ . _ _ .NA 21 .CMT vpl adequate_ to tie-lnJong .striog to.SJJrf csg. . _ No 122 _CMT will Goyer.aU klJow.npro_duGtiye horizon.s_ - - - - _ Yes - - - - 23 _C.asing designs actec¡uaJe fpr C, T:, B&. permafrpsL . _ . _ . _ . Yes - - -- 24 AdequJ1teJan.kageoJ re_serve pit _ _ - - - - - -- - - - - - _ _ Yes Nab9rs2ES, - - -- 25 JtaJe-drilt has. a to-403 for J1bandon..me_nt beeo <lPPJoved . _ _ Yes 10/22/2004. - - - - - 26 AdequJ1te.we!!bore sepªr<ltjo.nproposed. . . . _ . . _ _ _ _ . . . . _ . _ _ . _ . . . . .. .Yes - - - - - - - - - - - - - - - - - - - - 27 Jtdjverter Jequired, does jt meet reguJatipos. _ _NA Sidetrack. Appr Date 28 .DJilliog fluid program schematic 8. equip JisLadequ¡¡te . _ Yes Max MW to,2ppg.. . _ . WGA 10/27/2004 29 .BOPEs,_do.they meetreguJa.tion _ . _. Yes 30 _BOPEpre.s$ raJing approp(Îate; .test to .(pu.t psig i.n.comments). _ - - -- Yes Test tp.3500_psi.MS:) 2350 psi.. 31 _Choke. manifOld compJies w/APt R:)-53 lMay 84) _ _ Yes 32 Work will PGc.ur withpyLoper¡¡tjon .shutdQw.n. . - - - ~ - Y~s 33 Is pres.ence of H2S gªs_ pro~able. . N.o lQt.ao H2S pad. 34 MechanicaLcoodJt[oo pf wens wi.thin AOR yerifiect CFors_ervice welJ only). .NA Geotogy 35 P~(mit c.an be i.ssued wlo hYdrogen. s.ulfide O1eaSJJres. _ N.o. 36 _D.ata_ PJeseoted on_ pote_ntial OVeJpres.sur~ .zooe~ _ - ~ - - ~ NA Appr Date 37 .Sei.smicanalysJs of shaJlow gaszpoes. . · NA RPC 38 .Seªbedcoodjtipo survey.(if off-s.hp(e) . . NA - - - - - ~ 39 . CQntact namelp\1on..eJorweel5ly progres.s.reports [exploratory .only] . . . · .NA Geologic Date: Engineering Date ~ Date Commissioner: Commissioner ml ¥/tff' Ð7j 101<:..) /9-- . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation. 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. . . )O\"I-~/¿ }>).öì Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 06 15:50:30 2005 Reel Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ...... .........UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments......~....... ...STS LIS Writing Library. Scientific Technical Services Tape Header Service name.......... ...LISTPE Date.................... .05/07/06 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... ......... ...UNKNOWN Continuation Number......01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU/EOA MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 5-24A 500292220401 BP Exploration (Alaska) Inc. Sperry Drilling Services 06-JUL-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003374225 J. SACK J. RALL MWD RUN 2 MW0003374225 J. SACK R. BORDES MWD RUN 3 MW0003374225 J. SACK R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 32 11 15 2203 1194 63.10 34.60 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.750 6.125 CASING SIZE (IN) 10.750 7.000 DRILLERS DEPTH (FT) 3891.0 9406.0 # REMARKS: . 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A CEMENT PLUG IN THE 5-24 WELLBORE. THE EXIT POINT IS 3891'MD/3519'TVD. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 1 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). RUNS 2 & 3 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D.SCHNORR, GEOQUEST(BP), DATED 7/5/05. 6. MWD RUNS 1 - 3 REPRESENT WELL 5-24A WITH API#: 50-029-22204-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12308'MD/8933'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name. ......... ...STSLIB.001 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation...... .05/07/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3835.0 3835.0 3835.0 3835.0 3835.0 3839.5 3891. 5 STOP DEPTH 12260.5 12260.5 12260.5 12260.5 12260.5 12253.5 12308.0 . . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 3835.0 9406.0 10453.0 MERGE BASE 9406.0 10453.0 12308.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction..... ........... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................... ..60 .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 DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3835 12308 8071.5 16947 3835 12308 ROP MWD FT/H 0.12 766.62 116.562 16834 3891. 5 12308 GR MWD API 6.42 489.92 86.3161 16829 3839.5 12253.5 RPX MWD OHMM 0.26 1000.37 17.6294 16852 3835 12260.5 RPS MWD OHMM 0.29 2000 29.5913 16852 3835 12260.5 RPM MWD OHMM 0.36 2000 32.0281 16852 3835 12260.5 RPD MWD OHMM 0.3 2000 33.4186 16852 3835 12260.5 FET MWD HOUR 0.2 69.35 2.01536 16852 3835 12260.5 First Reading For Entire File..........3835 Last Reading For Entire File.......... .12308 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/07/06 Maximum Physical Record..65535 File Type.... .......... ..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...... .05/07/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 3835.0 3835.0 3835.0 3835.0 3835.0 3839.5 3891.5 STOP DEPTH 9345.5 9345.5 9345.5 9345.5 9345.5 9354.0 9406.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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 15-NOV-04 Insite 66.37 Memory 9406.0 3891. 0 9406.0 23.2 36.9 TOOL NUMBER 149205 15181:2 8.750 3891.0 Water 9.80 51. 0 9.5 1300 5.8 Based 1.300 .610 .840 1. 800 68.0 152.6 68.0 68.0 . . 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... ..0 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 DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3835 9406 6620.5 11143 3835 9406 ROP MWD010 FT/H 0.78 766.62 148.331 11030 3891.5 9406 GR MWD010 API 6.42 412.04 96.8478 11030 3839.5 9354 RPX MWD010 OHMM 0.26 326.79 2.96467 11022 3835 9345.5 RPS MWD010 OHMM 0.29 1709.83 3.14931 11022 3835 9345.5 RPM MWD010 OHMM 0.36 2000 3.60994 11022 3835 9345.5 RPD MWD010 OHMM 0.3 2000 4.53058 11022 3835 9345.5 FET MWD010 HOUR 0.2 6.01 0.921139 11022 3835 9345.5 First Reading For Entire File......... .3835 Last Reading For Entire File........ ...9406 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number. ........ ..1.0.0 Date of Generation.......05/07/06 Maximum Physical Record..65535 File Type............... .LO Next File Name:......... .STSLIB.003 Physical EOF File Header Service name.... .........STSLIB.003 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation...... .05/07/06 . Maximum Physical Record..65535 File Type............. ...LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 9346.0 9346.0 9346.0 9346.0 9346.0 9354.5 9406.5 STOP DEPTH 10408.0 10408.0 10408.0 10408.0 10408.0 10401.0 10453.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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): # 20-NOV-04 Insite 66.37 Memory 1045:3.0 9406.0 10453.0 29.13 81.13 TOOL NUMBER 8722~~ 156401 6.1:;::5 9406.0 Flo-pro 8.40 50.0 9.5 4400 9.2 .900 .460 .680 1.100 68.0 141. 0 68.0 68.0 . . 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 DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9346 10453 9899.5 2215 9346 10453 ROP MWD020 FT/H 0.83 117.79 49.1736 2094 9406.5 10453 GR MWD020 API 16.55 489.92 56.9636 2094 9354.5 10401 RPX MWD020 OHMM 1. 51 1000.37 86.7042 2125 9346 10408 RPS MWD020 OHMM 2.24 2000 178.145 2125 9346 10408 RPM MWD020 OHMM 0.75 2000 194.497 2125 9346 10408 RPD MWD020 OHMM 0.49 2000 199.384 2125 9346 10408 FET MWD020 HOUR 0.59 69.35 5.50221 2125 9346 10408 First Reading For Entire File......... .9346 Last Reading For Entire File....... ....10453 File Trailer Service name....... ......STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/07/06 Maximum Physical Record. .65535 File Type... ....... ......LO Next File Name......... ..STSLIB.004 Physical EOF File Header Service name........... ..STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......05/07/06 Maximum Physical Record..65535 File Type............... .LO Previous File Name.... ...STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 . RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ . header data for each bit run in separate files. 3 .5000 START DEPTH 10401.5 10408.5 10408.5 10408.5 10408.5 10408.5 10453.5 STOP DEPTH 12253.5 12260.5 12260.5 12260.5 12260.5 12260.5 12308.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction.......... .......Down 25-NOV-04 Insite 66.37 Memory 12308.0 10453.0 12308.0 84.1 95.1 TOOL NUMBER 87224 156401 6.125 9406.0 FLO-PRO 8.40 46.0 9.9 2500 7.0 1. 200 .650 3.000 1. 650 69.0 132.8 69.0 69.0 . . 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 DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10401. 5 12308 11354.8 3814 10401. 5 12308 ROP MWD030 FT/H 0.12 355.29 60.1462 3710 10453.5 12308 GR MWD030 API 25.56 175.8 71 . 552 3705 10401.5 12253.5 RPX MWD030 OHMM 5.58 75.2 21.6379 3705 10408.5 12260.5 RPS MWD030 OHMM 5.7 85.63 23.0511 3705 10408.5 12260.5 RPM MWD030 OHMM 5.81 73.47 23.385 3705 10408.5 12260.5 RPD MWD030 OHMM 6.75 66.64 24.1684 3705 10408.5 12260.5 FET MWD030 HOUR 0.28 42.9 3.27069 3705 10408.5 12260.5 First Reading For Entire File........ ..10401.5 Last Reading For Entire File.... ...... .12308 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation... '" .05/07/06 Maximum Physical Record..65535 File Type......... ...... .LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/06 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name..... ......UNKNOWN Comments......... ........STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services . Physical EOF . Physical EOF End Of LIS File