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Home My WebLink About205-1307. 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 02-17B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-130 50-029-20453-02-00 13570 Conductor Surface Intermediate Liner Liner 8835 80 2657 9642 2067 9499 9775 20" 13-3/8" 9-5/8" 4-1/2" 3- 1/ 2" x 3-3/ 16" x 2-7/ 8" 8382 33 - 113 33 - 2690 30 - 9672 9539- 11606 10204 - 13570 33 - 113 33 - 2689 30 - 8296 8189- 8860 8758- 8835 13333 520 2670 5080 7500 13890 9775 , 11700 1530 5380 8150 8430 13450 9652 - 13490 4-1/ 2" 12.6# L-80 28- 9527 9682 - 8842 Structural 4-1/2" Baker S-3 Perm , 9318 , 8013 No SSSV 9318 , 9470 8013 , 8134 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 0028308 28 - 8179 331 189 41109 43707 22 14 0 0 814 831 13b. Pools active after work:PRUDHOE OIL 4-1/2" TIW HBBP-T , 9470 , 8134 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 N/A By Grace Christianson at 10:38 am, Mar 14, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.03.13 15:16:44 - 08'00' Bo York (1248) DSR-3/24/25JJL 4/8/25 RBDMS JSB 060325 ACTIVITYDATE SUMMARY 2/2/2025 ***WELL S/I ON ARRIVAL*** DRIFTED w/ 33' x 2-7/8'' DUMMY GUNS (max od 3.16'') 3.75'' CENT, S/D @ 9464' SLM, TAG @ 10195' SLM (problem area @ 9464' slm, see log) ***WSR CONT ON 2-3-25*** 2/3/2025 ***WSR CONT FROM 2-2-25*** DRIFTED w/ 33' x 2-7/8'' DUMMY GUNS (max od 3.16'') 3.50'' CENT, DRIFTED @ 50, 100, 150 FPM THRU PROBLEM AERA ~ 9464' SLM TO ~9500' SLM (see log) TAG @ 10194' SLM ***JOB COMPLETE, WELL LEFT S/I*** 2/15/2025 ***WELL SHUT IN ON ARRIVAL*** (PLUG SET / ADPERF) RIG UP AK E-LINE FUNCTION TEST WLV'S PT 250L 3000H CORRELATE TO HES COIL FLAG DATED 22-DEC-18 SET NS 3.50" CIBP @ 9775' CCL STOP DEPTH=9763.8(CCL-ME=11.2'). TAG AFTER SET PERFORATE 9652' - 9682' WITH 2.75" 6SPF 60PHASE HSC W/ GEODYNAMICS RAZOR CHARGES CCL STOP DEPTH=9644.3 (CCL-TS=7.7'). CONFIRM SHOTS FIRED RDMO AK E-LINE ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE Daily Report of Well Operations PBU 02-17B 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 02-17B Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-130 50-029-20453-02-00 13570 Conductor Surface Intermediate Liner Liner 8835 80 2657 9642 2067 9499 11700 20" 13-3/8" 9-5/8" 4-1/2" 3- 1/ 2" x 3-3/ 16" x 2-7/ 8" 8860 33 - 113 33 - 2690 30 - 9672 9539- 11606 10204 - 13570 33 - 113 33 - 2689 30 - 8296 8189- 8860 8758- 8835 13333 520 2670 5080 7500 13890 11700 1530 5380 8150 8430 13450 11810 - 13490 4-1/ 2" 12.6# L-80 28- 9527 8859 - 8842 Structural 4-1/2" Baker S-3 Perm , 9318 , 8013 No SSSV 9318 , 9470 8013 , 8134 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 0028308 28 - 8179 331 516 38162 25810 21 18 0 0 762 793 324-374 13b. Pools active after work:PRUDHOE OIL 4-1/2" TIW HBBP-T , 9470 , 8134 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 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.08.20 14:32:09 - 08'00' Bo York (1248) By Grace Christianson at 3:39 pm, Aug 20, 2024 RBDMS JSB 082824 DSR-8/21/24WCB 10-2-2024 ACTIVITYDATE SUMMARY 7/12/2024 ***WELL S/I ON ARRIVAL*** PULLED 4-1/2'' DREAM CATCHER FROM X-NIP @ 9352'MD (recovered about 2 cups of metal chunks) ***WELL LEFT S/I ON DEPARTURE*** 7/19/2024 Assist Coil Pumped 10 bbls 60/40, 302 bbls KCL and 5 bbls DSL to assist coil ***Job Continues to 7-20-2024*** 7/19/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope - Drift/log, Set CIBP, 2 Ext Perf guns MIRU, MU NS MHA and HES memory gamma/CCL logging tool w/ 2.3" drift nozzle. Load the well with KCL/safelube. RIH to 12500 CTMD. Log up to 12650', paint flag, log up to 11200' paint second flag. Log up to 10000'. POOH. Good data, -10' correction. Pressure test MHA and safety joint. MU NS XR CIBP. RIH, set down at X/O at 9529CTM. Make muiltiple attempts then POOH. Plug sheared off at 1/2" shear stud. Order out venturi with 2.5" ID mule shoe ***Continued to WSR on 7/20/24*** 7/20/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope - Drift/log, Set CIBP, 2 Ext Perf guns M/U Baker Ventruri w/3.66" mule shoe. RIH, Set down at 9488' and unable to work through. POOH. Nothing recovered. MU BOT Jar, motor, venturi and cut lip shoe. RIH. Tag 10485 CTMD. PUH and rotate through. Work down to 9571' while hoovering. PUH. Attmepted a dry drift. Sat down 10483'. PUH and rotate through. Had a leak from the SSV. Make decion to POOH. Nothing recovered in venturi. Valve crew rebuilt SSV, Pressure tested to 4500psi. RIH with motor, venturi and modified cut lip shoe with wire grab inside. Venturi down to liner top. POOH ***Continued to WSR on 7/21/24*** 7/20/2024 Assist Coil ***Job Continued from 7-19-2024*** Pumped 215 bbls KCL to assist coil ****Job continues to 7-21-2024**** 7/21/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope - Drift/log, Set CIBP, 2 Ext Perf guns POOH w/Venturi w/cut lip shoe. L/D tools, Nothing recovered inside venturi, wire grabs and flutter cages untouched. M/U 2.3" three blade junk mill. RIH Tag LTP, HAd to work to get into the liner. Drifted to 12464 MD. POOH. MU BOT MHA and HES memory gamma/ccl tool and 2.2" carrier w/ 2,3" DJN. RIH. Drifted clean to 12300 CTMD. Log up 50 fpm. Stop 11650 and paint green flag, stop. Log up to 11220 paint yellow flag. Log up to 9300'. POOH. -15' correction. Start BOP test. Issue with pipe ram, possible internal leak casing pressure to bleed back into the system. Swap out BOPs ***Continued to WSR on 7/22/24*** 7/21/2024 ****Job Continues from 7-20-2024**** Assist coil Pumped 102 bbls KCL to Assist coil *****Job Continues to 7-22-2024**** 7/22/2024 Continued from 7-21-2024 Assist Coil Pumped 371 bbls KCL to Assist coil ****Job coninues to 7-23-2024**** Daily Report of Well Operations PBU 02-17B Daily Report of Well Operations PBU 02-17B 7/22/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope - Drift/log, Set CIBP, 2 Ext Perf guns Rig up crane for BOP swap. N/U BOP's. Perform weekly BOP test MU NS CIBP. RIH. AT the flag 11658.52' correlated to COE 11648.99'. RIH past set depth. PUH to 11700. Pump 3/8" ball and set the plug.Stack 4.5K on the plug. PUH to 11670. Circ a bottoms up. Attempted to do a 500 psi pressure test. Leaking by somewhere at a slow rate. POOH keeping the hole full. At surface performed no flow test. All good. Lined up .5 bbl/m across the top. MU the swivel and PT'd to 3500 psi. Skyed the injector and spotted the crane. Start running guns. RIH, correct to bottom shot at the plug. PUH and perforate interval 11,170-11,600' with 2" Maxforce guns 6SPF, 60 degree phase. POOH keeping hole full . ***Continued to WSR on 7/23/24*** 7/23/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope - Drift/log, Set CIBP, 2 Ext Perf guns POOH keeping hole full. Perform no-flow check and kick while tripping drill. Confirm shots fired, perforated interval 11,170-11,600' with 2" Maxforce guns 6SPF, 60 degree phase. recover ball. L/D gun run #1. Deploy gun run #2. 2" maxforce 6 SPF 60 degreee phase gun. RIH. Tag CIBP at 11700' and correlate to bottom shot. PUH and shoot 10830-11108'. POOH. Undeploy gun #2, all shots fired. Freeze protect the well with 39 bbls of diesel. RDMO . ***Job Complete*** 7/23/2024 ****Job continues from 7-22-2024*** Assist Coil Pumped 201 bbls KCL Followed by 39 bbls diesel Freeze protect on TBG 7/28/2024 Lrs Test Unit 2, Begin WSR on 7/28/24, RU,PT,POP,Welltest, Continue WSR on 7/29/24 7/29/2024 Lrs Test Unit 2, Continue WSR from 7/28/24, RU,PT,POP,Welltest, Continue WSR on 7/30/24 7/30/2024 Lrs Test Unit 2, Continue WSR from 7/29/24, RU,PT,POP,Welltest, Continue WSR on 7/31/24 7/31/2024 Lrs Test Unit 2, Continue WSR from 7/30/24, RU,PT,POP,Welltest, End WSR on 7/31/24 RIH.gy AT the flag 11658.52' correlated to COE 11648.99'. RIH past set depth. PUH tog 11700. Pump 3/8" ball and set the plug CIBP and adperfs are correctly shown on the WBS below. -WCB gg PUH and perforate interval 11,170-11,600' PUHggg and shoot 10830-11108'. POOH 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 02-17B Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-130 50-029-20453-02-00 ADL 0028308 13570 Conductor Surface Intermediate Liner Liner 8835 80 2657 9642 2067 9499 13554 20" 13-3/8" 9-5/8" 4-1/2" 3- 1/ 2" x 3-3/ 16" x 2-7/ 8" 8837 33 - 113 33 - 2690 30 - 9672 9539- 11606 10204 - 13570 2420 33 - 113 33 - 2689 30 - 8296 8189- 8860 8758- 8835 13333 520 2670 5080 7500 13890 none 1530 5380 8150 8430 13450 11810 - 13490 4-1/ 2" 12.6# L-80 28- 95278859 - 8842 Structural 4-1/2" Baker S-3 Perm , 4-1/2" TIW HBBP-T No SSSV 9318 , 9470 8013 , 8134 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 7/15/24 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 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.06.28 10:28:05 - 08'00' Eric Dickerman (4002) By Grace Christianson at 12:40 pm, Jun 28, 2024 324-374 A.Dewhurst 08JUL24 MGR28JUN24 DSR-7/8/24 * BHA length limited to 500'. 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.09 12:16:06 -08'00'07/09/24 RBDMS JSB 070924 Extended Add Perf 02-17B PTD:205-130 Well Name:02-17B API Number:50-029-20453-02 Current Status:Operable Rig:CTU Estimated Start Date:7/15/2024 Estimated Duration:2day Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Carrie Janowski Permit to Drill Number:205-130 First Call Engineer:Dave Bjork (907) 564-4672 (O)(907) 440-0331 (M) Second Call Engineer:Eric Dickerman (307) 250-4013 Expected Rates: AFE: Current Bottom Hole Pressure:3,300 psi @ 8,800’ TVD (Based on Offset well data) Max. Anticipated Surface Pressure:2,420 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:2,396 psi (Taken on 10/17/2023) Kill Weight Fluid:7.3 ppg Min ID:2.36” KB Packer 10,198’ MD Max Angle:95 Deg @ 13,493’ MD Tie-in Log:HES Coil flag 22 Dec 2018 Brief Well Summary: 2007 CTD sidetrack. 2009 RWO to replace tubing. Currently uncompetitive, we plan on plugging the existing 1A perfs. Then perforate ~700ft of 1A perfs in the 02-17A parent wellbore. Objective:Shoot 278ft and 430ft of extended add perfs in Z1A Procedure: Slickline 1. Pull dreamcatcher from X lock at 9,352ft. Coiled Tubing 1. Bullhead 1.5X wellbore volume - 220 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to setting the CIBP. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to PBTD = 167 bbls b. 4-1/2” Tubing – 10,198’ X .0152 bpf = 155 bbls c. 3-3/16” Liner – 1,502’ X .0076 bpf = 11.4 bbls 2. MU GR/CCL with ~2” JSN drift (Min ID through LTP is 2.36” max gun swell is 2.193”). RIH to 11,700’ MD, past deepest proposed perforation, to ensure liner is clear. If debris is encountered in the liner, attempt to jet through fill. 3. Pull tie-in log from 11,700’ MD up past top of liner to ~10,198’ MD. Flag pipe for subsequent extended perforating run. 4. POOH. Correlate with HES Coil Flag log, Dated 18-Dec-2018 (see attached annotated log). Correct flag and send to OE. 5. Set 3-3/16” cast iron bridge plug at 11,700ft. Pressure test to 500-psi. Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations Extended Add Perf 02-17B PTD:205-130 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 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. 6. 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. 7. At surface, prepare for deployment of TCP guns. 8. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF 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. 9. Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps 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. a. 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. 10.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” Maxforce guns or similar. Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 11,170’ – 11,600’ Run #2 10,830’ – 11,108’ 430’ 278’ 430’ 278’ 2,400 lbs (5.58ppf) 1,551 lbs (5.58ppf) 11. Make up QTS and PT same. 12. 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. 13. 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. 14. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 15. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 16. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 17. RDMO CTU. 18. Turn well over to Operations POP. Extended Add Perf 02-17B PTD:205-130 Attachments: Wellbore Schematic Proposed Schematic Tie-In Log Mini-Log BOPE, rig-up diagram and standing orders Sundry Change Form Extended Add Perf 02-17B PTD:205-130 Current Wellbore Schematic Extended Add Perf 02-17B PTD:205-130 Proposed Wellbore Schematic Extended Add Perf 02-17B PTD:205-130 Tie-In Log Mini Log ĺŕϟôŘċϟôťϟ͖ Extended Add Perf 02-17B PTD:205-130 ĺŕϟôŘċϟôťϟ͗ ÍŜôϟôŘċϟôťϟ͖ æīÍĲħϷ ĲĺϟŕôŘċŜ Extended Add Perf 02-17B PTD:205-130 ͖͖͕͛͛ϟXiϟċĺŘϟ͕͗Ϸ͖͜ ÍŜôϟôŘċϟôťϟ͗ Extended Add Perf 02-17B PTD:205-130 Minilog Extended Add Perf 02-17B PTD:205-130 BOP Schematic Extended Add Perf 02-17B PTD:205-130 Extended Add Perf 02-17B PTD:205-130 Extended Add Perf 02-17B PTD:205-130 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 Approve d 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 02-17B Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-130 50-029-20453-02-00 Conductor Surface Intermediate Liner Liner 8835 80 2657 9642 2067 9499 13554 20" 13-3/8" 9-5/8" 4-1/2" 3- 1/ 2" x 3-3/ 16" x 2-7/ 8" 8837 33 - 113 33 - 2690 30 - 9672 9539- 11606 10204 - 13570 33 - 113 33 - 2689 30 - 8296 8189- 8860 8758- 8835 13333 520 2670 5080 7500 13890 none 1530 5380 8150 8430 13450 11810 - 13490 4-1/ 2" 12. 6# L-80 28- 9527 8859 - 8842 Structural 4-1/2" Baker S-3 Perm, 9318 , 8013 No SSSV 9318 , 9470 8013 , 8134 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 0028308 28- 8179 468 439 48848 50511 29 27 0 0 925 913 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" TIW HBBP-T, 9470 , 8134 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 13570 By Meredith Guhl at 11:16 am, Jan 27, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.01.27 10:19:30 -09'00' DSR-1/30/23 RBDMS JSB 013123 WCB 12-6-2024 ACTIVITYDATE SUMMARY 1/2/2023 CT #9 1.75" Coil Tubing - Job Scope = Mill CIBP MIRU, Start weekly BOP test ***Job Continued 1/3/2023*** 1/3/2023 CT #9 1.75" Coil Tubing - Job Scope = Mill CIBP ***Job Continued from 1/2/2023*** Complete weekly BOP test and coil drift. MU YJ milling tools and 2.3" junk mill. WHP = 2406 psi. kill well w/ slick 1% kcl w/ SL. RIH. Tag CIBP @ 12,238 CTM. Mill 3- 3/16" CIBP. Plug moving down hole with some work. ***Job Continued on 1/4/2023*** 1/4/2023 CT #9 1.75" Coil Tubing - Job Scope = Mill CIBP ***Job Continued from 1/3/2023*** Continue to work CIBP down hole with YJ milling assembly and 2.30" Junk Mill. Had to work through the cross over at 12,464'. Chased down to 13,333' ctmd, started having over pulls. Made decision to call it good. POOH. Had some over pulls through the perfs 12,160' - 12,000'. Pooh. Freeze Protect Coil w/ Diesel. Freeze Protect Tbg w/ Diesel to 2500' TVD. ***Job Complete*** Daily Report of Well Operations PBU 02-17B g Continue to work CIBP down hole with YJ milling assembly and 2.30" Junk Mill. Hadgy to work through the cross over at 12,464'. Chased down to 13,333' ctmd Milled CIBP fish in shown correctly on the WBS below. -WCB STATE OF ALASKA " aCIED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed jAN i 1i M9 Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Opemtionn{5� 5 d [ISuspend ❑ Perforate m Other Stimulate ❑ Alter Casing 1:1ChangeApa� ❑ Plug for Redrill ❑ Perforate Nev, Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Set CIBP 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ® Exploratory ❑ 5. Permit to Dnll Number: 205-130 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 60-029-20453-02-00 7. Property Designation (Lease Number): ADL 028308 8. Well Name and Number: PBU 02-17B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 13576 feet Plugs measured 12234 feet true vertical 8835 feet Junk measured None feel Effective Depth: measured 12234 feet Packer measured 9318, 9470 few true vertical 8852 feet Packer true vertical 8013, 8133 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 33-113 33-113 1530 520 Surface 2657 13-3/8" 33-2690 33-2689 5380 2670 Intermediate 9642 9-5/8" 30-9672 30-8296 8150 5080 Liner 2067 4-1/2" 9539-11606 8189-8860 8430 7500 Liner 9499 3-1/2" x 3-3/16" x 2-7/8" 10204 - 13570 8758-8835 13450 13890 Perforation Depth: Measured depth: 11810 -13490 feet True vertical depth: 8859-8842 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 28-9527 28-8179 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 9318 8013 We vertical depth) 4-1/2"TIW HBBP-T Packer 9470 8133 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: 446 40209 36 0 898 Subsequent to operation: 435 27458 16 0 817 14. Attachments: (required per 2a MC 25.07025071, s 25.283) 15. Well Class after work: Daily Report of Well Operations EI Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ® Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Meixueiro, Pauline Contact Name: Meixueiro, Pauline Authorized Title: Production Engineer- Contact Email: paulina. meixueiroiijibp.com Authorized Signature: - JX'L� Date: I , ( �� Contact Phone: +1 907 564 5971 Form 10-404 Revised 04/2017 'ILhPKX0rr yl��y RBDMSZ;LJAN 2 2 2019 Submit Original Only Daily Report of Well Operations PBU 02-17B ACTIVITYDATF CI IMMGRV **'WELL FLOWING ON ARRIVAL'** (Profile modification) DRIFT TO DEVIATION AT 10,480' SLM W/ 2.00" x 25' PJO DUMMY GUN (2.29" rings to cover swell). 9/2/2018 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** CTU # 9 - 1.75" .156" wall thickness Blue Coil '**Continue from 12/21/18**' Job Objective: Plug set and Adperf Complete weekly BOP test. RIH with 2.25" JSN and 2.200" GR/CCL. Load well with 100bbl of safelube. Log from 12450-9000. Paint flag at 12201.51. OOH with logging tools and show a +22' correction, making corrected EOP at flag = 12213.39. RIH with 2" x 30' 6spf Millenium perf gun and perforate 12130-12160. OOH, ball recovered, all shots fired. MU & RIH w/ WFD 2.281" Extended Range CIBP 12/22/2018 ***Job in Progress' CTU # 9 - 1.75".156" wall thickness Blue Coil 'Continue from 12/22/18*** Job Objective: Plug set and Adperf Set WFD 2.281' Extended Range CIBP @ 12 234' MD. Perforate 12030 - 12060, 2" x 30' 6spf Millenium perf gun Perforate 12000 - 12030, 2" x 30' 6spf Millenium perf gun 12/23/2018 ***Job in Progress' CTU # 9 - 1.75" .156" wall thickness Blue Coil 'Continue from 12/23/18**' Job Objective: Plug set and Adperf Perforate 11810-11840,.2" x 30' 6spf Millenium perf gun Well freeze protected with 38bbl of 60/40. RDMO. DSO notified of well status. 12/24/2018 **'Job Com lete'*' TREE = CNV WELLHEAD= GRAY ACTUATOR- BA143RC KB. rLEV = - - 62' BF. B -EV = 2 KOP= 30_98' Max Angle = 95' @ 1349T Datum MD= 10385' Datum ND = 8800' SS GOND 1-1 110- 13-3/8- CSG, 72#, L-80,13TGM, D= 12.347' 2690' Minimum ID =2.36" @ 10198' 4-112'KB LINER TOP PACKER 41/2' TBG, 12.6#, 13CR-80 VAM TOP, 9425' .0152 bpf, 1D= 3.958' 412" TBG STUB (07/22109) TBG, 12.6#, L-80, BTGM XO TO NSCT 9460' 41/2' 7T3G, 12.6#, L-80, 9524' NSCi, 0152 bpf, D = 3.958" TOP OF 41/2"LNR 1 9625' MLLOUT WPMW (02-171A:)996:7:2'' - 9717' 9-5/8" CSG, 47#, 9717' L-80/ SOO-95, D = 8.681" TOP OFLDHR10204' -NR 8.81#. L-80, STL, .0087 bpf, ID = 2.992" 10266' W"PSTOCK - MONOBORE (09/07/05) 11606' RA TAG 11616' 14-1/2" LNR, PUFORATION SLR*MRY Rff LOG: C1L ON 09/13105 ANGLE AT TOP PERF: 900@ 11810' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2 6 11810 - 11840 O 12124/18 2 6 12000 - 12060 O 12/23/18 2 6 12130 - 12160 O 12/22/18 2 6 12270 - 12560 C 09114/05 2 6 12630 - 12850 C 09114/05 2 6 12950 - 13370 C 09114105 2 6 13470 - 13490 C 09/14/05 SAFETY NOTES: WELL > 700 @ 10398'. -17B WELLBORE NOTWN ON DIAGRAM.ORIGINAL CHROME TBG & NIPPLES"' j L 2200' 412" HES X W. D = 3.813" GAS LFT MANDRELS I 41/2" HES X FP, D= 3.813" 9318' 9-5/8" X 41/2" BKR S-3 PKR D = 3.870" ST I MD TVD I DEV TYPE VLV LATCH PORT DATE 10105184 MB RWO 1 2 3 3534 6346 9209 3511 5702 7927 25 40 39 MMG MMG MMG DOME SO DMY RK RK RK 16 0726/09 20 0726109 0 0722/09 SETPLUG&ADPERFS 928T _--I 9624'j -j4-1r2- 41/2" HES X FP, D= 3.813" 9318' 9-5/8" X 41/2" BKR S-3 PKR D = 3.870" 9357 412" HES X NP, D = 3.813- .813" X24'1-j4-12" X 5-1/2" XO, ID = 3.920" 9525' 9-5/8' X 7" BKR ZXP PKR ,1 6' D=6.3125- 5-112' %WEG, .3125'5-112'%WEG, D=4.00' \ ELMD TT NOT LOGGED 9$$9' 9-518' BKR HMC HGR D = 6.18T 7- X 5-1 /2' XO, D = 4.812' 9548' S-1 /2' X 4-12" XO, ID = 3.937" 10198' 4-12" KB LNR TOP PKK ID = 2.36• 1 n9nA'4• BOT r1FR OY SIV ir = 300• 3-3/16" LNR 6.2#, L-80, — 12464' TCI, .0076 bpf, D = 2.80" 2-718" LNR 6.16#, L-80, STL,13570' .0058 bpf, D = 2.441" 13-112" X 3-3/16" XO, ID = 2786" TIW 4-1/2' MLAS-CV SUB w / PROFLE, 10 MLLOLJT WNDOW (02-17B) 116G6' -11628- 22W 1606'-11628'2234' WFDEXTRANGEBR1DGEPLUIG(12J23/1 12464' 3-3116• X 2-7/6" XO, 10 DATE REV BY COMMENTS DATE REV BY COMMENTS 1980 ORIGINAL COMPLETION 0729/09 PJC DRLG HO CORRECTIONS 10105184 MB RWO 08/10/09 JT/JMJ DRLGDRAFTCORRECTIDNS 10105196 WES SIDETRACK -A" 01/02/19 JDMJMD SETPLUG&ADPERFS 09106/07 N2ES CTD"B" 0723109 D16 RIND 0729109 DTRJPJC GLV GO (0726/09) PRLDHOE BAY LUT WELL: 02-17B PST No: "2051300 AR No: 50-029-20453-02 SEC 36, Tl IR R14E 213' FAL & 787' FWL BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 f1; 41 ?fl ,� */ Mr. Tom Maunder �f 1c$r 0� Alaska Oil and Gas Conservation Commission C o7M 333 West 7 Avenue Qn� 4r � r ;s ea Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -02 a 0 130 17B Dear Mr. Maunde Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 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 • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMI~ION REPO~T OF SUNDRY WELL OPERATIONS ~ . ~ ~ I ~`~ ~i9G~ F~~1C ~ ~ 2009 ~~~~fil~:~ (lil ~~ ~Z~;~ ~r~ns !~~k 1. Operations Performed: ;~^~t,~~~~;~ ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~ Pull 7ubing - ^ PerForate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ PerForate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. -~ Development ^ Exploratory 205-130 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20453-02-00 - 7. KB Elevation (ft): 61.61' - 9• ~Nell Name and Number: PBU 02-17B - 8. Property Designation: 10. Field / Pool(s): ADL 028308 ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 13576 ~ feet true vertical 8835 - feet Plugs (measured) None Effective depth: measured 13534 , feet Junk (measured) None true vertical 8838, feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2690' 13-3/8" 2690' 2690' 4930 2670 Intermediate 9672' 9-5/8" 9672' 8296' 8150 5080 Production Liner 3180' 4-1/2" 9525' - 11606' 8177' - 8860' 8430 7500 Liner 3372' 3-1/2" x 3-3/16" x 2-7/8" 10198' - 13570' 8754' - 8835' Perforation Depth MD (ft): 12270' - 13490' Perforation Depth TVD (ft): 8850' - 8842' 4-112", 12.6# 13Cr80 / L-80 9527' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9'5/8" x 4-1/2" Baker'S-3' packer; 9318'; 9-5/8" x 4-1/2" TIW 'HBBP-T packer 9470' 12. Stimulation or cement squeeze summary: Intervals treated (measured): '' .~~ ~3 .~i~' ~' ~ ? F '` ~~' ~~~r; . , ~ ~ 3.« ~ ,; i t _ '. r~ Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Explorato ry ~ Development ^ Service ~ Daily Report of Well Operations ~ 6. Well Status after work: ~ Well Schematic Diagram -~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name Terrie Hubble Title Drilling Technologist D Prepared By Name/Number. ~ Si nature Phone 564-4628 Date ~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~~~~ ~~~.. ~~s,~ ~ :~ ~009 ~ Submit Original Only ~~y`~~~f'~~~ ~ lELLHEAD = GRAY V ~ ~ ~ ~ ~ ~ ~ ~ ~~~~ . ~.~.~.a~.r.~ ~.,~~ ~ ~ ~.~. ~ ~~. .. ~~~ WE RENOTSHOWNONDIAGRAM ` V . CTUATOR= BAKERC - - ~ • ***C~ME TBG & NIPPLES'`** g ELEV - 62 F. ELE'~/ = 20" CONDUCTOR 110~ " " ' ' HES X NIP, ID = 3.813 4-1/2 2200 OP = 3098 lax Angle = 95° @ 13493' atum MD = 10385' GAS LIFT MANDRELS atum ND = 8800' SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3534 3511 25 MMG DOME RK 16 07/26/0~ 13-3/8" CSG, 72#, L-80,BTGM, ID = 12.347" 2690' 2 6346 5702 40 MMG SO RK 20 07/26/0~ 3 9209 7927 39 MMG DMY RK 0 07/22/0~ Minimum ID =2.36" @ 10198' 4-1/2"KB LINER TOP PACKER 92$7' ~~4-1/2" HES X NIP, ID = 3.813" 9318~ I-I 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 9425~ .0152 bpf, ID = 3.958" 4-1/2" TBG STUB (07/22/09) 9430~ -1/2" TBG, 12.6#, L-80, BTGM XO TO NSCT 9460~ 4-1/2" TBG, 12.6#, L-80, 9524~ NSCT, .0152 bpf, ID = 3.958" TOP OF 4-1/2" ~NR 9525' MILLOUT WINDOW (02-17A) 9672' - 9717' 9-5/8" CSG, 47#, 9717' L-80/ SOO-95, ID = 8.681" TOP OF LINER 10204~ 3-1/2" LNR, 8.81#, L-80, STL, .0087 bpf, ID=2.992" ~ 10256' WHIPSTOCK - MONOBORE (09/07/05) 11606~ RA TAG -~5' 4-1/2" LNR, 12.6#, L-80, BTC-M, :0152 bpf, ID = 3.958" ~ 12719~ PERFOR,4TION SUMMARY REF LOG: CNL ON 09/13/05 ANGLEATTOPPERF:93°@ 12270' Noce: rceTer to rroaucuon ues ror nistoncai perT aata SIZE SPF INTERVAL Opn/Sqz DATE 2 6 12270 - 12560 O 09/14/05 2 6 12630 - 12850 O 09/14/05 2 6 12950 - 13370 O 09/14/05 2 6 13470 - 13490 O 09/14/05 9352~ I-I4-1/2" HES X NIP, ID = 3.813" 9440~ I~9-5/8"X4-1/2"UNIQUEOVERSHOT 9-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 3.917" 950~ 4-1/2" HES X NIP, ID = 3.813" 9524' ~ 4-1 /2" X 5-1 /2" XO, ID = 3.920" ~ 9525~ 9-5/8" X 7" BKR ZXP PKR w/ 6' PBR, ID = 6.3125" 9527' 5-1/2" WLEG, ID = 4.00" ~ ELMD Tf NOT LOGGED ~ 9539' 9-5/8" BKR HMC HGR, ID = 6.187" 9546~ 7" X 5-1/2" XO, ID = 4.812" 9548~ 5-1/2" X 4-1/2" XO, ID = 3.937" 10198~ 4-1/2" KB LNR TOP PKR, ID = 2.36" 10204~ 4" BOT DEPLOY SLV, ID = 3.00" 10209, ~-~ 4" X 3-1 /2" XO, ID = 3.00" ~ 10223~ 3-1/2" HOWCO X NIP, ID = 2.813" --~ 10256~ ~-j 3-1/2" X 3-3/16" XO, ID = 2.786" ~ 10392~ TNV 4-1/2" MLAS-CV SUB w/ PROFILE, ID = 3.890" MILLOUT WINDOW (02-17B) 11606' - 11628' 12464~ 3-3/16" X 2-7/8" XO, ID = 2.377 3-3/16" LNR, 6.2#, L-80, 12464' 13554' PBTD TCII, .0076 bpf, ID = 2.80" 2-7/8" LNR, 6.16#, L-80, STL, 13570~ .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 1980 ORIGINAL COMPLETION 07/29/09 PJC DRLG HO CORRECTIONS WE1L: 02-17B 10/OS/84 N1 B RWO 08/10/09 JT/JMD DRLG DRAFT CORRECTIONS PERMff No: ~2051300 10/05/96 N2ES SIDETRACK"A" API No: 50-029-20453-02 09/O6/07 N2ES CTD "B" SEC 36, T11 N, R14E, 213' FNL & 787' FWL 07/23/09 D16 RWO (17/99/(19 f~TR/P.IC ~i v ~.~~ rmi~FinA~ RP Fxnlnratinn lAlackwl • ~ J 02-17B, Well History (Pre Rig Workover) Date Summary 7/4/2009 WELL S/I ON ARRIVAL. PULLED PRONG FROM 9500' SLM. PULLED 4 1/2" PX PUG BODY FROM 9502' SLM (9504' MD). WEL LEFT S/I ON DEPARTURE. 7/6/2009 RIG UP ELINE TO SET HES FASDRILL, CMIT-TXIA, & JET CUT PRE-RWO. WELL SHUT-IN ON ARRIVAL, SSV OPEN, INITIAL PRESSURES = 300/300/200. SET FASDRILL PLUG AT 9480' MID ELEMENT. TOP OF PLUG AT 9479.3'. FIRST ATTEMPT AT CMIT-TXIA TO 3500 PSI FAILED, DROPPED 600 PSI IN 15 MINUTES. 7/6/2009 T/I/0= 400/300/120 Assist E-Line w/ CMIT Tx IA to 3500 psi (pre RWO). Standby for E-Line to set TBG Plug. Tests #1 and 2 failed. 7/6/2009 T/I/0=270/340/180. Temp=Sl. (pre E-Line). No AL. Integrals on IA & OA. TBG FL C 150'. IA FL Q 216'. SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. NOVP. 7/7/2009 2ND ATTEMPT AT CMIT-TXIA TO 2400 PSI FAILED W ITH A LLR OF 0.75 BPM. RD ELINE. FINAL T/I/0=800/280/200. WELL SHUT IN ON DEPARTURE. NOTIFIED OPERATOR. JOB COMPLETE. 7/7/2009 T/I/0= 400/300/120 ( Assist E-Line / CMIT Tx IA ) Tests 1 and 2 failed. Established LLR Q 2320 @.75 bpm. Standby for E-Line to rig down. Rig to TBG. Job cancelled. RDMO. (Wing-shut / swab-shut / ssv- open / master-open, IA and OA open to gauges.) Operator notified. FWHP = 200/200/180. 7/8/2009 T/I/0=300/200/200, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). PPPOT-T: Stung into test port (20 psi), bled to 0 psi. Functioned LDS, all moved freely (1 "). Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (200 psi), bled to 0 psi. Functioned ~DS, all moved freely (1 "). Pressured void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 7/9/2009 T/I/0=360/420/200 Assist E-line. Pumped 95 bbls crude down IA while E-line attempted to free toolstring post powercutter. E-line toolstring came free. Bled IA pressure down to 450 psi. FWHP's = 360/450/200. E-line rigging down upon LRS departure. Master, IA, OA open. Swab, Wing shut. 7/9/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0=240/200/175. SSV HALF OPEN ON ARRIVAL, GOOD CYCLE. SET 4.5" FASDRILL PLUG AT 9465', CMIT T X IA TO 3500 PSI. PUMPED DOWN IA DUE TO IA TO TUBING COMMUNICATION. PASSED ON SECOND ATTEMPT. CUT 4.5" TUBING AT 9430' WITH 3.65" SLB POWERCUTTER. FINAL T/I/O = 400 / 400 / 250 PSI. JOB COMPLETE. 7/9/2009 T/I/0=200/200/180 Temp=Sl Assist E-line. CMIT Tx1A PASSED to 3500 psi. Pressured up T/IA to 3500 psi with 16 bbls crude. 2nd test results, T/IA lost 0/40 psi in the ist 15 mins and 0/10 psi in the 2nd 15 mins for a total pressure loss of 0/50 psi in 30 min test. Bled back -15 bbls. Final W HP's = 200/200/180. E-line in control of well on departure. 7/13/2009 T/I/0=750/500/200 Temp=Sl Circ well, CMIT TxIA PASSED to 1000 psi post jet cut. MIT OA PASSED to 2000 psi. Rigged up to tubing and pumped 5 bbls neat, 995 bbls 110° seawater down tubing, up IA through jumper line down flowline. Rigged up to IA and pumped 160 bbls of 100° diesel down IA taking returns from tbg down flowline. U-Tubed Tx IA for 1 hr to freeze protect well. Pumped .8 bbls of 55° diesel down IA to reach achieve test pressure. T/IA lost 30/30 1 st 15 mins and 10/10 2nd 15 mins for a total loss of 40/40 in 30 mins. Bleed T& IAP. Bled back (- 3 bbls). Pumped 4.1 bbls of 55° diesel down OA to achieve test pressure. OA lost 80 psi 1 st 15 mins and 40 psi 2nd 15 mins for a total loss of 120 psi in 30 mins. Bleed OAP. Bled back (~3 bbls). Final WHP's = 0/vac/0. Wing shut, swab shut, ssv shut, master open, casing valves open to gauges. Page 1 of 2 • L~ 02-176, Well History (Pre Rig Workover) Date Summary 7/14/2009 T/I/O = SSV/VAC/80. Temp = SI. Bleed IAP & OAP to 0 psi (pre valve c/o). No AL. OA FL near surface. Bled OAP from 80 psi to 30 psi in 5 minutes, maintained open bleed for 15 minutes (gas/fluid slugs). Unable to bleed below 25 psi. Monitored for 30 minutes. OAP increased 27 psi. Final W HPs = SSV/VAC/52. SV, WV, SSV, MV = Closed. IA & OA = OTG. NOVP. 7/14/2009 T/I/O=SSV/Vac/50. Temp=Sl. Bleed IAP to 0 psi for IA & OA valve swap. No A/L. OA FL near surface. Bled OAP from 50 psi to 0 psi 1 hr (all gas). Monitor for 30 mins, OAP increased 15 psi. Note: IA & OA have integrals installed. Final WHPs SSV/vac/20. SV, WV, MV = Closed IA, OA = OTG. NOVP. 7/14/2009 T/I/0= SSVNAC/30. Temp= SI. WHPs (pre tree C/O). No AL. Integral flange installed on IA & OA. BPV in hole. SV, WV / SSV = C. MV = O. IA, OA = OTG. NOVP. 7/14/2009 T/I/0=0/0/0. Set 5-1/8" Gray K BPV thru tree, pre rig. 1-2' ext used, tagged C~ 108". No problems. 7/15/2009 T/I/O = SSVNAC/35. Temp = Sl. Monitor (IA & OA valve C/O). Integrals installed on IA & OA. BPV in hole. OAP increased 5 psi overnight. SV, WV, SSV, MV = Closed. IA & OA = OTG. NOVP. 7/16/2009 T/I/O = SSV/VAC/35. Temp = SI. Bleed OAP to 0 psi (pre-valve swap)(pre-rig). No AL. IA & OA have integrals installed. OA FL near surface. Bled OAP to BT from 35 psi to 0 psi in 1.5 hrs. Maintained open bleed for 1 hr. SI bleed for 2.5 hrs to allow Tie-In Crew to remove wellhouse & flowline. OAP increased to 8 psi. Resumed OAP bleed, OAP decreased 8 psi to 0 psi in 15 mins. Maintained open bleed while API Valve Crew swapped OA casing valve in 45 mins. Final WHPs = SSV/VAC/0. SV, WV, SSV, MV = Shut. API Valve Shop in control of annulus valves. 7/16/2009 T/I/0=0/0/0. Rolled 3-1/8 Gray HWO I/A to backside. 3" VR plug set in front side I/A. Rolled 3-1/8" HWO O/A to backside, new FMC 120 valve installed. All connections torqued to API specs and tested to 5000 psi. Page 2 of 2 • • BP EXPL~RATI~N ~'age i of 7 Operations ~ummary Report Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: WORKOVER Start: 7/15/2009 End: 7/23/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/23/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 711612009 06:00 - 08:00 2.00 RIGD P PRE Rig down floor, bridle up and lay down Derrick 08:00 - 09:30 1.50 RIGD P PRE Move rig of well 01-30 and position on Pad, Remove BOP stack and install on stand. Install booster Wheels on both front and back. 09:30 - 10:30 1.00 RIGD N PRE Wait on mats to be layed on DS 1 access road. 10:30 - 14:30 4.00 MOB P PRE Move Rig from DS-1 to DS-2 and position Rig on Pad to remove booster wheels and raise Derrick. 14:30 - 17:30 3.00 MOB P PRE PJSM, Remove front and rear booster wheels and gooseneck. Replace #2 Generator breaker. 17:30 - 18:30 1.00 MOB P PRE Position rig over BOP stand and install BOP on pedestal in cellar. 18:30 - 19:30 1.00 MOB P PRE PJSM, Raise and pin derrick 19:30 - 22:30 3.00 MOB P PRE Rig up floor and bridle down. 22:30 - 00:00 1.50 MOB N PRE Wait on Pad prep due to equipment shortage. 7/17/2009 00:00 - 01:00 1.00 MOB N PRE Continue waiting on Pad prep. 01:00 - 01:30 0.50 MOB P PRE Lay herculite around cellar and spot mats. 01:30 - 02:30 1.00 MOB P PRE Spot and level rig over well. 02:30 - 04:30 2.00 RIGU P PRE Spot slop tank and take on 120 deg seawater. - Install secondary annulus valve on IA. Rig up circulating lines to IA and tree. - Riq up DSM Lubricator and test to 500 psi. good test. Pull BPV and ri down lubricator. - Hook up 2" line from OA to slop tank. - Spot pump and Generator modules. -Tbg, IA and OA pressures are 0-psi. Acce t Ri for well work on 02-17 ~ 0300 hrs 7/17/2009 04:30 - 09:00 4.50 KILL P DECOMP Displace out freeze protection and Kill well with 120-degree seawater. -Reverse 45-bbls to clear tubing of diesel at 6-BPM with 800-psi. -Swap over and pump a full circulation the long way at 6-BPM with 800-psi. -Monitor well - inconclusive. -CBU at 8-BPM with 1500-psi. -Monitor well - Static. -Blow down and RD circulating equipment. 09:00 - 09:30 0.50 WHSUR P DECOMP PU DSM lubricator test lubricator to 500- si and set K- lu . -Drain tree. -Cameron re T-bar in test dart. -RU to test K- lu & test dart. 09:30 - 10:30 1.00 WHSUR P DECOMP Test K-plug below to 1000- si for 10-charted minutes and above to 3500-psi for 10-charted minutes. -Both tests good. -Blow down & RD testing equipment. -Drain tree. 10:30 - 12:00 1.50 WHSUR P DECOMP Hold PJSM & ND tree. -Cameron rep bleed control lines. -ND Tree and adapter flange and remove from cellar. 12:00 - 12:30 0.50 WHSUR P DECOMP Inspect and clean tubing hanger and API ring groove. -MU 5-1/2" MCA XO to hanger with 19-turns. -Function all LDSs. 12:30 - 14:00 1.50 BOPSU P DECOMP Hold PJSM & NU BOPE. Printed: 7/29/2009 3:05:11 PM ~ • Onera'~ Legal Well Name: 02-17 Common Well Name: 02-17 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 7/17/2009 12:30 - 14:00 1.50 BOPSU P 14:00 - 14:30 0.50 BOPSU P 14:30 - 21:00 6.50 BOPSU P 21:00 - 21:30 0.50 BOPSU~ N 21:30 - 00:00 2.50 BOPSU N 7/18/2009 100:00 - 01:30 I 1.501 BOPSURN 01:30 - 03:00 I 1.501 BOPSUFI N 03:00 - 04:30 1.50 BOPSUF~ N I 04:30 - 06:00 1.50 BOPSUd P 06:00 - 06:30 0.50 BOPSU P 06:30 - 07:00 0.50 WHSUR N 07:00 - 08:00 1.00 WHSUR P Start: 7/15/2009 Rig Release: 7/23/2009 Rig Number: Spud Date: End: 7/23/2009 ivr i r'hase D~~uEaN~ivri ui ~p~raauris DECOMP -Use Sweeney to properly torque all nuts. -Attach turnbuckles and install riser. DECOMP RU to test BOPE. -Fill all lines & stack. DECOMP Perform initial BOP test. -Test to 250-psi low and 3500-psi high. -Hold and chart all tests for 5-minutes. -Test 2-7/8" x 5" VBRs with 4-1/2" & 2-7/8" test jts. Test Annular with 2-7/8" test jt. -Chuck Scheve, AOGCC, waived witness. -All tests witnessed by BP WSL and Doyon Toolpusher. -Hydrill test failed with 2 7/8 test joint. - Packing element failed, also oil in well bore suspect piston seal failur RREP DECOMP Rig down BOP test equipment, Lay down test joint and blow down lines. RREP DECOMP PJSM on changing packing element. -N/D riser, makeup potato masher, break and remove cap on hydril. -Remove packing element. -Mobilize Hydril Rep from Doyon 14. -Hydril Rep conducted inspection on packing element, seals, piston and threads on cap and body. - Hydril Rep's recommendation was to replace entire unit. RREP DECOMP Clean piston and inner body, dress threads on cap and Hydril body tor re- assembly. M/U potato masher and makup cap to Hydril. RREP DECOMP PJSM. Remove lifting ring, dutch riser nipple and Nipple down Hydril -Mobilize new 13-5/8" Hydril from Doyon yard. RREP DECOMP Nipple up new 13-5/8" Hydril, Dutch nipple and lifting ring. -Connect turnbuckles and install drilling nipple. DECOMP Rig up BOP test equipment, install test joint and complete BOP test. -Test Annular with 2-7/8" test ioint to 250 psi low, 3,500 psi hiah. Good test. -Perform Koomey test. DECOMP RU Dutch Riser, RILDSs and fill riser. DECOMP Wait on DSM. DECOMP PU DSM lubricator and test to 500- si. Good test. -Cameron reo oull test dart with T-bar. -No pressure under K-plug. -LD DSM lubricator & K-plug. -Drain stack & RD Dutch Riser. 08:00 - 09:30 1.50 PULL P DECOMP MU double grapple ITCO spear to jt of DP. -Hold PJSM on pulling hanger to floor. -RIH & Engage 4-1/2" Tbg. -BOLDs. -Pull hanger free at 160K-Ibs. String pulls at 145K-Ibs. -Terminate control lines. -Attempt to break out spear - unable. Break out tubing hanger and XO with spear inside and LD. Printed: 7/29/2009 3:05:11 PM • • BP EXPLORAT[ON Rage 3 of 7 Operations Surnmary R~port Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: WORKOVER Start: 7/15/2009 End: 7/23/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/23/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description o# Operations 7/18/2009 09:30 - 11:00 1.50 PULL P DECOMP RU to circulate & CBU at 11-BPM with 1420-psi. -RU Camco spooling unit while circulating -Monitor well - static. -Pump dry job. -RD circulating equipment. 11:00 - 13:00 2.00 PULL P DECOMP POH & LD 4-1/2" 12.6# L80 completion, spooling dual SS contro mes. 13:00 - 13:30 0.50 PULL P DECOMP RD Camco control line spooling unit. -Recovered 58-SS bands of 59-bands reported. 13:30 - 18:30 5.00 PULL P DECOMP Continue POH & LD 4-1/2' 12.6# L80 completion to jet cut. -Starting at jt #148, pin ends are sporadically corroded. -Recover 227-jts of 4-1/2" tbg, 1-cut jt, 3-GLMS, and 1-SSSV. -Cut jt has a very clean cut flared to 4-7/8" OD and 10.58' long. 18:30 - 19:00 0.50 PULL P DECOMP Clear floor of tubing handling equipment. - Install wear ring. 19:00 - 19:30 0.50 MOB P DECOMP Mobilize BHA tools to rig floor - PJSM with Baker Rep rig crew and WSL. 19:30 - 21:00 1.50 MOB P DECOMP M/U Dress off BHA consisting of 8-1/2" dress off shoe, 3 ea. washpipe extensions, tbg top dress mill, junk basket, XO, 9 5/9" casing scraper, XO, Bumper sub, oil jar, cire sub, XO, (6) ea 4 3/4" steel DC's. (240.71') 21:00 - 00:00 3.00 MOB P DECOMP RIH w/ BHA #1 picking up 4" DP from pipe shed F/ 240' T/ 3086'. ~7/19/2009 00:00 - 05:00 5.00 MOB P DECOMP Continue RIH w/ BHA picking up singles from pipe shed, from ' 3,086' to 9200'. 05:00 - 05:30 0.50 DHB P DECOMP PU 9-5/8" HES Storm Packer. -RIH and set 1-std below ri floor. -Test Storm acker to 1000- si for 10-charted minutes. -POH, LD HES running tool. 05:30 - 06:00 0.50 WHSUR P DECOMP Pull wear ring. Drain Stack & Pull Riser. 06:00 - 07:00 1.00 BOPSU P DECOMP Install BOP lifting yoke on stack. 07:00 - 07:30 0.50 BOPSU P DECOMP ND BOP Stack & set back on pedestal. -2 barriers for ND are 1) tested FasDrill at 9465' and 2) tested Storm packer 1-std below rig floor. 07:30 - 08:30 1.00 WHSUR P DECOMP ND Tubin s ool. -Upper packoff came with spool. -Clean top of casing spool, ring groove and casing stump. , -Ensure OA pressure is 0-psi. ! 08:30 - 09:30 1.00 WHSUR P DECOMP Chan e out 9-5/8" casing packoff. , -MU packoff pulling tool. RIH and into lower packoff. Pull packoff free. LD pulling tool and packoff. -Cameron rep install new 9-5/8" casing packoff. -RILDSs. 09:30 - 11:30 2.00 WHSUR P DECOMP NU Grey New Standard Tubing spool & BOP stack. -Install test plug in tubing spool prior to NU BOP. -Cameron rep test packoff to 5000-psi for 30-minutes. Good test. 11:30 - 12:00 0.50 BOPSU P DECOMP Test BOP break to 250- si low and 3500- si hi -Hold and chart each test for 5-minutes. -AOGCC rep Chuck Scheve waived witness of test. 12:00 - 12:30 0.50 WHSUR P DECOMP Pull test plug. Set wear ring. RILDs. 12:30 - 13:00 0.50 DHB P DECOMP MU Storm Packer retrieving tool. -RIH on 1-std of DP. Printed: 7/29/2009 3:05:11 PM ~ • BP EXPLORATIC7N Page 4 of 7 Operations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: WORKOVER Start: 7/15/2009 End: 7/23/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/23/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase aescription of Operations 7/19/2009 12:30 - 13:00 0.50 DHB P DECOMP -Check for pressure - none present. Release packer and allow element to relax. -POH. LD Storm acker & runninp tool. 13:00 - 14:30 1.50 CLEAN P DECOMP Hold PJSM, then Slip & Cut drilling line. 14:30 - 15:00 0.50 CLEAN P DECOMP Continue RIH with 4-1/2" Dress off BHA on DP from shed. -Scrape casing from 9247' to 9374'. 15:00 - 15:30 0.50 CLEAN P DECOMP RIH and ta 4-1/2" tubinq stub at 9428' -PU and establish dressing parameters. -PU wt = 190K-Ibs, SO wt = 135K-Ibs, Rot wt = 160K-Ibs. -Rotate at 60-rpm with 7K-ftlbs of free torque. -Pump at 6-BPM with 560-psi. -RIH and mill stub with above arameters down to 9429'. -Work over stub twice with rotation and then twice without. All passes made without trouble. 15:30 - 16:30 1.00 CLEAN P DECOMP Pump 20-bbl Hi Vis sweep and chase at 12-BPM with 2440-psi. -See small amount of paraffin and sand across shakers. Metal millings on ditch magnets. 16:30 - 17:00 0.50 CLEAN P DECOMP LD single jt of DP to pipe shed. -Monitor well - Static. -Pump dry job. 17:00 - 19:30 2.50 CLEAN P DECOMP POH with Dress Off BHA, standing back DP in derrick. 19:30 - 20:00 0.50 CLEAN P DECOMP Stand back 4 3/4" DC's, lay down remaining BHA. - Recovered 1 gallon of inetal shavings and 1 SS band 20:00 - 21:00 1.00 CLEAN P DECOMP Clear floor of Baker dress off tools, -Bring 2 7/8" handling equipment, power tongs and BHA tools to floor. -Rig up power tongs. 21:00 - 23:30 2.50 CLEAN P DECOMP Make u BHA #2 consistin of 3 5/8" Reverse circulatin basket 5 3/4" shear in uide, 6 ea. 2 7/8" PAC DC's, 21 jts 2 7/8" PAC DP XO, Bumper sub, oil jar, cire sub, XO, (6) ea. 4" 3/4" DCs. = 1,039.01' 23:30 - 00:00 0.50 CLEAN P DECOMP Circulate 2 7/8" drill string volume to ensure pipe is clear. 4 bpm ~ 470 psi. 7/20/2009 00:00 - 00:30 0.50 CLEAN P DECOMP RIH with BHA #2 from 1039' to 4830' 00:30 - 01:00 0.50 CLEAN P DECOMP M/U Topdrive and break circulation to ensure BHA is clear. -4 bpm ~ 810 psi. 01:00 - 02:00 1.00 CLEAN P DECOMP Continue RIH from 4830' to 9384' 02:00 - 02:30 0.50 CLEAN P DECOMP M/U Topdrive break circulation and obtain parameters. , -Up wt = 185k, Dn wt = 135k, rt wt =160k, 4 bpm C~ 900 psi, 60 ' rpm, Tq = 5k -Wash down & ta u with shear in uide on to of tb stub @ 9430' - Set down 15k and shear pins. - Wash down and ta Fasdrill lu (~ 9460' 02:30 - 03:30 1.00 CLEAN P DECOMP Mill Fasdrill lu ~ 94 0' - 4 bpm ~ 920 psi - 60 rpm, Tq 6k - 7k WOB. Wash down from 9461' to 9473' -Set down 15k several times to ensure plug is latched into RCJB or flipper dog sub. 03:30 - 04:30 1.00 CLEAN P DECOMP Lay down single & rack back 1 stand. -Drop ball to open cire sub. Printed: 7/29/2009 3:05:11 PM ~ • _ -_ _ - __ BP EXPLORATIC7N' Page 5 of 7 Operations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: WORKOVER Start: 7/15/2009 End: 7/23/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/23/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Upera#ians 7/20/2009 03:30 - 04:30 1.00 CLEAN P DECOMP -Pump ball to seat ~ 4 bpm, 850 psi. -Increase flow rate to 11 bpm C~ 2000 psi and circulate bottoms up. 04:30 - 05:00 0.50 CLEAN P DECOMP Monitor well - Static -Pump dry job 05:00 - 07:30 2.50 CLEAN P DECOMP POH with BHA #2, standing back 4" DP in derrick. 07:30 - 09:30 2.00 CLEAN P DECOMP Stand back 4-3/4" DCs and 2-7/8" PAC DP. -Place stands of PAC in "cradle" of 4" DP so it is secure in derrick. -LD 4-jts of 3-1/8" DCs. -Break out mill from shear pin guide washpipe extensions. -Recover misc parts of Jet cutter and -6" core of FasDrill com osite. 09:30 - 10:00 0.50 CLEAN P DECOMP Discuss results of FasDrill milling & retrieval run with ADW RWO engineering team. Decide to run same BHA with new mill & "flipper dog" sub. 10:00 - 12:00 2.00 CLEAN P DECOMP MU same BHA as last run with new mill/"flipper dog" sub. -Repin Shear pin guide & redress Pump out sub. -PU 4yts of 3-1/8" DCs from pipe shed. -RIH with 7-stds of 2-7/8" PAC DP. 12:00 - 12:30 0.50 CLEAN P DECOMP PU first stand of DP and pump through BHA to ensure string is clear. 12:30 - 15:00 2.50 CLEAN P DECOMP RIH with FasDrill mill / retrieval BHA on 4" DP from derrick. -Stop at 5300' and break circulation to ensure BHA is still clear. -BHA is clear. Continue RIH to 9384'. 15:00 - 20:00 5.00 CLEAN P DECOMP RIH and tag 4-1/2" tubing stub with shear pin assembly at 9429'. Shear pins at 15K-Ibs down. -Obtain milling parameters. -PU wt = 170K-Ibs, SO wt = 145K-Ibs, Rot wt = 157K-Ibs. -Pump at 4-BPM with 910-spi. Drop ball and pump down. Circ pressure with RCJB open = 1080-psi. -Rotate at 30-RPM with 3K-ftlbs of free torque. -RIH and tag up at 9473'. Pump pressure increase to 1350-psi. - i rom o 77' with 30-60-RPM with 4-6K-ftlbs torque. Running 5-10k WOM and pumping 3- 5 BPM with 660-1100 psi. - Plu free ~ 9477' wash down to X nipple ~ 9504' set down 10-15k serveral times, 5-8k overpull on pickup. - 40 b h D namic loss rate. 20:00 - 22:00 2.00 CLEAN P DECOMP POH & stand back 1-stand of DP to park mill at 9384' - Drop ball to open cire sub pump to seat ~ 3 bpm, 560 psi. - CBU @ 11 bpm 2000 psi. - Small amount of crude oil at shakers 85 bbls prior to bottoms up, cleaned up at bottoms up. - Monitor well, 36 bph static loss rate. 22:00 - 00:00 2.00 CLEAN P DECOMP POH with fishing assembly from 9384' to 4830' 7/21/2009 00:00 - 02:30 2.50 CLEAN P DECOMP POH with Fishing assembly #3 from 4830' to 1039'. - Stand back 4 3/4' DCs, 7 stands of 2 7/8" DP & LD 3 1/8" DC's - Recovered 1' of Fas ' - 1" of the fli er do shoe worn off and the connection had swelled due to over tor ued own hole. 02:30 - 04:30 2.00 CLEAN P DECOMP Wait on new RCJB from Baker shop. Printed: 7/29/2009 3:05:11 PM ~ ! BP EXPLORATfON Page 6 of 7 Qperations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: WORKOVER Start: 7/15/2009 End: 7/23/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/23/2009 Rig Name: DOYON 16 Rig Number: ' Date` Frorn - To Hours Task Code NPT Phase Qescriptian of Operations 7/21/2009 02:30 - 04:30 2.00 CLEAN P DECOMP - Clean Floor. - Install cradle for booster wheels on front of Rig. 04:30 - 06:30 2.00 CLEAN P DECOMP M/U BHA#4 consisting of 3 5/8" Reverse circulating basket,5 3/4" shear pin guide, (6) ea. 2 7/8" PAC DC's, 21 jts 2 7/8" PAC DP, XO, Bumper sub, oil jar, cire sub, XO, (6) ea. 4 3/4" DC's. = 1,039.01' 06:30 - 09:00 2.50 CLEAN P DECOMP RIH with BHA #4 on 4" DP from derrick. 09:00 - 10:30 1.50 CLEAN P DECOMP RIH and tag shear sub on 4-1/2" tubing stub at 9429'. Shear at 12K-Ibs down. -Obtain Milling parameters. PU wt = 165K-Ibs, SO wt = 138K-Ibs, Rot wt = 156K-Ibs. -Rotate at 60-RPM with 4K-ftlbs free torque. Pumps on at 4-BPM with 760-psi. -Continue RIH and ta Fasdrill lu at 9470' and then X Ni le at 9505'. Slight rotation got string through both. No other obstructions seen. -Continue to RIH and tag liner top (or plug on top of liner top) at 10,199'. -PU and reconfirm tag. -PU and mill for 10-minutes with above parameters. Run 5K-Ibs WOM with 4-6K-ftlbs of torque. Make -1' of progress. -PU, shut down rotation and RIH to tag and then set down 10k-Ibs. Repeat PU and set down. See slight overpull when PU off of bottom both times. -PU off bottom 1-std without overpulls. -Drop ball to open pump out sub and pump down at 3-BPM with 750-psi. Pump out sub shears open at 2100-psi. 10:30 - 12:00 1.50 CLEAN P DECOMP Circulate bottoms up at 11-BPM with 1700-psi. -Monitor well. -Pump dry job. , -losses tor past 12 hrs = 179 bbls. 'I 12:00 - 18:30 6.50 CLEAN P DECOMP Pull out of the hole laying down drillpipe. i - From 10,141'to 1,039' I 18:30 - 19:00 0.50 CLEAN P DECOMP Rig up 2-7/8" handling equipment and power tongs. ~, 19:00 - 20:30 1.50 CLEAN P DECOMP Lay down 21 jts 2-7/8" PAC DP and 6 3-1/8" DCs ' - Break and lay down RCJB unable to break shoe from basket, Piece of Fasdrill lu in bottom of revese basket. - Tools will be broke down at Baker shop. ' 20:30 - 21:00 0.50 CLEAN P DECOMP Clear floor of all Baker tools and 2-7/8" handling equipment. - Pull wear ring. ' 21:00 - 23:00 2.00 CLEAN P DECOMP Mobilize tubing equipment to rig floor. '~ - Install long bails. I - Rig up torque turn equpment. 23:00 - 00:00 1.00 RUNCO P RUNCMP PJSM. Run 4-1/2" com letion er runnin tall . - Bakerlok all connections below packer. - Use Jet Lube Seal guard pipe dope on all connections. - Makeup torque = 4,440 ft/Ibs. 7/22/2009 00:00 - 12:30 12.50 RUNCO P RUNCMP Run 4-1/2" completion per running tally. - Bakerlok all connections below packer. - Use Jet Lube Seal Guard pipe dope on all connections. - Makeup torque = 4,440 ft-Ibs. - Joint #127 RIH at 0630-hours; joint #198 at 1000-hours; - P/U joint #223 to RIH and tag the stub at 9430'. Calculate Printed: 7/29/2009 3:05:11 PM • M ~ ~ BP EXPLQRATIC~N Page 7 af 7 ' Operations Summary Report Legal Well Name: 02-17 Common Weil Name: 02-17 Spud Date: Event Name: WORKOVER Start: 7/15/2009 End: 7/23/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/23/2009 Rig Name: DOYON 16 Rig Number: Date Fram - To Hours Task Code NPT Phase Deseription of Operations 7/22/2009 00:00 - 12:30 12.50 RUNCO P RUNCMP spaceout with bottom of the Unique Machine overshot at 9440' for a 10' swallow of the 4-1/2" tubing stub. - POH with #223 and #222; P/U a full joint of 37.58' and RIH on top of joint #221. 12:30 - 13:00 0.50 RUNCO RUNCMP PJSM to land tubing. P/U and M/U hanger and RIH. Final pick-up weight: 142k. Final slack-off weight: 125k. Land hanger in tubing spool and run in lockdown screws. 13:00 - 14:00 1.00 RUNCO P RUNCMP Rig up circulating head to landing joint and hold PJSM with rig crew, CH2 truckers, TP and WSLs covering circulating operations. Pressure test lines to 3500 psi. 14:00 - 18:30 4.50 RUNCO P RUNCMP Reverse circulate 145-bbls of 110-F 2%-KCL followed by 500-bbls of 110-F corrosion inhibited seawater. 18:30 - 20:30 2.00 RUNCO P RUNCMP Drop ball and rod. Start to increase pressure on tubing to set Baker S-3 acker, saw shear begin at 1300-psi. Pressure tubing to 3500-psi and held for 30 charted minutes for a solid test. Bleed tubin ressure to 1500- si ressure u IA to 3500 si and test for 30 charted minutes for a solid test. Bleed tubin ! ressure and shear DCR valve. Pump 2-BPM at 50-psi, both ways, for a total 6-1/2-Bbls to confirm shear. 20:30 - 21:30 1.00 WHSUR P RUNCMP P/U and install TWC and test to 3,500 psi from above, 1,000 si from below for 10 min. record on chart 21:30 - 22:00 0.50 WHSUR P RUNCMP Blow down circulating choke and Kill lines. 22:00 - 22:30 0.50 WHSUR P RUNCMP PJSM. covering nipple down BOP and nipple up production tree. - Nipple down BOP. 22:30 - 00:00 1.50 WHSUR P RUNCMP Nipple up Adapter flange and tree. 7/23/2009 00:00 - 02:00 2.00 WHSUR P WHDTRE Continue Nipple up Adapter flange and tree, Test adapter flange and tree to 5,000 psi. Good test. 02:00 - 02:30 0.50 WHSUR P WHDTRE Riq up DSM lubricator and test to 500 psi. - Pull TWC - Rig down Lubricator. 02:30 - 04:00 1.50 WHSUR P WHDTRE PJSM, with Little Red. -R/U Little Red and Test lines to 3,500 psi. Freeze protect well to 2200' with 152 bbls diesel. - Displace ~ 3 bpm FCP 500 psi. - Haul #2 pump and Generator modules to DS-14. 04:00 - 05:00 1.00 WHSUR P WHDTRE Allow Diesel to U-Tube. 05:00 - 06:00 1.00 WHSUR P WHDTRE Install BPV, Test from below with Little Red to 1,000 psi. pood test. - Rig down Little Red. 06:00 - 07:00 1.00 RIGD P POST RD and prepare to move off the well 07:00 - 08:00 1.00 RIGD P POST Release Ri at 0700-hours. Move off the well and prepare to move the rig to DS 14-12. Printed: 7/29/2009 3:05:11 PM NOT OPERABLE: 02-17B (PT~2051300) Sustained Casing Pressure ~ to TxIA Co... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] '~~~ ~y~~Z~U % Sent: Thursday, May 07, 2009 9:36 AM ~`~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Quy, Tiffany; NSU, ADW WL & Completion Supervisor; NSU, ADW Tree Weilhead PE; NSU, ADW Wells Slickline Scheduler; Roschinger, Torin T.; Rico Hernandez, Claudia; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 02-17B (PTD #2051300) Sustained Casing Pressure due to TxIA Comm All, / Well 02-17B (PTD #2051300) has confirmed TxiA communication and has been secured with a tubing tail plug. A CMIT-TxIA passed confirming the well is secured. The well has been reciassified as Not Operable and will be further evaluated for repair options. ` Thank you, Anna ~Du6e, 2~.~. Well Integrity Coordinator GPB Welis Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 , . '~lb~~~ ,'~:; i r. ~~ ~~~U; ~~ ~ y 1 . From: NSU, ADW Well Integrity Engineer Sent: Tuesday, April 14, 2009 10:06 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DqA)'; GPB, Area Mgr East (FSl/2/COTU/5eawater); GPB, FSi OTL; GPB, FSi DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Quy, Tiffany; NSU, ADW WL & Completion Supervisor; NSU, ADW Tree Wellhead PE; NSU, ADW Wells Slickline Scheduler; NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Rico Hernandez, Claudia Subject: UNDER EVALUATION: 02-176 (PTD #2051300) Sustained Casing Pressure due to TxIA Comm All, Well 02-17B (PTD #2051300) has been confirmed to have sustained casing pressure due to TxIA communication as evidenced by repressurization post bieed. The wellhead pressures were 2240/2240/220 on 04/12/09 when the IA pressure was bled to 1830 psi and immediately repressured to 2220 psi. The well has been reclassified as Under Evaluation and may be returned to production while further diagnostic testing is completed. The pian forward includes evaluating the well for a leak detection log prior to changing out dummy gas lift valves. A TIO plot and welibore schematic have been included for reference. Please let us know if you have any questions. Thank you, 8/7/2009 NOT OPERABLE: 02-17B (PT~2051300) Sustained Casing Pressure ~to TxIA Co... Page 2 of 2 Anna ~u6e, ~P. E. Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: {907} 659-5100 x1154 8/7/2009 UNDER EVALUATION: 02-~ (PTD #2051300) Sustained Casing Pure due to TxL.. Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, April 14, 2009 10:06 PM '~,.~~ ~ L~ ~ ~~ ~D`'1 To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Quy, Tiffany; NSU, ADW WL & Completion Supervisor; NSU, ADW Tree Wellhead PE; NSU, ADW Wells Slickline Scheduler; NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Rico Hernandez, Claudia Subject: UNDER EVALUATION: 02-17B (PTD #2051300) Sustained Casing Pressure due to TxIA Comm Attachments: 02-17 TIO Plot.doc; 02-17B.pdf AI I, ~/ Well 02-176 (PTD #2051300) has been confirmed to have sustained casing pressure due to,TxlA communication as evidenced by repressurization post bleed. The wellhead pressures were 2240/2240/220 on 04/12/09 when t e IA pressure was bled to 1830 psi and immediately repressured to 2220 psi. The well has been reclassified as Under Evaluation and may be returned to production while further diagnostic testing is completed. The plan forward includes evaluating the well for a leak detection log prior to changing out dummy gas lift valves. A TIO plot and wellbore schematic have been included for reference. «02-17 TIO Plot.doc» «02-17B.pdf» Please let us know if you have any questions. Thank you, Anna ~Du6e, ~1'. E. ;_ Well Integrity Coordinator c`~Rx`~~~~..• ~~~ °~ ` ~~~°N GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 4/15/2009 PBU 02-17B PTD 205-130 4/14/2009 TIO Pressures anon 3,000 2,000 1,000 -#~ T bg -/ IA OA OOA ~- OODA On • 01!17/09 01!24!09 01!31109 02.107.109 02!14!09 02!21!09 02!28!09 03!07109 03114109 03!21109 03/28/09 04:'04:'09 04/11109 TREE= GRAY GEN 2 WELLHEAD= GRAY ACTUATOR = AXELSON KB. ELEV. - 62~ BF. ELEV..- __ KOP = 3098' Max Angle = 95° @ 13359' Datum MD = 10385' Datum ND = 8800' SS 120" CONDUCTOR 13-318" CSG, 72#, L-80,BTGM, ID = 12.347" 02-17B I 110' I I 2690' I I 9460' I 14-1/2" TBG, 12.6#, L-80, BTGM XO TO NSCT I Minimum ID =2.377" @ 12464' 3-3/16" X 2-7/8" XO (LINER) 4-1/2" TBG, 12.6#, L-8o, 9524' NSCT, .0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR 9525' MILLOUT WINDOW (02-17A) 9672' - 9717' 9-5/8" CSG, 47#, I-~ L-80/ SOO-95, ID = 8.681" S~ NOTES: W ELL ANGLE > 70° @ 10398' OR AL WELLBORE NOT SHOWN ON DIAGRAM. 2224' ~4-1/2" CAM BAL-O SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3993 3899 39 MMGM DMY RK 0 04/26/05 2 7479 6568 39 MMGM DMY RK 0 04/26/05 3 9401 8079 37 MMGM DMY RK 0 04/26/05 9470' 9-5/8" X 4-1/2" TIW HBBP-T PKR, ID = 3.917" 9504' 4-1/2" HES X NIP, ID = 3.813" 9~ 524' I-14-1/2" X 5-1/2" XO, ID = 3.920" 9525' 9-5/8" X 7" BKR ZXP PKR w / 6' PBR, ID = 6.3125" 9527' 5-112" WLEG, ID = 4.00" ELMD TT NOT LOGGED 9539' 9-5/8" BKR HMC HGR, ID = 6.187" 9546' 7" X 5-1/2" XO, ID = 4.812" 954$' 5-1/2" X 4-1/2" XO, ID = 3.937" 10198' I--~ 3-1 /2" X 4-1 /2" LNR TOP PKR, ID = 2.992" 10204' 4" BOT DEPLOY SLV, ID = 3.00" 10209, I-~ 4" X 3-1 /2" XO, ID = 3.00" 10223' 3-1/2" HOWCO X NIP, ID = 2.813" 13-1/2" LNR, 8.81#, L-80, STL, .0087 bpf, ID=2.992" I WHIPSTOCK - MONOBORE (09/07/05) RA TA G 14-1/2" LNR, 12.6#, L-80, BTGM, .0152 bpf, ID = 3.958" I PERFORATION SUMMARY REF LOG: CNL ON 09/13/05 ANGLEATTOPPERF:93°@ 11270' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2 6 12270 - 12560 O 09/14/05 2 6 12630 - 12850 O 09/14/05 2 6 12950 - 13370 O 09/14/05 2 6 13470 - 13490 O 09/14/05 3-3/16" LNR, 6.2#, L-80, I 12464' TCII, .0076 bpf, ID = 2.80" 12464' 3-3/16" X 2-7/8" XO, ID = 2.377" 13554' I-IPBTD ~2-7/8" LNR, 6.16#, L-80, STL, .0058 bpf, ID= 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 1980 ORIGINAL COMPLETION 05/25/07 JAD/PJC DRLG DRAFT CORRECTIONS 10/05/84 N1 B RWO 10/05/96 N2ES SIDETRACK "A" 09/06/07 N2ES CTD "B" 09/26/05 EZL/TLH WANERSAFETY NOTE 05/08/07 RDW/PJC WANERSFTY NOTE DELETED I 13570' I PRUDHOE BAY UNff WELL: 02-17B PERMfT No: 2051300 API No: 50-029-20453-02 SEC 36, T11 N, R14E, 787' FEL & 213' FNL BP 6rploration (Alaska) ' ~`'"' 10256' -~ 3-1 /2" X 3-3/16" XO, ID = 2.786" 11606' 10392' TNV 4-1/2" MLAS-CV SUB w /PROFILE, ID = 3.890" 11615' MILLOUT WINDOW (02-17B) 11606' - 11628' I ~ ~ ~ ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051300 Well Name/No. PRUDHOE BAY UNlT 02-178 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20453-02-00 MD 13576 TVD 8835 Completion Date 9/15/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD / EWR / SGRD / SGRC / SROP, MGR /CCL / CNL Well Log Information: Log/ Electr Data Digital Dataset Log Log Run T~e Med/Frmt Number Name Scale Media No -_ --- --- ------- ---- y ------- ---------- jD D Asc Directional Surve QED C Tf 13413' 1 Loo Neutron 2 Blu 1 D D Lis 13442 ~amma Ray pt Lis 13442 Gamma Ray D C Pdf 13889 ''Rate of Penetration n 8-10 B " C Lis 13889 ~~ity ~ '"~ Directional Survey Yes /~. (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments - --------- --- - 11598 13576 Open 9/26/2005 IIFR 100 11616 Case 1/24/2006 TIF WIRELINE LOGS 13545 13650 Case 1/24/2006 MEMORY COMPENSATED NEUTRON LOG MEMORY MPL/CCL/GR/NEUTRON 11350 13548 1!31/2006 GR/ROP 11350 13548 1/31/2006 GR/ROP 11626 13576 5/10/2006 ROP NGP 4-Sep-2005 11350 13579 5/10/2006 GR, ROP Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y / N Analysis ~~ Y / N Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? `~-~ N Formation Tops ~ N Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051300 Well Name/No. PRUDHOE BAY UNIT 02-176 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20453-02-00 MD 13576 TVD 8835 Completion Date 9/15/2005 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: _~__d ~` ~N~ _7 i !- 02-17 (PTD #2051300) Internal Waiver Can~ation -Normal Well ~2-17 ~ Subject: 02--1'T (PTD #2051300) Internal Waiver Cancellation -Normal Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWeII[ntegrityEngineer@BP.com> Date: Tue, 08 May 2007 14:45:23 -0800 ~~'~~ 5 ~~~~~ 7 To: toi~~i7~aunder~c~:;admin ,late.ak.us'. "jim rc~,_~r~iadmin.state.ak.us" ~~'jin~ rc~~~(c~;admin.state.ak.us' ~, "boh ileckcnsteinru:admin.state.akus~~ 'bob. lleckensteinl~l'admin.state.ak.us'>, "NSA!. ADW' Vl-'~11 Operations Super~~isor" NSU,4D~UWzllOpcrationsSupcrvisor(cr`BP.com=-~, "Rossber~~, R Ste~-en'~ Ste~~en.Rossberg(abp.com= "GPB, FS1 OTI," -~GPBFSIOTL(~~;bp.com=~. "GPB, Area Mgr East (FSIi?~COTl1 Sea~~~atcr)" <GPBAreal~lgrEastFS1?('S~u?BP.com~~, "GPB, FS1 DS Ops Lead" ~~GPBTS l DSOpsLead~~r?BP.com=> "GPB, ~~'ells Opt End" <GPBWc1lsOptEn~~i~c?BP.com==, "GPB, LOC Specialists" -(~PBEOCSpecialists;~c BP.com=. CSC: "NSU, AD~V tip;°cll lntegritti~ Engineer" ~ ~1St_~~~~Dti~~«`e111nt~~~rityEn~ineer(cr,I3P.con>>, "~Sli, r~D~~' ~~'I Tech" :~Sl':~D~~'~~"l"~echV}3P.com , All, C32.-i T 1a An internal waiver was issued for IAxOA communication on well Q2f1'7 (PTD #2051300) on 09/25/05. The well passed an MITIA on 04/03/07 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1, 2007, well t~ 1~ will be Operable. U Z-~ ~ r3 The well is reclassified as a Normal well. Please remove all waivered well signs and the lamintaed copy of the waiver from the wellhouse. Thank you - jack L. Winslow (far Andrea Hughes) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 1 of 1 5/10/2007 10:58 AM 0 3'b`~ 9 aos- t~~ • WELL LOG TRANSMITTAL To: State of Alaska Apri127, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`~ Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 02-17B, 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 02-17B: LAS Data & Digital Log Images: 50-029-20453-02 1 CD Rom aos- /30 • • WELL LOG TRANSMITTAL To: State of Alaska January 27, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 02-17B, o2D5_ I~AK-MW-3229698 ~~~ ~~ 1 LDWG formatted Disc with verification listing. API#: 50-029-20453-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Dater 3l p Signed: Schiumherger Alaska Data & Consulting Services 2525 Garnbell Street, Suite 400 Anchoraye, AK 99503-2838 ATTN: Beth Wall _Inh tt r ,, ne ..ar.. ~V~~ V ~~ t114i~ 2 4 2006 ~l ~ C,~S Cufi-S. ~m J~f's<~1G("~~ NO. 3668 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 995x'^. Field: Prudhoe Bay, Milne Pt. 01!23/06 D-1U 10913021 LDL 06/02/05 1~ Z-24 11183454 LDL 12/29/05 1 DS 13-22 10987560 INJECTION PROFILE 01/05/06 1 G-11A (REDO) 11084277 RST-SIGMA 07/12/05 1 W-17A 10987549 USIT-PDCL 09/20/05 1 U2-17B ~ - ( p 10928646 MCNL 09/13/05 1 1 MPS-10A 11076475 SCMT 10/17/05 1 W-17A 10913044 USIT 09/03!05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth -_ Received by C C] STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COM~ION ~~~ V ~. ~~~ ~ ~~Q WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oi! & Gas Gans. Garrnt~issori! 11 nr~l,~~... 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.~os zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One P Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 9/15/2005 12. Permit to Drill Number 205-130 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/7/2005 13. API Number 50-029-20453-02-00 4a. Location of Well (Governmental Section): Surtace: 213' FNL 787' FWL SEC 36 Ti 1 N R14 7. Date T.D. Reached 9/12/2005 14. Well Name and Number: PBU 02-17B , , . , , E, UM Top of Productive Horizon: 3922' FSL, 869' FEL, SEC. 26, T11 N, R14E, UM g. KB Elevation (ft): 61.61' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 5154' FSL, 2209' FEL, SEC. 26, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 1.3534 + 8838 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 687518 y- 5950986 Zone- ASP4 10. Total Depth (MD+TVD) 13576 + 8835 Ft 16. Property Designation: ADL 028308 TPI: x- 685758 y- 5955078 Zone- ASP4 Total Depth: x- 684 3 88 Y- 5956277 Zone- ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: _ _ _ _ 18. Directional Survey ®Yes ^ No i9. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900 (Approx.) 21. Logs Run: MWD / EWR / SGRD / SGRC / SROP, MGR / CCL / CNL 2• ASING, LINER AND EMENTING RECORD CASING ETiINCi EPTH MD ETTINO EPTH TVD HOLE MOUNT. SIZE WT. PeR Fr. GRADE OP OTTOM OP TTOM SIZE CEMENTING RECORR PULLED 20" 94# H-40 Surface 110' Surtace 110' 32" 00 sx Permafrost 13-3/8" 72# L-80 Surtace 2690' Surface 2690' 17-1/2" 300 sx Fondu, 400 sx Permafrost 9-5/8" 47# S00-95 Surface 9672' Surface 8296' 12-1/4" 1400 sx Class 'G' 4-1/2" 12.6# L-80 9539' 11606' 8189' 8860' 6" 395 sx Class 'G' 3-1/2° x 3-3116• x 2-71e• a.ai p / s.zs / s.~sn L-80 10204' 13570' 8758' 8835' 4-1 /8" 157 sx Class 'G' 23. Pertorations open to Produc B I tt l S tion (MD + TV D of Top and " " 24. TUBING REGOHD om nterva o , ize and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9527' 9470' MD TVD MD TVD 12270' - 12560' 8850' - 8853' 12630' - 12850' 8853' - 8857' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12950' - 13370' 8859' - 8849' 13470' - 13490' 8843' - 8842' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect w/ McOH 26. PRODUCTION TEST Date First Production: September 25, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 9/28/2005 Hours Tested 6.1 PRODUCTION FOR TEST PERIOD OIL-BBL 605 GAS-MCF 1,618 WATER-BBL -0- CHOKE SIZE 59.06 GAS-OIL RATIO 2,673 Flow Tubing Press. 431 Casing Pressure 640 CALCULATED 24-HOUR RATE OIL-BBL 2,382 GAS-MCF 6,367 WATER-BBL -0- OIL GRAVITY-API (CORK) ~~ 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". ~ ~ ~ ~ `` f ~ o.~r,,.,.h..~ //,~~r~ M ~~'7 y9 s~s~~ None V iF3F..Ct " - ~ ~ ~ ~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ j (~(~ 28 GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kicked off and remained in None Sadlerochit /Zone 1 A 10493' 8888' (From 02-17A) 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 Terris Hubble w Title Technical Assistant Date ~ ~ ~ ~ off,' VS PBU 02-17B 205-130 Prepared By Name/Number. Terris Hubble, 564-4628 Well Number Drilling Engineer: Ted Stagg, 564-4694 Permit No. / A royal No. INSTRUCTIONS GENEaAr.: 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). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only • BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2005. End: Contractor Name: NORDIC CALISTA Rig Release: 9/15/2005 Rig Name: NORDIC 1 Rig Number: N1 ~ ~ Date ; From - To '~ Hours Task Code NPT Phase ~ Description of Operations 9/2/2005 05:00 - 05:15 0.25 MOB P PRE Rig released from F-27A @ 05:OOHrs on 9/2/2005. Prep to move rig off well. 05:15 - 06:00 0.75 MOB P PRE PJSM. Jack-up rig & pull rig off well. Conduct post-operations pad inspection. 06:00 - 15:00 9.00 MOB N WAIT PRE W.O. Tool Services to lay matting boards on F-pad access road. 15:00 - 15:15 0.25 MOB P PRE Held pre-move safety meeting with crew, security & tool services. 15:15 - 00:00 8.75 MOB P PRE Move rig from F-pad to DS#02. Had to wait on Tool Services to reposition mat boards at several places. 9/3/2005 00:00 - 02:30 2.50 MOB P PRE Move rig from F-pad to DS#02. Arrive C~3 DS#02 & position rig in front of 02-17. Install dikes around tree. 02:30 - 07:00 4.50 MOB N WAIT PRE DSM source & install work platform on 02-17 tree. Remove tree cap. Check well pressures & observe WHP = Opsi, IAP = Opsi & OAP = 210psi. 07:00 - 07:15 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for backing rig over well 07:15 - 07:30 0.25 MOB P ~ PRE Back rig over well & set down. Accept rig @ 07:30Hrs on 9/3/2005. 07:30 - 08:30 1.00 RIGU P PRE N/U BOPE. 08:30 - 09:00 0.50 RIGU P PRE R/U &PJSM for BOPE testing. 09:00 - 17:00 8.00 BOPSU P PRE Perform initial BOPE pressure/function test. Had to fix leaking test pump. Also slip indentations on test joint causing BOP seals to leak. Changeout test joint & achieve good pressure tests on BOPE. AOGCC test witnessed by Chuck Scheve. Meanwhile spot outside trailers & tanks. Position wellsite safety coordination shack C~? pad entrance. R/U hardline to tiger tank & P/test to 4000psi. Fill rig pits with 2% KCL water. 17:00 - 18:30 1.50 RIGU P PRE Install dart catcher. Pump 10bbls of KCL-water. Load wiper dart. Launch & chase with 2% KCL. Dart hit @ 51.1 bbls. Pressure test inner reel valve to 3500psi - OK. 18:30 - 19:30 1.00 WHIP P WEXIT Cut 6' coil. MU CTC. - Pull test to 35k. - Pressure test to 3500 psi. 19:30 - 20:15 0.75 WHIP P WEXIT PU WFD fishing BHA. 20:15 - 22:45 2.50 FISH P WEXIT RIH with WFD fishing BHA. - Displacing MEOH to TT. - Circulating 0.9 / 1.2 bpm at 400 psi. - At 11,600': 44k PU, 24k SO 22:45 - 23:30 0.75 FISH P ', WEXIT Tag fish at 11,660'. SD pumps. Set down 10k on fish. PU 48k. RIH, set down 5k at 11,660' MD. PU 45k. RBIH, set 15k down. PU to 65k. Wait, no jar lick. Set down 15k. PU to 70k. Wait, no jar lick. Set down 15k, PU to 80k. No go. PU again, looks like jars went off on way up at 64k. PU 62k. No go. PU 58k. No go. Set down to 4k. Wait. Jarred down. PU 74k. No go. Looks as though jars are not working. - Pump off. Did not pump bio sweep. 23:30 - 00:00 0.50 FISH P WEXIT POOH. - Pump at 2.4 / 2.1 bpm. - Paint EOP flag at 11,400' MD. 9/4/2005 00:00 - 01:45 1.75 FISH P i W EXIT POOH with fishing assy. 01:45 - 02:30 0.75 FISH P I WEXIT Tag up. Lay down fishing assembly. Printed: 9/79/2005 8:38:09 AM BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date_ - Name: 0 ell Name: 0 e: Name: From - To ~I 2-17 2-17 REENTE NORDIC NORDIC j Hours 4 R+COM CALIST 1 Task ' - - PLET A Code E NPT Start Rig Rig Phase ~ Spud Date: : 9/2/2005 End: Release: 9/15/2005 Number: N1 Description of Operations 9/4/2005 02:30 - 04:30 2.00 WHIP ( P _ _ WEXIT - -- MU WS assy. - Baker Gen II 4-1/2" monobore WS, FAIV, orienter, MWD. - Insert 2 RA pip tags into WS. -Install Baker CTC. Pull and pressure test. 04:30 - 06:30 2.00 WHIP P WEXIT RIH with Baker WS assy. - SHT MWD and orienter. - Set down 8k at 10,390' MD. PU to 48k, overpull to 65k. Slack off to neutral. PU to 70k. 06:30 - 06:45 0.25 WHIP N DPRB WEXIT Discuss plan forward with ANC. Suspect WS is hanging up @ squeezed cmt nodes on the upper perfs. 06:45 - 08:15 1.50 WHIP N DPRB WEXIT Bring on pumps to 1.6bpm/1500psi: Confirm TF @ 3R. Orient 4 clicks & confirm TF @ 20R. Pressure up backside to 1500psi & pull to 50k without success. Orient 8 clicks - TF @ 31 R. Stack down wt & push WS free. RIH ratty & set down @ 10412'. P/U clean @ 46k. PUH & pull tight (60k) @ 10380'. RBIH to neutral wt @ 10392'. 08:15 - 11:45 3.50 WHIP N DPRB WEXIT Orient TF to 40L. Getting only intermittent 10degs clicks. 11:45 - 13:30 1.75 WHIP N DPRB WEXIT Held up @ 10389' with no up & down movement. Set down max wt (-17k) no movement. Orient TF to 36L. Work string between 60k & -17k without luck. Pressure up backside to 1500psi & pull to 50k without success. Pull to 75k & put 1500psi on the backside. Continue working pipe. Work down to 10410'. P/U & get stuck. Orient to 25L. Work pipe with 75k pull & 1500psi backside pressure & shear off. 13:30 - 15:45 2.25 WHIP N DPRB WEXIT POOH pumping across the WHD with 200psi back pressure. 15:45 - 16:30 0.75 WHIP N DPRB WEXIT OOH. PJSM. S/B injector. L/D BHA & observe that WS has sheared off from the setting tool. 16:30 - 17:00 0.50 FISH N DPRB WEXIT W.O. Baker fishing tools. Meanwhile changeout packoffs. 17:00 - 18:00 1.00 FISH N DPRB WEXIT M/U Baker WS fishing BHA#3 with WS release hook, MWD, orienter, dual acting jar, 2 wt bars, accelerator & MHA. M/U injector. 18:00 - 19:00 1.00 FISH N DPRB WEXIT RIH fishing BHA#3, pumping minimum rate. - SHT orienter at 3000' MD. First click went normal, second click pressured up. Try again, pressured up. Bleed off pressure. 19:00 - 19:30 0.50 FISH N DPRB WEXIT POOH to check BHA for plugging. 19:30 - 21:00 1.50 FISH N DPRB WEXIT Change out pulser and orienter. No obvious restriction. 21:00 - 23:30 2.50 FISH N DPRB WEXIT RIH with new BHA. -Surface test orienter. - Circulate min rate. - Test orienter again at 6000' MD. Increase rate to 2.25 bpm, pressure increesd to 3200 psi, fluctuating to 2500 psi. Pressured up to 4500 psi keeping flowrate constant. Decrease rate to 1.5 bpm, pressure decreased to 2700 psi. Pressure fluctuating +/- 500 psi. Decide to keep flow at 1.5 bpm, pressure still fluctuating. Switch pumps. Pressure continues to fluctuate. Not getting good signal from MWD. 23:30 - 00:00 0.50 FISH N DPRB WEXIT POOH. 9/5/2005 00:00 - 00:30 0.50 FISH N DPRB WEXIT Continue to POOH. 00:30 - 02:15 1.75 FISH N DPRB WEXIT LD entire BHA, inspect all components for source of restriction. - C/O dual BPV. - Changed stator on pulser. Printed: 9/19/2005 8:38:09 AM • BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/15/2005 Rig Name: NORDIC 1 Rig Number: N1 I Date From - To 'Hours Task Code NPT ' Phase Description of Operations 9/5/2005 00:30 - 02:15 1.75 FISH ~ DPRBWEXIT ~ Surface test OK. 02:15 - 03:15 1.00 FISH N DPRB WEXIT RIH with fishing BHA. 03:15 - 03:45 0.50 FISH N DPRB WEXIT 03:45 - 04:30 0.75 FISH N DPRB WEXIT 04:30 - 05:00 I 0.501 FISH I N I DPRB I W EXIT 05:00 - 05:30 I 0.501 FISH I N I DPRB I WEXIT 05:30 - 06:30 I 1.001 FISH I N I DPRB I WEXIT 06:30 - 08:10 1.67 FISH N DPRB WEXIT 08:10 - 08:25 0.25 FISH N DPRB WEXIT 08:25 - 12:00 3.58 FISH N DPRB WEXIT 12:00 - 14:00 2.00 FISH N DPRB ~' , W EXIT 14:00 - 14:45 0.75 FISH N DPRB ; WEXIT 14:45 - 15:15 I 0.501 FISH I N I DPRB I W EXIT 15:15 - 16:00 0.75 FISH N DPRB ~ WEXIT 16:00 - 16:15 0.25 FISH N DPRB I WEXIT 16:15 - 16:40 I 0.421 FISH I N I DPRB I W EXIT 16:40 - 18:45 2.081 FISH N DPRB WEXIT 18:45 - 19:00 0.25 FfSH N DPRB WEXIT 19:00 - 20:15 1.25 FISH N DPRB WEXIT - Circulating as RIH. Pressures and rate consistent, 1 bpm/650 psi. - Stop at 3000' MD to SHT orienter. Circulating at constant 1.86 bpm, pressure increasing steadily to 4200 psi then leveling off to 3000 psi (approximately 7 minutes). MWD pulsing, no information making it to surface. Increase rate to 2 bpm, 3000 psi. Still no MWD signal to surface. POOH. Change out sonde. Modify equalizer sub from 10/32" and blank to the annulus to 12/32" and open to the annulus. RIH with fishing BHA #6. - Surface test ok. 2.25 bpm, 3000 psi. Signal looks good. - At 1000', pressures begin fluctuating again. Signal gone. POOH. LD BHA. MU BHA #7. Reconfigure BHA, put jars etc below the MWD/orienter. RIH with BHA #7. - Circulate 2.0 bpm, 2800 psi. Fluctuations increase as RIH. - Stopped at 1000' MD. 2.1 bpm, 3000 psi. Flatline pressure. - SHT tools ~ 3000' with 2.3bpm13200psi -got 2 for 2 clicks. Continue RIH fishing BHA#7 to 10300'. Wt check: Up = 45k. Down = 24k. Check TF 75L. Orient to 125R (+/-180degs from LOHS TF). Meanwhile arrange for BKR muleshoe guide. S/D pumps & RIH C 20fpm & tag @ 10395'. P/U slow & observe no engagement. Orient around & try to slide hook into WS slot C various TFs without luck. Max O/pull observed is 3k. Click all round & retry without luck. Orient to 159R. RBIH & set down @ 10395'. P/U 3' & click around while on tray. Only got 1 click. Attempt to hook WS - no luck. Retry again without success. Decide to POOH to cut CT & P/U BKR muleshoe guide that would better align hook on WS tray. POOH fishing SHA#7 OOH. PJSM. S/B injector. UD fishing BHA#7. Take hook to Baker to M/U to muleshoe skirt. PJSM. R/U hydraulic cutter & cut 150' of CT for fatigue management. W.O. Baker fishing tools. PJSM. Behead & M/U Baker CTC. Pull test to 38k & pressure test to 3500psi- OK. M/U Baker WS fishing BHA#8 with WS release hook & muleshoe guide, MWD, orienter, dual acting jar, 2 wt bars, accelerator & MHA. Scribe tools. M/U injector. RIH Baker WS fishing BHA#8. SHT tools @ 3000' with 2.3bpm/3000psi -got 2 for 2 clicks. Continue RIH. Check PU (42k) and SO (22k) at 10,300' MD. Orient TF to 134R. Getting clicks 1:1. RIH to tag at 10,391.8' MD. Fish whipstock. - Begin at 134R, setting down a couple times at each orientation. - Latch fish at 111 R. Printed: 9/19/2005 8:38:09 AM BP EXPLORATION Operations Summary Report Page 4 of 10 Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/15/2005 Rig Name: NORDIC 1 Rig Number: N1 Date !From - To Hours I Task Code I. NPT Phase ! Description of Operations 9/5/2005 20:15 - 20:30 0.25 FISH 20:30 - 22:45 2.25 FISH 22:45 - 23:30 0.75 FISH N N N 23:30 - 00:00 I 0.501 FISH I N 9/6/2005 00:00 - 01:45 1.75 CLEAN N 01:45 - 03:00 1.25 CLEAN N 03:00 - 05:00 I 2.001 CLEAN I N 05:00 - 06:00 I 1.001 CLEAN I N 06:00 - 07:00 1.00 CLEAN N 07:00 - 07:45 0.75 CLEAN N 07:45 - 10:00 I 2.251 CLEAN I N 10:00 - 11:00 1.00 CLEAN N 11:00 - 11:30 0.50 CLEAN N 11:30 - 14:00 I 2.501 CLEAN ( N 14:00 - 14:45 I 0.75 I CLEAN I N 14:45 - 15:30 I 0.751 WHIP I N 15:30-18:401 3.171 WHIP IN 18:40 - 20:00 1.33 WHIP P 20:00 - 20:45 0.75 WHIP P DPRB WEXIT Jar fish with 62k PU. Jar free. DPRB WEXIT POOH with BHA #8, dragging fish DPRB WEXIT LD BHA and fish. - Remove RA tags from WS. DPRB WEXIT MU BHA #9, cleanout BHA - Parabolic 3.79", string 3.78" DPRB WEXIT RIH with cleanout assy, circ min rate. DPRB WEXIT ~ Clean out well from 10,300' MD. - 2.5 / 2.6 bpm, 2000 psi. - Pump 20 bbls 2 ppb bio sweep. Lightly tag top of fish at 11,652.3' MD (pumps on). ( DPRB WEXIT POOH. -Paint EOP flag at 11500' MD. - Motor work/overpulls at 9700'. RBIH 30', maintaining circulation. Continue to POOH. DPRB WEXIT LD BHA #9. PU drift BHA #10. - Boot basket, jars, and 4 each 3.625" weight bars. - Circulate across the top. -Will wait for boot basket from Baker. DPRB WEXIT W.O. Baker junk basket. DPRB WEXIT M/U Baker drifting BHA#10 with 4 wt bars, jaunk basket, dual acting jar & MHA. M/U injector. DPRB WEXIT RIH Baker WS fishing BHA#10. Continue RIH. Wt check ~ 10300' - 42k. Run-in wt - 22k. Set down ~ 10385'. P/U with 2k O/pull. RBIH clean Q 10fpm thru restriction & continue RIH clean to TOF lightly tagged ~ 11649'. PUH to 11630'. DPRB WEXIT Circ 2% KCL while W. O. hivis flopro pill. DPRB WEXIT Circ 30bbls of hivis flopro pill follwed by 10bbls of 2% KCL & another 30bbls of hivis flopro pill. Displace pill & chase @ 3.40bpm/1380psi. DPRB WEXIT POOH @ 40fpm chasing pills out @ 3.36bpm/1320psi. POOH clean thru 10385' to 10350'. RBIH clean to 10470'. PBUH clean & continue POOH to surface. - While POOH, jetted possum belly and MM. Recovered rocks, largest conglomerate 2" x 3" x 1.5", looks to be cemented together. Magnets covered in metal shavings. DPRB WEXIT LD BHA #10. Boot basket full of brass, rubber, and metal shavings. DPRB WEXIT PU BHA #11, 4-1/2" Gen II monobore WS. - 2 pip tags in WS. DPRB WEXIT RIH with WS. - SHT ok -Circ min rate, 86 fpm. - Slow to 30 fpm from 10,300 - 10,600' MD. Minor (1-2k) stackup, went right through. RIH to 11170 WEXIT Tie-in. No correction. WEXIT RIH to setting depth top of WS 11620'. Up Wt 41 K. DN Wt 24K. Orient at 1.4 bpm with 1050 psi to 55L Increase rate to 3 bpm at 4160 psi Bleed off to allow rate to equalize 0/0 Pressure to 3200 psi with .4bbls shear@ 3200psi. Final TF 27L Set down 3k Printed: 9/19/2005 8:38:09 AM \J BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/15/2005 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To ~ Hours Task ' Code I NPT Phase Description of Operations 9/6/2005 20:00 - 20:45 0.75 WHIP P W EX I T 20:45 - 21:00 0.25 WHIP P WEXIT Drop 3/4 ball. Circulate well to 2# bio. 21:00 - 23:40 2.67 WHIP P WEXIT POH. 23:40 - 00:00 0.33 WHIP P WEXIT LD WS setting tool. 9/7/2005 00:00 - 03:00 3.00 WHIP P WEXIT RI H tag W S at 11616 03:00 - 10:15 7.25 STWHIP P WEXIT Mill window. Up 42K,Dn Wt 13K. Control milling 2.55 / 2.55 bpm at 1950 psi. - Start milling at 11,620.5' MD. - Punched through at 11,628' MD. 10:15 - 11:45 1.50 STWHIP P WEXIT Drill ahead in formation to 11,638' MD. - Circulate hole with flo pro. 11:45 - 13:00 1.25 STWHIP P WEXIT Dress window. Dry run through window. 13:00 - 15:30 2.50 STWHIP P WEXIT POOH with milling BHA. 15:30 - 15:45 0.25 STWHIP P WEXIT LD milling BHA. - Window mill 3.80" no go. 15:45 - 17:30 1.75 DRILL P PROD1 PU build BHA #12. - Hughes bicenter. - 3.0 deg motor. 17:30 - 20:00 2.50 DRILL P PROD1 RIH with build BHA. - SHT at 3000' MD. RIH to11595 set down. Orient to 64L RIH to 11635 20:00 - 00:00 4.00 DRILL P PROD1 Orient 90L Directionally drill 2.5 / 2.5 bpm @ 3100 psi. 2950 psi=FS, ROP 25 9/8/2005 00:00 - 02:40 2.67 DRILL P PROD1 Directionll drill to 11726. 02:40 - 05:00 2.33 DRILL P PROD1 Tie-in to formation correction -9.5'. RIH. Tie-in to WS. RA 11614.5' TOW =11606.4', BOW= 11613.9' RIH. 05:00 - 06:30 1.50 DRILL P PROD1 Directionally drill to end of build at 11,775' MD. - 2.5 / 2.5 bpm at 3000 psi. 06:30 - 08:45 2.25 DRILL P PROD1 POOH with build BHA #12. 08:45 - 09:45 1.00 DRILL P PROD1 Decrease bend to 1.0 deg. 09:45 - 12:00 2.25 DRILL P PRODi RIH with lateral BHA #13. -SHT at 3000' MD. 12:00 - 13:00 1.00 DRILL P PRODi Tie in. -13' correction. RIH. - Tag bottom at 11,776' MD 13:00 - 22:15 9.25 DRILL P PROD1 Drill ahead to 11,833' MD. - Free spin 2900 psi at 2.5/2.6 bpm - TF at 120E - ROP 20-30 fph, stalling - Mud swap started at 17:00 hrs. 22:15 - 22:45 0.50 DRILL P PROD1 Wiper to window. 22:45 - 00:00 1.25 DRILL P PROD1 Directionally drill 2.47/2.47 C~3 2850 psi FS= 2550 psi. 9/9/2005 00:00 -04:15 4.25 DRILL P PROD1 Directionally drilling 2.5/2.5 bpm @ 2850 psi, FS 2550 psi. 04:15 -04:50 0.58 DRILL P PROD1 Wiper to window. 04:50 - 06:30 1.67 DRILL P PRODi Directionally drilling 2.6/2.6 bpm ~ 2890 psi, FS 2550 psi., WOB 3K, ROP 40. Drill to 12,157' MD - ROP consistent, regardless of formation. Not able to put weight down without stalling motor. 06:30 - 08:45 2.25 DRILL P , PROD1 POOH to change motor. Bit ok. Printed: 9/19/2005 8:38:09 AM • BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 0 2-17 Common W ell Name: 0 2-17 Spud Date: Event Nam e: REENTE R+COM PLET E Start : 9/2/2005 End: Contractor Name: NORDIC CALIST A Rig Release: 9/15/2005 Rig Name: NORDIC 1 Rig Number: N1 Date !! From - To ' Hours Task Code NPT Phase '~, Description of Operations 9/9/2005 08:45 - 10:00 1.25 DRILL P PRODi Change out motor, bend at 1.0 deg. Check bit. 10:00 - 12:00 2.00 DRILL N RREP PROD1 Engine #1 repair - Antifreeze leaking by seal into oil. Replace same. 1 NOTE: Keeping hole full. 12:00 - 14:30 2.50 DRILL P PROD1 RIH with lateral BHA #14. - SHT at 3000' MD. - OK through +/- 10,400' MD. - Orient through window. 14:30 - 15:00 0.50 DRILL P PROD1 Tie in. Correct -18.5 feet. 15:00 - 15:30 0.50 DRILL P PROD1 RIH. Orient 80L. Tag TD at 12,162' MD. - Lost approximately 11 bbls while OOH. 15:30 - 18:50 3.33 DRILL P PROD1 Drill ahead. - Free spin 2800 psi at 2.5 bpm. - Drilling at 3100 - 3300 psi. - 50 - 70 fph ROP, 14k CT wt. 18:50 - 20:30 1.67 DRILL P PRODi Wiper to window. 20:30 - 00:00 3.50 DRILL P PROD1 Drill ahead. - Free spin 2720 psi at 2.6 bpm. - Drilling at 2850 psi. - 50 - 70 fph ROP, 12k CT wt. 9/10/2005 00:00 - 01:30 1.50 DRILL P PROD1 Directionally drill 2.5/ 2.5 bpm at 3070psi, FS = 2720psi. WOB 4K, ROP 50 -70. 01:30 - 03:00 1.50 DRILL P PROD1 Wiper to 10200'. 03:00 - 06:30 3.50 DRILL P PROD1 Directionally drill to 12,600' MD - 2.6/ 2.6 bpm at 3170psi, FS = 2720psi. WOB 2K, ROP 50 . 06:30 - 07:00 0.50 DRILL P PROD1 Wiper trip to window. 07:00 - 07:30 0.50 DRILL P PRODi Tie in. +10 ft correction. 07:30 - 08:00 0.50 DRILL P PROD1 RIH to bottom. 08:00 - 09:30 1.50 DRILL P PROD1 Drill ahead to 12,657' MD. - 135L, orient as required. - 2.6/2.67 bpm, 3300 psi - 2900 psi free spin. 09:30 - 09:45 0.25 DRILL P PRODi Orient back around to 135 L. 09:45 - 10:30 0.75 DRILL P PROD1 Drill ahead to 12,724' MD. - 135L, orient as required. - 2.6/2.67 bpm, 3300 - 3500 psi - 2900 psi free spin. - ROP at 100 fph. 10:30 - 10:45 0.25 DRILL P PROD1 Orient to 135L. 10:45 - 11:15 0.50 DRILL P PROD1 Drill ahead to 12750' MD. - 135L, orient as required. - 2.6/2.67 bpm, 3300 - 3500 psi - 2900 psi free spin. - ROP at 100 fph. - 8k Ct wt. 11:15 - 13:45 2.50 DRILL P PRODi Wiper trip to 10,200' MD. 13:45 - 16:15 2.50 DRILL P PRODi Drill ahead to 12,920' MD. - 90L, orient as required. - 2.6/2.67 bpm, 3300 - 3500 psi - 2900 psi free spin. - ROP at 100 fph. - 8k Ct wt. Printed: 9/19/2005 8:38:09 AM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date 'From - To Hours Task Code i NPT 9/10/2005 ~ 13:45 - 16:15 2.50 DRILL ~ P 16:15 - 17:45 1.50 DRILL P 17:45 - 20:20 2.58 DRILL P 20:20 - 21:50 1.50 DRILL P 21:50 - 00:00 2.17 DRILL P 9/11/2005 00:00 - 01:20 1.33 DRILL P 01:20 - 01:45 0.42 DRILL P 01:45 - 02:20 0.58 DRILL P 02:20 - 03:00 0.67 DRILL P 03:00 - 07:00 4.00 DRILL P 07:00 - 08:45 1.75 DRILL P 08:45 - 10:30 1.75 DRILL P 10:30 - 13:00 I 2.501 DRILL I P 13:00 - 13:45 I 0.751 DRILL I P 13:45 - 14:00 0.25 DRILL P 14:00 - 15:30 1.50 DRILL P 15:30 - 17:30 I 2.001 DRILL I P Spud Date: Start: 9/2/2005 End: Rig Release: 9/15/2005 Rig Number: N1 Phase Description of Operations PRODt -Begin mud swap. - Sticky off bottom (10k overpull) PROD1 Wiper trip to window. PROD1 Drill ahead to 13,070' MD. - 45L, orient as required. - 2.5/2.56 bpm, 3300 - 3500 psi - 2900 psi free spin. - ROP at 100 fph. - 13k Ct wt. PROD1 Wiper to window. PRODi Drill ahead to 13,190' MD. -90L, orient as required. - 2.6/2.6 bpm, 3300 - 3500 psi - 2900 psi free spin. - ROP at 100 fph. - 10k Ct wt. PROD1 Wiper to 10200'. PRODi RIH to 11660' PROD1 Log tie-in. Correction = +18.5'. PROD1 Completion of wiper trip. PROD1 Drill ahead to 13,356' MD. -80R, orient as required. - 2.6/2.6 bpm, 3070 - 3500 psi - 2900 psi free spin. - ROP at 100 fph. - 13k Ct wt. PROD1 Wiper trip to window. PRODi Drill ahead to 13,400' MD - 110R, orient as required. - 2.5/2.6 bpm, 3070 - 3500 psi - 2800 psi free spin. - ROP at 100 fph. - 6-13k Ct wt. PROD1 Drill ahead to 13,420' MD - 110R, orient as required. - 2.5/2.6 bpm, 3070 - 3500 psi - 2800 psi free spin. - Difficulty keeping it drilling. - Weight stacking out (-4k CT wt). Short wipers as needed. PROD1 Drill ahead to 13,443' MD. - 110R, orient as required. - 2.5/2.6 bpm, 3400 psi - 2800 psi free spin. - ROP at 10-70 fph, in spurts. -Weight improved. PROD1 Orient to 45R. PROD1 Drill ahead to 13,492' MD. - 45R, orient as required. - 2.5/2.6 bpm, 3400 psi - 2800 psi free spin. - ROP at 10-70 fph, in spurts. - Hit large shale at 13,400' MD, still in it. PROD1 Wiper trip to 10,200' MD. Printed: 9/19/2005 838:09 AM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/15/2005 Rig Name: NORDIC 1 Rig Number: N1 { Date I From - To Hours Task Code', NPT Phase Description of Operations 9/11/2005 17:30 - 18:00 0.50 DRILL P PROD1 Tie in. Correct + 15' MD. 18:00 - 19:00 1.00 DRILL P PROD1 RIH 19:00 - 23:30 4.50 DRILL P PROD1 Drill ahead to 13544 ' MD. 23:30 - 00:00 0.50 DRILL P 9/12/2005 00:00 - 02:30 2.50 DRILL P 02:30 - 03:00 0.50 DRILL P 03:00 - 03:50 0.83 DRILL P 03:50 - 04:10 0.33 DRILL P 04:10 - 05:00 0.83 DRILL P 05:00 - 07:45 2.75 DRILL P 07:45 - 08:30 0.75 DRILL P 08:30 - 10:45 2.25 CASE P 10:45 - 16:30 I 5.751 CASE I P 16:30 - 18:30 1 2.001 CASE i P 18:30 - 19:00 0.50 CASE P 19:00 - 21:30 2.50 CEMT P 21:30 - 22:00 0.50 CEMT P 22:00 - 23:30 1.50 CEMT P 23:30 - 00:00 0.50 CEMT P 9/13/2005 00:00 - 01:40 1.67 CEMT 01:40 - 02:30 0.83 CEMT - 101 R, orient as required. - 2.8/2.8 bpm, 3500 psi - 3100 psi free spin. - ROP at 5-30 fph, in spurts. PROD1 Wiper to 13080. PROD1 Drill ahead to 13573 ' MD. - 85R, orient as required. - 2.4/2.5 bpm, 3500 psi - 3100 psi free spin. - ROP at 5-30 fph, in spurts. PROD1 Wiper to 13000. Discussed drilling condition with Anch. Geo. Called TD. PROD1 Continued Wiper to window PROD1 Log tie-in. Correction = +10.5 PRODi Continue wiper to TD. Bauble at 12290. Pull back thru OK. Continue to RIH. Bobble at 13450'. Tag TD at 13,576. Spot liner running pill. PROD1 POH for liner. PROD1 LD BHA. PROD1 Rehead. Pull tesUpressure test. Pump volume dart. - Dart hit 5 bbls early. Will try again. Hit at 51.4 bbls. PROD1 PJSM. Pick up liner as per tally. - Change out at 12:00 hrs. PJSM with new crew. - Fill pipe half way through. PROD1 RIH with liner. - SO 20k, PU 50k at 11,550' MD. T - Tag TD. -Up WT 47K PROD1 UP to ball drop position. Drop ball and launch with 900 psi. RIH Circulate ball to seat 2.2 bpm at 2800 psi. 7 bpm ~ 1850 psi. Balt on seat at 45.9 bbp. Shear at 4360 psi. PU 41 K PROD1 Swap well to KCL.2.58 bpm @ 2910 psi. Mix Bio pill. PROD1 PJSM PRODi Batch mix cement. Pump 2 bbl H2O. PT lines to 4000 psi. OK Pump 32.4 bbl at 2.6 bpm ~ 1450 -1850 psi. Clear line to inner reel valve. Load dart and launch dart with 800 psi. Displace with 30 bbl bio followed by 2°I° KCL. Displace to shear LWP at 51.8 bbl with 2900 psi. Bump plug at 74.4 bbl (calculated 75.2 bbl). Floats held. Cement in place 23:20 hrs. PRODi POH filling voidage PROD1 POH PROD1 LD liner running tools Printed: 9/19/2005 8:38:09 AM • BP EXPLORATION Operations Summary Report Page 9 of 10 Legal Well Common W Event Nam Contractor Rig Name: Date , Name: 0 ell Name: 0 e: Name: From - To ~ 2-17 2-17 REENTE NORDIC NORDIC Hours ' R+COM CALIS 1 Task PLET TA Code I E NPT Start Rig Rig i Phase Spud Date: : 9/2/2005 End: Release: 9/15/2005 Number: N1 Description of Operations 9/13/2005 02:30 - 03:45 1.25 EVAL LOWERI Prep floor. Program logging tools. MU logging /cleanout BHA 03:45 - 04:00 0.25 EVAL LOWERI PJSM for picking up logging tools. 04:00 - 04:45 0.75 EVAL LOWERI PU BHA for cleanout/logging run. 04:45 - 05:30 0.75 EVAL N WAIT LOWERI Leak in Baker disconnect wait on replacement. - Baker retested disconnect at shop to 4000 psi, test ok. 05:30 - 08:30 3.00 EVAL P LOWERI Continue RIH with CSH (110 joints total, including the 2 jts below logging tools). - PJSM with day tour. 08:30 - 09:30 1.00 EVAL P LOW ER1 I RIH with logging assy. i -Cement at 600 psi at 06:30 am. 09:30 - 12:00 2.50 EVAL P LOWERI Log down from 9500' at 30 fpm. - Minimal cement returns. - Cement at 2000 psi compressive strength at 11:00 am. 12:00 - 15:00 3.00 EVAL P LOWERI Log up 60 fpm to 9300'. POH to Hydrill Circulate to clean out returns. 15:00- 17:00 2.00 EVAL P LOWERI Stand back CSH. 17:00 - 20:00 3.00 PERFO P LOW ER1 RU for jetting stack. Jet stack. Lots of cement across shakers. Several runs to clean stack out. RD from jetting stack. 20:00 - 20:50 0.83 PERFO P LOWERI Liner lap test: Call SLB tab: cement sample at 3000 psi compressive strength. Tried 3 times. Check and double blocked all lines. No pressure held on IA. IA holding steady @ 60 psi +/-5 psi. ~ All tests failed. Bleed back IA: gas returns =possible compression of gas in IA resulting in production packer leak pressure not showing. 20:50 - 21:50 1.00 PERFO P LOWERI Call out Hot Oil to pump up IA to 1000 psi. Safety meeting for loading pert guns into pipe shed. Load pert guns in pipe shed while waiting on town's analysis of CNL log and Little Red. 21:50 - 22:40 0.83 PERFO P LOWERI Little Red on loc. RU on IA. Pump 10 bbl of diesel, bringing IA up to 1000 psi. RD Little Red. 22:40 - 11:20 12.67 PERFO P LOWERI RU for liner lap test. Liner lap test: Shut-in pressure: 2000 psi. IA: 941 psi. After 15 mins. shut-in pressue: 1480 psi. IA: 918 psi. Test Failed. 11:20 - 12:00 0.67 PERFO P LOWERI RU SLB perforaters for RIH. 9/14/2005 00:00 - 00:20 0.33 PERFO P LOWERI Safety meeting with SLB perforators. Main topics: pinch points, well control. 00:20 - 03:00 2.67 PERFO P LOWERI PU perf guns. 03:00 -04:15 1.25 PERFO P LOWERI PU CSH. (40 stands). 04:15 - 06:20 2.08 PERFO P LOWERi RIH tag PBTD and correct. 06:20 - 07:20 1.00 PERFO P LOWERI Circulate 5/8" steel ball to firing head. Ball on seat at 50.4 bbls Fire guns at 2850 psi with 51.6 bbl pumped. 07:20 - 09:45 2.42 PERFO P LOWERI POH 09:45 - 11:30 1.75 PERFO P LOWERI Stand back 40 stands of 1-1/4" CSH. Printed: 9(19/2005 8:38:09 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 02-17 Common Well Name: 02-17 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date 9/14/2005 9/15/2005 From - To Hours 11:30 - 12:00 12:00 - 15:00 15:00 - 16:00 16:00 - 16:45 16:45 - 19:30 19:30 - 20:15 Task I Code ~ NPT 0.50 PERFO P 3.00 PERFO P 1.00 PERFO P 0.75 CASE P 2.75 CASE P 0.75 CASE P 20:15 - 22:40 I 2.421 CASE I P 22:40 - 23:40 I 1.001 W HSUR I P 23:40 - 23:50 23:50 - 00:00 00:00 - 00:10 00:10 - 01:30 0.17 RIGD P 0.17 RIGD P 0.17 WHSUR P 1.33 DEMOB P Spud Date: Start: 9/2/2005 fnd: Rig Release: 9/15/2005 Rig Number: N1 Page 10 of 10 Phase Description of Operations LOWERI PJSM laying down spent guns. LOWERI Lay down spent guns. All guns fired. LOWERI Clear floor and loadout spent guns. RUNPRD MU liner top packer and running tool assembly. RUNPRD RIH. Find liner top. Drop ball & pump at 0.5 bpm until it seats. Sting back into liner top. PU 8'. Pressure up 2000 psi. SO wt to pack-off element. PU to PU wt (40K Ib) to ensure lock rings holding element. Pressure up back-side. RUNPRD Pressure test LTP. Shut-in: 2000 psi. After 30 min: 1930 psi. LTP test called good. RUNPRD Shear off LTP at 3570 psi. POOH with LTP running tool. LD BHA. POST PU nozzle for freeze protect. RIH to 2500'. Freeze protect with 60/40 McOH. 25 bbl, waiting at 500' for McOH to come across shakers. 1.05 bpm/115 ft/min: rate/speed. POST Safety meeting with SLB N2 crew. POST Blow down coil with N2 @ 1500 psi. POST Blowdown reel with N2 @ 1500 psi. POST Setback injector. ND stack. Install tree cap. Rig down. Rig released at: 01:30 hrs on 09/15/2005. Printed: 9/19!2005 8:38:09 AM Halliburton Sperry-Sun North Slope Alaska BPXA 02-178 Job No. AKMW3922698, Surveyed: 12 September, 2005 Survey Report 76 September, 2005 Your Ref: API 500292045302 Surface Coordinates: 5950985.81 N, 687518.43E (70° 16' 15.3653" N, 148° 28' 59.9671" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 61.61ft above Mean Sea Leve( DRILLING SERVCCES A Halliburton Company DEFII~9TI~•' Survey Ref: svy4668 C7 • Halliburton Sperry-Sun Survey Report for 02-176 Your Ref; AP1500292045302 Job No. AKMW3922698, Surveyed: 12 September, 2005 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) (°/100ft) 11598.78 88.610 26.500 8797.93 8859.54 5199.75 N 1426.63 W 5956148.40 N 685962.69E 968.01 Tie On Point 11605.00 88.630 26.820 8798.08 8859.69 5205.30 N 1423.84 W 5956154.02 N 685965.34E 5.153 964.75 Window Point 11659.85 91.410 12.200 8798.06 8859.67 5256.86 N 1405.57 W 5956206.02 N 685982.32E 27.130 942.06 11698.01 88.830 2.020 8797.98 8859.59 5294.67 N 1400.86 W 5956243.94 N 685986.09E 27.518 934.07 11728.07 89.120 348.510 8798.52 8860.13 5324.55 N 1403.33 W 5956273.75 N 685982.87E 44.947 933.93 11760.03 92.640 339.190 8798.03 8859.64 5355.21 N 1412.21 W 5956304.17 N 685973.23E 31.164 940.10 11790.66 90.440 332.340 8797.21 8858.82 5383.11 N 1424.77 W 5956331.75 N 685959.98E 23.480 950.18 11820.19 89.740 328.640 8797.16 8858.77 5408.81 N 1439.31 W 5956357.08 N 685944.80E 12.752 962.43 11850.65 91.930 324.600 8796.72 8858.33 5434.23 N 1456.06 W 5956382.08 N 685927.42E 15.085 976.90 11880.92 94.310 324.950 8795.07 8856.68 5458.92 N 1473.50 W 5956406.33 N 685909.38E 7.947 992.11 11910.30 94.040 327.590 8792.93 8854.54 5483.29 N 1489.77 W 5956430.28 N 685892.51E 9.009 1006.20 11940.15 90.180 323.190 8791.83 8853.44 5507.83 N 1506.70 W 5956454.39 N 685874.97E 19.599 1020.93 11970.50 90.970 316.690 8791.53 8853.14 5531.04 N 1526.22 W 5956477.11 N 685854.87E 21.573 1038.35 12001.83 90.700 312.300 8791.07 8852.68 5552.99 N 1548.56 W 5956498.50 N 685831.99E 14.037 1058.70 12031.72 91.580 307.020 8790.47 8852.08 5572.06 N 1571.56 W 5956516.99 N 685808.53E 17.905 1079.94 12061.60 89.210 302.980 8790.27 8851.88 5589.19 N 1596.03 W 5956533.50 N 685783.64E 15.674 1102.83 12092.20 87.630 297.710 8791.11 8852.72 5604.64 N 1622.42 W 5956548.29 N 685756.87E 17.973 1127.77 12124.49 87.980 291.550 8792.35 8853.96 5618.08 N 1651.74 W 5956560.99 N 685727.23E 19.094 1155.80 12158.80 90.970 283.640 8792.67 8854.28 5628.44 N 1684.41 W 5956570.54 N 685694.31E 24.643 1187.45 12190.85 91.760 279.600 8791.90 8853.51 5634.90 N 1715.79 W 5956576.21 N 685662.78E 12.840 1218.14 12220.81 92.280 274.850 8790.84 8852.45 5638.66 N 1745.48 W 5956579.23 N 685633.00E 15.939 1247.40 12253.31 94.040 272.750 8789.05 8850.66 5640.81 N 1777.86 W 5956580.57 N 685600.58E 8.423 1279.46 12283.58 91.580 275.730 8787.57 8849.18 5643.05 N 1808.00 W 5956582.06 N 685570.39E 12.756 1309.30 12314.30 89.300 279.780 8787.33 8848.94 5647.19 N 1838.43 W 5956585.44 N 685539.87E 15.128 1339.25 12344.27 89.740 284.870 8787.58 8849.19 5653.59 N 1867.70 W 5956591.11 N 685510.45E 17.046 1367.85 12376.18 89.380 289.270 8787.83 8849.44 5662.95 N 1898.20 W 5956599.71 N 685479.73E 13.834 1397.41 12407.12 87.890 292.080 8788.57 8850.18 5673.87 N 1927.13 W 5956609.90 N 685450.53E 10.277 1425.29 12441.25 87.710 288.040 8789.88 8851.49 5685.57 N 1959.16 W 5956620.80 N 685418.22E 11.840 1456.18 12472.04 89.300 286.460 8790.68 8852.29 5694.69 N 1988.55 W 5956629.19 N 685388.61E 7.279 1484.66 12503.02 89.030 283.120 8791.13 8852.74 5702.60 N 2018.50 W 5956636.35 N 685358.47E 10.815 1513.81 12535.22 89.210 280.830 8791.63 8853.24 5709.28 N 2049.99 W 5956642.24 N 685326.82E 7.133 1544.60 12570.45 90.000 275.030 8791.87 8853.48 5714.14 N 2084.87 W 5956646.23 N 685291.84E 16.615 1578.92 12599.54 90.180 272.750 8791.82 8853.43 5716.11 N 2113.89 W 5956647.48 N 685262.78E 7.862 1607.66 12634.34 90.440 269.050 8791.64 8853.25 5716.66 N 2148.68 W 5956647.16 N 685227.98E 10.658 1642.27 12665.31 89.380 266.070 8791.68 8853.29 5715.34 N 2179.62 W 5956645.07 N 685197.09E 10.213 1673.20 • 16 September, 2005 - 13:21 Page 2 of 4 Dril/Quest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 02-176 Your Ref: API 500292045302 Job No. AKMW3922698, Surveyed: 12 September, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordi nates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 12700.39 89.300 264.130 8792.09 8853.70 5712.34 N 2214.57 W 5956641.20 N 685162.23 E 12730.15 88.680 262.900 8792.61 8854.22 5708.98 N 2244.13 W 5956637.11 N 685132.75 E 12774.17 88.590 259.910 8793.66 8855.27 5702.41 N 2287.64 W 5956629.45 N 685089.42 E 12802.40 89.740 255.870 8794.07 8855.68 5696.48 N 2315.23 W 5956622.84 N 685061.99 E 12840.48 87.710 253.590 8794.92 8856.53 5686.46 N 2351.95 W 5956611.91 N 685025.53 E 12876.50 86.750 252.530 8796.66 8858.27 5675.98 N 2386.37 W 5956600.57 N 684991.38 E 12908.92 88.150 247.780 8798.10 8859.71 5664.99 N 2416.83 W 5956588.82 N 684961.21 E 12940.16 91.760 246.200 8798.13 8859.74 5652.78 N 2445.57 W 5956575.90 N 684932.77 E 12972.85 92.020 242.860 8797.05 8858.66 5638.73 N 2475.07 W 5956561.12 N 684903.64 E 13006.79 92.110 237.410 8795.83 8857.44 5621.84 N 2504.47 W 5956543.51 N 684874.67 E 13040.29 90.530 239.000 8795.06 8856.67 5604.20 N 2532.93 W 5956525.16 N 684846.65 E 13072.74 89.120 230.210 8795.15 8856.76 5585.42 N 2559.36 W 5956505.73 N 684820.70 E 13105.80 90.610 230.030 8795.23 8856.84 5564.23 N 2584.73 W 5956483.91 N 684795.87 E 13137.34 92.020 230.730 8794.51 8856.12 5544.12 N 2609.02 W 5956463.20 N 684772.09 E 13169.03 92.900 228.450 8793.15 8854.76 5523.60 N 2633.12 W 5956442.09 N 684748.50 E 13200.88 91.580 230.560 8791.90 8853.51 5502.93 N 2657.32 W 5956420.83 N 684724.83 E 13230.63 88.940 235.660 8791.77 8853.38 5485.08 N 2681.11 W 5956402.39 N 684701.49 E 13262.86 89.210 239.170 8792.29 8853.90 5467.73 N 2708.25 W 5956384.37 N 684674.79 E 13292.97 90.880 238.290 8792.26 8853.87 5452.10 N 2733.99 W 5956368.10 N 684649.45 E 13326.71 94.390 242.860 8790.71 8852.32 5435.55 N 2763.33 W 5956350.82 N 684620.53 E 13358.65 95.360 247.260 8788.00 8849.61 5422.13 N 2792.18 W 5956336.69 N 684592.02 E 13391.28 94.920 247.430 8785.07 8846.68 5409.61 N 2822.17 W 5956323.43 N 684562.35 E 13423.71 91.050 252.530 8783.38 8844.99 5398.53 N 2852.59 W 5956311.60 N 684532.22 E 13457.90 92.110 255.870 8782.44 8844.05 5389.23 N 2885.47 W 5956301.47 N 684499.58 E 13493.05 95.360 255.520 8780.15 8841.76 5380.56 N 2919.45 W 5956291.97 N 684465.83 E 13525.71 95.180 260.620 8777.15 8838.76 5373.84 N 2951.26 W 5956284.45 N 684434.20 E 13549.20 94.750 263.080 8775.12 8836.73 5370.53 N 2974.42 W 5956280.56 N 684411.12 E 13576.00 94.750 263.080 8772.90 8834.51 5367.31 N 3000.94 W 5956276.68 N 684384.70 E All data is in Feet (US Survey) unless ot herwise sta ted. Directions and coordinates are relative to True North. Vertical dept hs are relativ e to Well Refe rence . Northings and Eastings are relative to Well Reference . Global North ings and Eas tings are relati ve to NAD2 7 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 1 00 feet (US Survey). Vertical Sect ion is from Well Reference and calculated along an Azimuth of 265.000° (True). Based upon Minimum Cu rvature type calculations, at a Measured Depth of 13576.OOft., The Bottom Hole Displacement is 6149. 28ft., in the Direction of 33 0.790° (True). Dogleg Vertical Rate (°/100ft) 5.535 4.628 6.794 14.878 8.015 3.968 15.260 12.614 10.243 16.050 6.690 27.433 4.540 4.991 7.706 7.810 19.302 10.921 6.269 17.066 14.058 1.445 19.722 10.245 9.299 15.559 10.593 0.000 Section Comment 1708.28 1738.02 1781.94 1809.94 1847.40 1882.60 1913.89 1943.60 1974.20 2004.96 2034.86 2062.82 2089.94 2115.89 2141.69 2167.60 2192.85 2221.40 2248.40 2279.08 2308.99 2339.95 2371.22 2404.78 2439.39 2471.67 2495.03 2521.73 Projected Survey BPXA r • 16 September, 2005 - 13:21 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Reporf for 02-17B Your Ref: API 500292045302 Job No. AKMW3922698, Surveyed: 12 September, 2005 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11598.78 8859.54 5199.75 N 1426.63 W Tie On Point 11605.00 8859.69 5205.30 N 1423.84 W Window Point 13576.00 8834.51 5367.31 N 3000.94 W Projected Survey Survey tool program for 02-17B From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 9597.61 8235.82 BP Conventional Gyro -BOSS-GYRO (02-17) 9597.61 8235.82 13576.00 8834.51 MWD Magnetic (02-17A) BPXA • C7 16 September, 2005 - 13:21 Page 4 of 4 DrillQuest 3.03.06.008 TREE _. GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 62' BF. ELEV = KOP = 11606' Max Angle = 94 @ 13570' Datum MD = 11400' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-i 2690' Minimum ID = 2.441" @ 12464' LSL XO to 2 7/8" 6.46 #Ift L••80 liner 19-5/8" X 4-112" TNV HBBRT PKR I 9504' ~-{4-1/2" HES X NIP, ID= 3.813" ITOPOF4-1/2' LWER H 9525 /2' TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9526' TOP OF C6NENT I 9464' 9-5/8' CSG, 47#, SOO-95, ID = 8.681" 9672' PERFORATION SUMMARY REF LOG: CNL on 9/13/05 ANGLE AT TOP PERF: 90° @ 12249' Note: Refer to Roduction DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 2 6 12270'-12560' open 09/14/05 2 6 12630'-12850' open 09114/05 2 6 12950'-13370' open 09/14/05 2 6 13470'-13490' aQen C~3/14!05 O ~ -17 B S NOTES: HORIZ. WELL - 70° @ 10391' ***T X IA X OA COMM. OPERATING LIMITS: MAX CTD Sidetrack ~qp = 2500 PSI, MAX OAP = 2500 PSI (01/10/04 WAVER)*** ~4-1/2" CAM BAL-O SSSV NIP, ID = 3.813" ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3993 3899 39 MMGM DMY RK 0 04/26/05 2 7479 6568 39 MMGM DMY RK 0 04/26/05 3 9401 8079 37 MMGM DMY RK 0 04/26/05 9527' ~s-1n" wLEG ~ ELMD TT NOT LOGGED 9525 9-5/8' BAKER ZXP PKR W/6.5' PBR W/7.5" W/7" X 5-1/2" XO, 5-1/2" X 4-1/2' XO M~LOUT WINDOW 9672' - 971T 10198' Liner top packer 10205' Top of 3-3/16" Liner 10200' Top of Cement 10223' 3.5" XN np 3.813" ID 12464' 1~3-3/16 x 2-7l8 X-over 3-3116 x 2-7/8" crri'ed and perfed ~--~ 13570' Mechanical Whipstock @ 11606' 11750' 4-1/2" HES EZSV CIBP (01/04/03) 12715' FISH - 4-1/2" LOWER ASSY 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 12719' OF 4 BLADED SPINNER 12720' 1" DIAMETER LS FOLDED -3" 6S OPEN DATE REV BY COMMENTS DATE REV BY COMMENTS 1980 ORIGINAL COMPLETION 01/10/04 JRGKK WANERSAFETY NOTE REV. 10/05/96 SIDETRACK COM PLETION 04/20!04 JAF/KAK SET CIBP 01/31/02 RNlTP CORRECTIONS 04/27/05 RWLlTLH GLV GO 01/04/03 KSB/KK ADPERF;SETCIBP 03/15/03 PWE/TLH ADPERF 08/29/03 KC/TLH WAVER SAFETY NOTE PRUDHOE BAY UNfr WELL: 02-17A PERMfr No: 1961450 API No: 50-029-20453-01 SEC 36, T11 N, R14E, 895.42' FEL & 4554.81' FNL BP Exploration (Alaska) • • 19-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2-17B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,.598.78' MD Window /Kickoff Survey: 11,605.00' MD (if applicable) Projected Survey: 13,576.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 (r' Date l9 ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~ ~.~3~ 2m~i ./f{~~p, (/`®"m' /.tea Y~ I i ~ j' '~ ~ 1 11 ~ ~ ~ ~~ ~ ~ ~ '~' ~ ~, ~ ~~` ~ '®" f FRANK H. MURKOWSKI, GOVERNOR ~/~7~ OIIl ~ ~ ~ 333 W. T" AVENUE, SUITE 100 COI~TSERQA'I`IOI~T COMbIISSIOI~T ~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe 02-17B BP Exploration (Alaska) Inc. Permit No: 205-130 Surface Location: 213' FNL, 787' FWL, SEC. 36, T11N, R14E, UM Bottomhole Location: 5154 FSL, 2244' FEL, SEC. 26, T 11 N, R 14E, UM Dear Mr. Stagg: 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 to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this~day of August, 2005 cc: Department of Fish 8a Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~;.ruGi~ ~jt~ j~~s STATE OF ALASKA ALASKA AND GAS CONSERVATION CO SSIO~.; PERMIT TO DRILL 20 AAC 25.005 ~~~ =~ 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Stratigraphic Test ^ Service ~ Dev~tppd~aentOil ' 1] Multiple Zone 'ffei~etb~i'nerit Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 02-17B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13650 TVD 8768ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 213' FNL 787' FWL SEC 36 T11N R14E UM 7. Property Designation: ADL 028308 Pool , , . , , , Top of Productive Horizon: 3469' FSL, 851' FEL, SEC. 26, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: September 4, 2005 ~ Total Depth: 5154' FSL, 2244' FEL, SEC. 26, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 32,850' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 687518 y- 5950986 Zone- ASP4 10. KB Elevation 1 (Height above GL): 61.61 feet 5. Distance to Nearest Well within Pool 1,100' 16. Deviated Wells: Kickoff Depth: 11650 feet Maximum Hole Angle: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 Surface: 2370 ~ 18: asing;Program: Size Specifications Setting Depth To Bottom Quantity of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" 3-3/16° X za/a• 6.2# / 6.16# L-80 STL 3450' 10200' 8694' 13650' 8768' 150 sx Class 'G' ~ 19. PRESENT W ELL CONDITION SUMM ARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 12719 Total Depth TVD (ft): 8859 Plugs (measured): 10550 & 11750 Effective Depth MD (ft): 10550 Effective Depth TVD (ft): 8892 Junk (measured): 12715 Casing Length Size Cement Volume MD TVD tr trl ndu t r 110' 20" 300 sx Permafrost 110' 110' 2690' 13-3/8" 2300 sx Fondu, 400 sx Permafrost 2690' 2690' 9672' 9-5/8" 1400 sx Class 'G' 9672' 8296' Pr ti n i 3180' 4-1/2" 395 sx Class 'G' 9539' - 12719' 8189' - 8859' Perforation Depth MD (ft): Be~oW sqZ / ~SOc 10330' -12625' Perforation Depth TVD (ft): 8837' - 8858' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Stagg, 564-4694 Printed Name Ted Stagg Title CT Drilling Engineer Prepared By Name/Number: Si nature ~ Phone 564-4694 Date ~~ds Terrie Hubble, 564-4628 Commission Use Only ' Permit To Drill Number: 20 ~ API Number: 50- 029-20453-02-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes No Mud Log Required ^ Yes No d ogen Sulfide Measures ~'1'es ^ No Directional Survey Required Yes ^ No Other: ~ -E ~~~ 1~3 ~7 t 3~ ~ ~ ~~ ~ . A rove ~ ~ "° ~ ~ " " ~ THE COMMISSION Date ~~( ~~ Form 10-401 Revise 06/2004 ~ubmit j4i Duplicate BP Prudhoe Bay D5 02-17B CTD Sidetrack CTD Sidetrack Summary Rig Work: 1. MIRU Nordic 1 and test BOPE to 250 psi low and 3500 psi high. ~ 2. Mi113.8" window at 11,650' MD (8799'ss) and 10' of Zone 2. Swap the well to Flo-Pro. 3. Drill approx. 2,000 ft of 4.125" OH. 4. Run 3 3/16" x 2 7/8" solid Iiner le in~ TOL at 10,200' MD (8694'ss). ~ 5. Cement liner with a minimum of 31 B is to place top of cement at 10,200' MD (8694'ss). -- 6. Cleanout liner and MCNL/GR/ ~ L, log 7. Test liner lap to 2000 psi. 8. Perforate liner per asset instructions (expect approx. 800 ft of perfs) 9. Freeze protect well, RDMO Mud Program: • Well kill: 8.5 ppg i e • Milling/drilling• 8. ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 3 3/16" x 2 7/8" 1 cemented liner • A minimum of 31 bls 15.8 ppg cement will be used for liner cementing. Casing/Liner nformation 13 3/8", N-80, 72#, Burst 5380 psi; collapse 2670 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 4.5", L-80, 1.2.6#, Burst 6350 ;collapse 7780 psi Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. ~ The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 93 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 32,850 ft. • Distance to nearest well within pool -1100 ft. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. • A cased hole CNL/GR/CCL log will be run. Hazards ~ • The maximum recorded H2S level on DS 02 i 100 pm (02-29 on 10/23/92). ~ • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 3250 psi at 8800'ss (7.1 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2370 psi. ~ TREE _~ GRAY GEN 2 WELLHEAD = GRAY P.CTUATOR= AXQSON KB. ELEV = 62' BF. ELEV = KOP = Max Angle = 3098' 94 @ 10783' Datum MD = 11400' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2690' Minimum ID = 3.813" @ 2224' 4-1 /2" Camco Bal-O SSSV Nipple O 2 ~ ~ 7 B ~ S NOTES: HORIZ. W ELL - 70° @ 10391' ***T X IA X OA COMM. OPERATING LIMITS: MAX Proposed CTD Sidetrack IAp = 2500 PSI, MAX OAP = 2500 PSI (01/10/04 WAVER)*** 2224' 4-1/2" CAM BAL-O SSSV NIP, ID = 3.813" 0 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3993 3899 39 MMGM DMY RK 0 04/26!05 2 7479 6568 39 MMGM DMY RK 0 04/26/05 3 9401 8079 37 MMGM DMY RK 0 04/26/05 9470' -I9-518" X 4-112" TIW HBBP-T PKR 950 4-1/2" HES X NiP, ID = 3.813" 114-1 /2" OF4-1/2" LINER bpf, ID = 3.958" TOP OF CEMENT 9-5/8" CSG, 47#, SOO-95, ID = 8.681" 9525' 9527' - j 5-1 /2" W LEG 9526' ~ ELMD TT NOT LOGGED 9525' 9-5/8" BAKER ZXP PKR W/6.5' PBR W/7.5" ID W/7" X 5-1/2" XO, 5-1/2" X 4-1/2" XO ' 9464 MILLOUT WINDOW 9672' - 9717' PERFORATION SUMMARY REF LOG: BHCS ON 09/21/96 ANGLE AT TOP PERF: 59° @ 10330' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10330 - 10342 isolated proposed 3-2/8" 6 10400 - 10450 isolated proposed 2-3/4" 4 11185 - 11400 isolated proposed 2-3/4" 4 11445 - 11550 isolated proposed 2-3/4" 4 11800 - 11940 isolated proposed 2-3/4" 4 11980 - 12105 isolated proposed 2-3/4" 4 12284 - 12402 isolated proposed 2-3/4" 4 12505 - 12625 isolated proposed `4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ I i u I' 10200' Top of 3-3/16" Liner 10200' Top of Cement 10200' 3.5" XN nip 3.813" ID ~ 11900' ~-~ 3-3/16 x 2-7/8 X-over 3-3/16 x 2-7/8" cmPed and perfed 13650' Mechanical Hollow Whipstock 11650' 11750' 4-1/2" HES EZSV CIBP(01/04/03) 12719' 12715' FISH-4-1/2"LOWERASSY ADED SPINNER 12720' OF 4 BL 1" DIAMETER IS FOLDED -3" IS OPEN DATE REV BY COMMEMS DATE REV BY COMMENTS 1980 ORIGINAL COMPLETION 01/10/04 JRGKK WANERSAFETY NOTE REV. 10/05/96 SIDETRACKCOMPLEf10N 04/20/04 JAF/KAK SETCIBP 01/31!02 RWTP CORRECTIONS 04/27/05 RWL/TLH GLV GO 01/04/03 KSB/KK ADPERF; SETCIBP 03/15/03 PWEITLH ADPERF ~ PRUDHOE BAY UNfT WELL: 02-17A PERMff No: 1961450 API No: 50-029-20453-01 SEC 36, T11 N, R14E, 895.42' FEL & 4554.81' FNL BP Exploration (Alaska) • • BP Amoco ~ ~,oz;,. ., &~~. .,,,~ BAiC#R ~,,, " ,"w".'" a' ~~ ,,...,. 1"1'L(1 ~~ ..,.o..._ .,.... ...M AEFE~ s„a ,_ ~. _ ~.. .. a, ,_. ,ti ,~ .~.._ ... .,._ .. .~...,., , ......, _ m.. ,., ,y. ~~ „ ,., ~ .,..m..~,.. .~,~ ~~.~ --~ .. ~_, .,..,.,,..o... ,o. ~„aFw. ~"~ Po~ .~..H .............«,,..ou a ~, : ~. ..u,,,.. dam ~,s~ mss, P~~ oz's' ~~_- .n..:..:~.a 8 ~ '. + AT_ .»,...,:n.o.. c~.~. .....:, ,:....w ,. .~....,......o. ,o ~ __ e / AM • • BP-GDB Baker Hughes INTEQ Planning Report Company: BP Amoco Date: 8/11/2005 Time: 11:11:58 Pa£_e: 1 Field: Prudhoe Bay Co-ordinate(N6;) Rcf crcnec: W ell: 02-17, True North Site: PB DS 02 Vertical (TVD) Refer ence: 02 -17A 61.6 Well: 02-17 Section (VS) Reference: W ell (O.OON,O.OOE,265.OOAzi) Wellpath: PIan11, 02-176 Survey Calculation Method: Mi nimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 02 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5948800.37 ft Latitude: 70 15 53.847 N From: Map Easting: 687638.44 ft Longitude: 148 28 58.060 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: 02-17 Slot Name: 17 02-17 Well Position: +N/-S 2187.99 ft Northing: 5950985.93 ft Latitude: 70 16 15.366 N +E/-W -64.73 ft Easting : 687519.21 ft Longitude: 148 28 59.944 W Position Uncertainty: 0.00 ft Wellpath: PIan11, 02-17B Drilled From: 02-17A Tie-on Depth: 11598.78 ft Current Datum: 02-17A Height 61.61 ft Above System Datum: Mean Sea Level Magnetic Data: 7/21/2005 Declination: 24.94 deg Field Strength: 57610 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 31.61 0.00 0.00 265.00 Targets Map Map <-- Latitude --> <-- Longitude -> Name Description TVD +~/-S +E/-VV Northing Easting Deg ~1in Sec Deg Min Sec ~ Dip. Dir. ft ft ft ft ft 02-176 Polygon 61.61 5480.21 -3014.79 5956389.00 684368.99 70 17 9.258 N 148 30 27.774 W -Polygon 1 61.61 5503.57 -1383.61 5956453.00 685998.99 70 17 9.493 N 148 29 40.253 W -Polygon 2 61.61 5689.67 -1505.02 5956636.00 685872.99 70 17 11.323 N 148 29 43.791 W -Polygon 3 61.61 5765.43 -1735.21 5956706.00 685640.99 70 17 12.067 N 148 29 50.498 W -Polygon 4 61.61 5785.83 -2031.81 5956719.00 685343.99 70 17 12.267 N 148 29 59.139 W -Polygon 5 61.61 5721.23 -2570.62 5956641.00 684806.99 70 17 11.630 N 148 30 14.837 W -Polygon 6 61.61 5578.15 -2810.28 5956492.00 684570.99 70 17 10.222 N 148 30 21.817 W -Polygon 7 61.61 5431.39 -3063.03 5956339.00 684321.99 70 17 8.778 N 148 30 29.179 W -Polygon 8 61.61 5264.46 -3028.17 5956173.00 684360.99 70 17 7.136 N 148 30 28.162 W -Polygon 9 61.61 5312.76 -2838.90 5956226.00 684548.99 70 17 7.612 N 148 30 22.648 W -Polygon 10 61.61 5514.96 -2562.76 5956435.00 684819.99 70 17 9.601 N 148 30 14.605 W -Polygon 11 61.61 5535.10 -2287.16 5956462.00 685094.99 70 17 9.800 N 148 30 6.576 W -Polygon 12 61.61 5569.80 -1753.09 5956510.00 685627.99 70 17 10.143 N 148 29 51.018 W -Polygon 13 61.61 5395.03 -1604.39 5956339.00 685780.99 70 17 8.425 N 148 29 46.684 W 02-17B Fault 61.61 5425.29 -2376.93 5956350.00 685007.99 70 17 8.720 N 148 30 9.191 W -Polygon 1 61.61 5425.29 -2376.93 5956350.00 685007.99 70 17 8.720 N 148 30 9.191 W -Polygon 2 61.61 5228.02 -2368.84 5956153.00 685020.99 70 17 6.780 N 148 30 8.953 W -Polygon 3 61.61 5048.05 -2252.28 5955976.00 685141.99 70 17 5.010 N 148 30 5.556 W -Polygon 4 61.61 4947.70 -2239.77 5955876.00 685156.99 70 17 4.024 N 148 30 5.191 W -Polygon 5 61.61 4642.04 -2057.32 5955575.00 685346.99 70 17 1.018 N 148 29 59.874 W -Polygon 6 61.61 4947.70 -2239.77 5955876.00 685156.99 70 17 4.024 N 148 30 5.191 W -Polygon 7 61.61 5048.05 -2252.28 5955976.00 685141.99 70 17 5.010 N 148 30 5.556 W -Polygon 8 61.61 5228.02 -2368.84 5956153.00 685020.99 70 17 6.780 N 148 30 8.953 W 02-17B Tgt 4.11 8831.61 5368.83 -3001.56 5956278.00 684385.00 70 17 8.163 N 148 30 27.388 W OZ-176 Tgt 3.11 8854.61 5546.44 -2622.00 5956465.00 684759.99 70 17 9.911 N 148 30 16.332 W 02-176 Tgt 1.11 8855.61 5673.30 -1851.55 5956611.00 685526.99 70 17 11.161 N 148 29 53.887 W 02-17B Tgt 2.11 8865.61 5676.89 -2236.61 5956605.00 685141.99 70 17 11.195 N 148 30 5.105 W • BP-GDB Baker Hughes INTEQ Planning Report Company: B P Amoco Da te: 8/11/2005 Time: 11:11:58 Page: 2 Lield: Prudhoe Bay Co-~trdinate(NE) Reference: W eII: 02-17, True North Site: PB DS 02 Vertical (TVD) Reference: 02-17A 61.6 N'cll: 02-17 Section (VS) Reference: W ell (O.OON,O.OOE,265.O OAzi) Wcllpath: Plan11, 02-17 B Survey Calculation Method: Mi nimum Curvature Db: Oracle Targets Map Map <-- Latit ude -> <~ Longitude -> Name Description TVD +Nl-S +);;/-W Northing Fasting Deg Min Sec Deg Min Sec Di p. Dir. ft ft ft ft ft Annotation MD TVD _. _-- - -- ft ft 11598.78 8859.54 TIP 11650.00 8860.74 KOP 11670.00 8860.95 End of 9?/100' DLS 11700.00 8859.92 4 11830.00 8854.84 End of 35?/100' DLS 12230.00 8852.90 6 12380.00 8853.63 7 12520.00 8857.53 8 12770.00 8863.26 9 12895.00 8861.82 10 13255.00 8849.80 11 13650.00 8829.32 TD Plan: Plan #11 Date Composed: 7/21/2005 Copy Lamar's Plan 11 , uses Finder survey Version: 5 Principal: Yes Tied-to: From: Definitive Path Plan Section Information A1D Incl Azim TVD +!~/-S +L/-yV DLS Build Turn fF0 "fargct ft deg deg ft ft ft deg/100ft deg/100ft deg/100 ft deg 11598.78 88.61 26.50 8859.54 5199.73 -1426.61 0.00 0.00 0.00 0.00 11631.40 88.71 28.20 8860.31 5228.70 -1411.63 5.22 0.31 5.21 86.65 11650.00 88.62 28.32 8860.74 5245.08 -1402.83 0.81 -0.48 0.65 126.88 11670.00 90.18 27.42 8860.95 5262.75 -1393.48 9.00 7.79 -4.50 330.00 11700.00 93.75 17.54 8859.92 5290.42 -1382.03 35.00 11.90 -32.94 290.00 11830.00 90.49 332.12 8854.84 5416.41 -1393.49 35.00 -2.51 -34.94 267.00 12230.00 90.03 284.12 8852.90 5656.15 -1699.07 12.00 -0.12 -12.00 269.60 12380.00 89.41 266.13 8853.63 5669.49 -1847.85 12.00 -0.41 -11.99 268.00 12520.00 87.42 282.82 8857.53 5680.36 -1986.87 12.00 -1.42 11.92 97.00 12770.00 90.01 252.92 8863.26 5671.13 -2233.79 12.00 1.04 -11.96 274.50 12895.00 91.30 267.86 8861.82 5650.32 -2356.67 12.00 1.03 11.96 85.00 13195.00 92.23 231.86 8852.26 5548.80 -2633.59 12.00 0.31 -12.00 272.00 13255.00 92.46 224.66 8849.80 5508.91 -2678.29 12.00 0.39 -12.00 272.00 13650.00 93.14 272.11 8829.32 5367.67 -3034.60 12.00 0.17 12.01 88.00 Survey MD Incl Azim SSTVD NlS F/W MapN MapF. VS DLS Toolfacc Tool ft deg deg ft ft ft ft ft ft degl100ft deg 11598.78 88.61 26.50 8797.93 5199.73 -1426.61 5956148.20 685963.57 968.00 0.00 0.00 M W D 11600.00 88.61 26.56 8797.96 5200.82 -1426.07 5956149.30 685964.09 967.36 5.22 86.65 M W D 11631.40 88.71 28.20 8798.70 5228.70 -1411.63 5956177.52 685977.83 950.55 5.22 86.65 M W D 11650.00 88.62 28.32 8799.13 5245.08 -1402.83 5956194.12 685986.22 940.35 0.81 126.88 MWD 11670.00 90.18 27.42 8799.34 5262.75 -1393.48 5956212.02 685995.13 929.50 9.00 330.00 MWD 11680.00 91.38 24.13 8799.20 5271.76 -1389.13 5956221.13 685999.25 924.38 35.00 290.00 M W D 11690.00 92.57 20.84 8798.86 5280.99 -1385.31 5956230.45 686002.84 919.77 35.00 289.96 MWD 11700.00 93.75 17.54 8798.31 5290.42 -1382.03 5956239.96 686005.88 915.68 35.00 289.84 MWD 11710.00 93.56 14.04 8797.67 5300.02 -1379.32 5956249.63 686008.36 912.14 35.00 267.00 M W D 11720.00 93.36 10.54 8797.07 5309.77 -1377.19 5956259.43 686010.24 909.17 35.00 266.78 MWD 11730.00 93.14 7.04 8796.50 5319.64 -1375.67 5956269.33 686011.51 906.79 35.00 266.57 M W D 11740.00 92.91 3.54 8795.97 5329.58 -1374.75 5956279.29 686012.19 905.01 35.00 266.37 MWD 11750.00 92.67 0.04 8795.49 5339.56 -1374.43 5956289.27 686012.25 903.83 35.00 266.18 MWD 11760.00 92.43 356.55 8795.04 5349.55 -1374.73 5956299.25 686011.70 903.26 35.00 266.01 M W D 11770.00 92.17 353.06 8794.64 5359.49 -1375.64 5956309.17 686010.55 903.29 35.00 265.86 MWD • BP-GDB Baker Hughes INTEQ Planning Report Company: BP Amoco llate: 8!11/2005 Time: 11:11:58 Page: 3 Field: Pru dhoe Bay Co-or dinate(NE) R eference: Well: 02-17, T rue N orth Site: PB DS 02 Vertical (I'VD) Reference: 02-17A 61.6 ~~'ell: 02- 17 Section (VS) Reference: Well (O.OON,O .OOE,265.OOAzi) Wellpath: Pia n11, 02-17 B Survey Calculation Method: Minimum Curvature llb: Oracle S m~ve~~ MD Inc! :azim SSTVD N/S E/VV MapN 111apE VS DLS Toolface Tool ft deg deg ft ft ft ft ft ft deg/ 100ft deg 11780. 00 91.90 349.56 8794. 28 5369.37 -1377 .15 5956319.00 686008. 80 903.93 35 .00 265.72 MWD 11790. 00 91.63 346.07 8793. 98 5379.14 -1379 .25 5956328.72 686006. 45 905.18 35 .00 265.59 MWD 11800. 00 91.35 342.58 8793. 72 5388.76 -1381 .96 5956338.27 686003. 51 907.03 35 .00 265.48 MWD 11810 .00 91.07 339.09 8793. 50 5398.21 -1385 .24 5956347.63 685999 .99 909.48 35 .00 265.39 M W D 11820 .00 90.78 335.60 8793. 34 5407.43 -1389 .09 5956356.75 685995. 91 912.51 35 .00 265.32 MWD 11830 .00 90.49 332.12 8793. 23 5416.41 -1393 .49 5956365.62 685991. 29 916.12 35 .00 265.26 M W D 11850 .00 90.47 329.72 8793. 06 5433.88 -1403 .21 5956382.84 685981. 13 924.28 12 .00 269.60 MWD 11875 .00 90.45 326.72 8792. 86 5455.13 -1416 .38 5956403.76 685967. 44 935.54 12 .00 269.58 MWD 11900. 00 90.43 323.72 8792. 67 5475.66 -1430 .64 5956423.92 685952. 68 947.96 12 .00 269.56 MWD 11925. 00 90.40 320.72 8792. 49 5495.42 -1445 .95 5956443.29 685936. 88 961.49 12 .00 269.53 M W D 11950. 00 90.38 317.72 8792. 32 5514.34 -1462 .28 5956461.80 685920. 08 976.11 12 .00 269.51 M W D 11975. 00 90.35 314.72 8792. 16 5532.39 -1479 .58 5956479.41 685902. 34 991.77 12 .00 269.49 M W D 12000. 00 90.32 311.72 8792. 01 5549.51 -1497 .79 5956496.07 685883. 71 1008.42 12 .00 269.47 MWD 12025. 00 90.29 308.72 8791. 88 5565.65 -1516 .88 5956511.73 685864. 22 1026.03 12 .00 269.45 M W D 12050. 00 90.26 305.72 8791. 75 5580.77 -1536 .79 5956526.34 685843. 95 1044.54 12 .00 269.44 MWD 12075 .00 90.23 302.72 8791. 65 5594.82 -1557 .46 5956539.88 685822. 93 1063:91 12 :00 269.42 M W D 12100 .00 90.20 299.72 8791. 55 5607.78 -1578 .84 5956552.30 685801. 24 1084.08 12 .00 .269.41 M W D 12125 .00 90.17 296.72 8791. 47 5619.60 -1600 .86 5956563.56 685778. 93 1104.99 12 .00 269.40 M W D 12150 .00 90.14 293.72 8791. 40 5630.25 -1623 .48 5956573.65 685756. 06 1126.59 12 .00 269.39 M W D 12175 .00 90.10 290.72 8791. 35 5639.70 -1646 .62 5956582.52 685732. 69 1148.82 12 .00 269.38 MWD 12200 .00 90.07 287.72 8791. 31 5647.93 -1670 .22 5956590.15 685708. 89 1171.62. 12 .00 269.37 M W D 12225 .00 90.04 284.72 8791. 29 5654.91 -1694 .23 5956596.53 685684. 72 1194.92 12 .00 269.37 M W D 12230 .00 90.03 284.12 8791. 29 5656.15 -1699 .07 5956597.66 685679. 85 1199.64 12 .00 269.37 M W D 12250 .00 89.95 281.72 8791. 29 5660.62 -1718 .56 5956601.64 685660. 25 1218.66 12 .00 268.00 M W D 12275 .00 89.84 278.72 8791. 33 5665.06 -1743 .16 5956605.46 685635. 55 1242.78 12. 00 268.00 M W D 12300 .00 89.74 275.72 8791 .43 5668.20 -1767 .96 5956607.99 685610. 68 1267.21 12 .00 268.01 M W D 12325 .00 89.64 272.72 8791. 56 5670.04 -1792 .89 5956609.21 685585. 72 1291.89 12 .00 268.02 MWD 12350 .00 89.53 269.73 8791. 74 5670.58 -1817 .88 5956609.12 685560. 72 1316.74 12 .00 268.03 MWD 12375 .00 89.43 266.73 8791. 97 5669.80 -1842 .86 5956607.72 685535. 77 1341.69 12 .00 268.05 M W D 12380 .00 89.41 266.13 8792. 02 5669.49 -1847 .85 5956607.29 685530. 79 1346.69 12. 00 268.08 MWD 12400 .00 89.12 268.51 8792. 27 5668.56 -1867 .83 5956605.85 685510. 84 1366.67 12. 00 97.00 MWD 12425 .00 88.76 271.49 8792. 74 5668.56 -1892 .82 5956605.23 685485. 86 1391.57 12. 00 96.97 M W D 12450 .00 88.40 274.47 8793. 36 5669.86 -1917 .78 5956605.91 685460. 88 1416.32 12. 00 96.91 M W D 12475 .00 88.04 277.45 8794. 13 5672.45 -1942. 63 5956607.88 685435. 97 1440.85 12. 00 96.84 M W D 12500 .00 87.69 280.43 8795. 06 5676.33 -1967. 30 5956611.15 685411. 21 1465.09 12. 00 96.75 MWD 12520 .00 87.42 282.82 8795. 92 5680.36 -1986. 87 5956614.68 685391. 55 1484.24 12. 00 96.64 MWD 12525 .00 87.47 282.22 8796. 14 5681.44 -1991. 75 5956615.64 685386. 65 1489.00 12. 00 274.50 MWD 12550 .00 87.71 279.22 8797. 19 5686.08 -2016 .29 5956619.68 685362. 00 1513.04 12. 00 274.53 M W D 12575 .00 87.95 276.23 8798. 14 5689.44 -2041 .04 5956622.42 685337. 17 1537.41 12. 00 274.65 M W D 12600 .00 88.20 273.24 8798. 98 5691.51 -2065 .94 5956623.86 685312. 23 1562.03 12. 00 274.77 M W D 12625 .00 88.46 270.25 8799. 71 5692.27 -2090 .91 5956624.00 685287. 25 1586.84 12. 00 274.87 M W D 12650 .00 88.72 267.26 8800. 32 5691.73 -2115 .90 5956622.83 685262. 29 1611.78 12. 00 274.95 M W D 12675 .00 88.99 264.27 8800. 82 5689.88 -2140. 82 5956620.37 685237. 42 1636.77 12. 00 275.03 M W D 12700 .00 89.25 261.28 8801. 20 5686.74 -2165. 62 5956616.61 685212. 71 1661.74 12. 00 275.09 M W D 12725 .00 89.52 258.30 8801. 47 5682.31 -2190. 22 5956611.57 685188. 23 1686.64 12. 00 275.13 M W D 12750 .00 89.79 255.31 8801. 62 5676.60 -2214. 55 5956605.26 685164. 04 1711.38 12. 00 275.16 M W D 12770 .00 90.01 252.92 8801. 65 5671.13 -2233. 79 5956599.31 685144. 95 1731.02 12. 00 275.18 MWD 12775 .00 90.06 253.52 8801. 65 5669.68 -2238. 58 5956597.74 685140. 20 1735.91 12. 00 85.00 M W D 12800 .00 90.32 256.50 8801. 57 5663.22 -2262 .72 5956590.68 685116. 23 1760.53 12. 00 85.00 MWD 12825 .00 90.58 259.49 8801. 37 5658.02 -2287. 17 5956584.88 685091. 92 1785.34 12. 00 85.01 M W D 12850 .00 90.84 262.48 8801. 06 5654.11 -2311. 86 5956580.35 685067. 34 1810.27 12. 00 85.03 M W D 12875 .00 91.10 265.47 8800. 63 5651.48 -2336. 71 5956577.11 685042. 56 1835.26 12. 00 85.07 MWD • • BP-GDB Baker Hughes INTEQ Planning Report Company: BP Amoco Date: 8/11/2005 Timc : 11:11:58 Page: 4 Field: Pru dhoe Bay Co-~x dinate(NE) Re ference: Well: 02-17, True North Sitr. PB DS 02 Vertical (TVD) Refe rence: 02-17A 61.6 R'ell: 02- 17 Sectio n (VS) Referen ce: Well (O.QON,O.OOE,265.OOAzi) Wellpath: PIa n11, 02-17 B Surve y Calculation Method: Minimum Cur vature Db: Oracle Survey D1D Incl :~zim $S"[VU N/S E/W MapN VIapE VS DLS Toolface '1'001 ft deg deg ft ft ft ft ft ft deg/100ft deg 12895.00 91.30 267.86 8800.21 5650.32 -2356.67 5956575.45 685022.63 1855.25 12.00 85.12 M W D 12900.00 91.32 267.26 8800.10 5650.11 -2361.67 5956575.11 685017.64 1860.24 12.00 272.00 M W D 12925.00 91.43 264.27 8799.50 5648.26 -2386.59 5956572.64 684992.78 1885.23 12.00 271.99 M W D 12950.00 91.52 261.27 8798.86 5645.12 -2411.38 5956568.88 684968.08 1910.20 12.00 271.91 M W D 12975.00 91.62 258.27 8798.17 5640.68 -2435.97 5956563.83 684943.61 1935.08 12.00 271.84 MWD 13000.00 91.71 255.27 8797.44 5634.96 -2460.29 5956557.51 684919.43 1959.81 12.00 271.75 M W D 13025.00 91.79 252.27 8796.68 5627.97 -2484.28 5956549.93 684895.63 1984.32 12.00 271.67 MWD 13050.00 91.87 249.27 8795.88 5619.74 -2507.87 5956541.11 684872.25 2008.54 12.00 271.58 MWD 13075.00 91.95 246.26 8795.05 5610.29 -2531.00 5956531.09 684849.37 2032.40 12.00 271.48 M W D 13100.00 92.02 243.26 8794.18 5599.64 -2553.60 5956519.88 684827.05 2055.84 12.00 271.38 M W D 13125.00 92.08 240.26 8793.29 5587.82 -2575.60 5956507.51 684805.34 2078.79 12.00 271.28 MWD 13150.00 92.14 237.26 8792.37 5574.86 -2596.96 5956494.03 684784.31 2101.20 12.00 271.17 M W D 13175.00 92.19 234.26 8791.42 5560.81 -2617.61 5956479.47 684764.02 2123.00 12.00 271.06 M W D 13195.00 92.23 231.86 8790.65 5548.80 -2633.59 5956467.06 684748.35 2139.95 12.00 270.94 M W D 13200.00 92.25 231.26 8790.46 5545.69 -2637.50 5956463.86 684744.52 2144:12 . 12.00 272.00 M W D 13225.00 92.35 228.26 8789.45 5529.56 -2656.56 5956447.26 684725.86 2164.52 12.00 271.98 MWD 13250.00 92.44 225.26 8788.41 5512.45 -2674.76 5956429.70 684708.10 2184.14 12.00 271.86 M W D 13255.00 92.46 224.66 8788.19 5508.91 -2678.29 5956426.08 684704.66 2187.96 12.00 271.73 M W D 13275.00 92.54 227.06 8787.32 5495.00 -2692.62 5956411.81 684690.68 2203.46 12.00 88.00 M W D 13300.00 92.64 230.06 8786.19 5478.47 -2711.34 5956394.82 684672.38 2223.55 12.00 88.10 M W D 13325.00 92.73 233.06 8785.02 5462.95 -2730.90 5956378.82 684653.21 2244.38 12.00 88.24 M W D 13350.00 92.81 236.06 8783.81 5448.47 -2751.24 5956363.84 684633.24 2265.91 12.00 88.38 M W D 13375.00 92.88 239.07 8782.57 5435.08 -2772.31 5956349.93 684612.51 2288.07 12.00 88.53 M W D 13400.00 92.95 242.07 8781.29 5422.81 -2794.06 5956337.12 684591.08 2310.80 12.00 88.68 M W D 13425.00 93.01 245.07 8780.00 5411.70 -2816.41 5956325.46 684569.01 2334.03 12.00 88.83 M W D 13450.00 93.05 248.08 8778.67 5401.77 -2839.32 5956314.97 684546.36 2357.72 12.00 88.98 MWD 13475.00 93.09 251.08 8777.33 5393.06 -2862.71 5956305.68 684523.20 2381.78 12.00 89.14 M W D 13500.00 93.13 254.08 8775.98 5385.59 -2886.52 5956297.61 684499.57 2406.15 12.00 89.30 MWD 13525.00 93.15 257.09 8774.61 5379.38 -2910.70 5956290.80 684475.56 2430.78 12.00 89.47 M W D 13550.00 93.17 260.09 8773.23 5374.44 -2935.16 5956285.26 684451.23 2455.58 12.00 89.63 M W D 13575.00 93.17 263.10 8771.85 5370.79 -2959.85 5956280.99 684426.64 2480.50 12.00 89.80 MWD 13600.00 93.17 266.10 8770.46 5368.45 -2984.70 5956278.03 684401.86 2505.45 12.00 89.96 M W D 13625.00 93.16 269.11 8769.08 5367.40 -3009.64 5956276.36 684376.96 2530.39 12.00 90.13 M W D 13650.00 93.14 272.11 8767.71 5367.67 -3034.60 5956276.01 684352.00 2555.23 12.00 90.30 M W D • • TERRIE t NUBBLE. BP EXPLORATION. AK 1NC ss-6/1252 220 PO BOX 1966T2 -MB7-5 "Mastercard Check" ANCHORAGE, AK 99519-6612 DATE ~'"~C.J °C'~J PAY TO THE W ORDER OF ~~ $~ First ational Bank`Alaska Anchorage, AK 995/01 MEMO~~~ I /~ ~ ~: L 25 200060:99 i4~~~6 2 2 7~~~ L 556~~• 0 2 20 .~ ,. • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /biQG~ L 1 ~~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as j last two (Z) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (pH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) .assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 02-17B Program Well bore seg ^ PTD#:2051300 Comp any BP EXPLORATION ALASKA) INC Initial ClasslType 11-OIL GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mit_feeattached_________________________ _________ _________Yes_ __----___________----_--_--__-______ -- 2 Lease number appropriate - - - - Yes - - - - - 3 Unique well-name and number - ---------- ----- --- - ----Yes - - - -- -- ...- ----- ------ ------ -- --- - -- -- 4 Well locatedin_a_defned_pool________-_____-_-.--.-_--__ __----..Yes_ ____________________ 5 Well located proper distance from drilling unit-bounda_ry_ _ - . - - . - _ _ _ - - - ... Yes _ _ _ _ - - - - - - - --- - - - - - - - -- - 6 Well located properdistanc@fromotherwells___________ _________ _________Yes _-__---__________-_-.------- -____ - - -- -- 7 Sufficient acreageayailablein_d_rillingunit_-_____________ ______ _________Yes_ ____-.--_-_ -- - 8 If deviated, is-wellboreplatinc_lulled---------------- --------- _...---_Yes_ --__--__ __ ----------------------------------------------------------- 9 Operatoronlyaffectedparty-- --------------------- ------ -------_Yes_ -..-...- -------------------------------------------------------------- 10 Operator has-appropriate. bond in force-- - --- -- -- - -- --- -- Yes - ------ --- -- -- -------- ------ - ------ -- ------------- -- 11 Permit_canbeissuedwithoutconservationorder_________ _________ _________Yes_ _____----_______________--__-.--___--__---_---.--_--__ _--___--_---__-__ Appr Date 12 Permit_canbeissuedwithoutadminist[alive-appr_oval_______________ _________Yes- _______-__--..----__--__-__-__- ------------------------------------------- RPC 8!26!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaan_dslrataauthorizedbylnjection0[der#(put_10#in_comments)-(For_ NA__ _____________-__--__--__-..--..--___--__--__---..__--_--______---_._--_ 15 All wells within1l4_mileareaofreyiewidentified(Forservicewellonly)______ _________NA__ _______-...-_____--__--______.-.-_____- ----------------------------------- 16 Pre-produced injector: duration of pre production less than 3 months_ (For_se[vice well only) NA_ _ - _ _ - _ ----------------------------------- 17 ACM_P_FindingofConsistency_hasbeenissued_for_thispr_oject___________ _________NA__ ____________--_-_--__-____________----__________------.---____________ Engineering 18 Conductor str-ing_p-rovided - - - NA - - - - 19 Su _rface casing_protects aIIknown USl)Ws - - - NA - - - - - 20 CMT-vol_adequate_tocireul_ate-on conductor&surf_ag __ ________ _________ NA_- -----__________--.....-_-__--__-__--...--..----_ - - 21 CMT_vol_adeguate_totie-in long string to surfc&g____-----.------- --- .----NA_ ______-__-_________--_-_______---------------- 22 CMT-willcover_allknown-productive horizons--_-________________ ____ ____Yes- __--____________-_--.-_.-__________-_--..--.---___--__--__-_-..-...--.. 23 Casing designs adequate for C,T,B&_permafrost__________________ ________Yes_ _-.-._.-____________-_--_.__..____________.-------__._____________- _ 24 Adequate tankage.or reserve pit - - - - - - - Yes CTDU. - - - - - - 25 If_a_re-dell, has_a 10-403 for abandonment been approved - - - Yes 26 Adequatewellboreseparation_proposed ---------- - - ------ ---- -Yes ------ -- --- -- - - -- ------ - -- - -- ------ -- - ------ -- 27 Ifdiverterrequired,doesitmeetregulations________________-.-- -___-__-_ NA__ ___-_-$idetrack.__________----_-__-_-__________-__-__--__________-___--___ Appr Date 28 Drillingfluid_programsehematic_&equiplistadequate________________ _________Yes_ -----.Max MW 8.6ppg,___-_--_-___,______-..-..-_-----______-___-.-.-_ WGA 8129!2005 29 BOPES, do they meet regulation _ Yes _ _ _ _ _ 30 BOPE_pressratingappropriate;testto_(putpsigincomments)_-_-.--._ _-- --___Yes- -_--__Testto3500psi._MSP2370psi.---______________ ____________--__--_-.--...-.- 31 Choke-manifold compliesw/API_RP-53~M_ay 84)___________________ _________Yes_ ___---.----__-________ -- - --- 32 Work willoccurwithoutoperationshutdow_n_________ ______----- ___-___Yes_ ____-_-_--_--________ __--_--___-_________ __----.---.-_--__-___-__ -__-- 33 I& presence_of H2S gas probable- - - - - - - - - - - Yes - 100-Ppm= - - - - - 34 Mechanical condition of wells within AOR verified (For_s_ervice well onlya - _ NA_ _ - _ - - - - - - - -- Geology 35 Permit can be issuedwlohydrogen-sulfide measures____--..---____ __-__.--No-- __________________--.-_-___-______-----_-----.__-.-__---_---..-..---.- 36 Data_presentedon-potentialoyerpressur_ezones-_____-------- --- NA-- ------------------------------------------------------------------- Appr Date 37 Seismic-analysis_ofshallowgas_zones-______------- --------- ---------NA__ ___________--__-.-- ------------------------------------------------------ RPC 8!2612005 38 Seabed condition survey_(ifoff-shore) _ - - - - - - NA - - - -- - --- - 39 _Conta_ctnamelphone_for_weeklyprogress-repo[ts[exploratoryonly]-------- ---------NA-- _-,__-_-_.______--,---.-_-„-_____-_---_-.----___________-.--..--.....- Geologic Commissioner: Engineering Date: Commissioner: Date C m' s n Dat ~~'s ~ ~ ~ ~ ~ z~_as ~ . 1~~Js .f • J~ Well History File APPENDIX • Information of detailed nature that is not particufariy 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 information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • Sperry-Sun Drilling Services LIS Scan Utility C3 n ~ $Revision: 3 $ `t`T LisLib $Revision: 4 $ Vc-~~'r (~ Thu Jan 26 15:49:12 2006 Reel Header Service name .............LISTPE Date .....................06/01/26 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 .....................06/01/26 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 Prudhoe Bay MWD/MAD LOGS WELL NAME: 2-17B API NUMBER: 500292045302 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 26-JAN-06 JOB DATA MWD RUN 8 MWD RUN 9 MWD RUN 10 JOB NUMBER: MW0003229698 MW0003229698 MW0003229698 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: B. HOLT / B. B. HOLT / B. B. HOLT / B. SURFACE LOCATION SECTION: 36 TOWNSHIP: 11N RANGE: 14E FNL: 213 FSL: FEL: FWL: 787 ELEVATION (FT FROM MSL 0) KELLY BUSHING: 61.61 DERRICK FLOOR: GROUND LEVEL: • WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 11614.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 2-17A WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 11605'MD/8798'TVDSS. 4. MWD RUNS 8-10 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO MWD DATA WERE ACQUIRED ON MWD RUNS 1-7. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN IN THE 2-17B WELLBORE ON 13 SEPTEMBER 2005. THESE LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 18 JANUARY 2006. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 8-10 REPRESENT WELL 2-17B WITH API#: 50-029-20453-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13576'MD/8773'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. File Header Service name .............STSLIB.001 Service Sub Level Name.... Ver$ion Number...........1.0.0 Date of Generation.......06/01/26 Maximum Physical Record..65535 File Type ................LO Previous File Name....."..STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11350.5 13548.0 • • ROP 11627.5 13579.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 11350.5 11352.0 11353.5 11355.0 11356.0 11357.5 11359.0 11360.0 11365.0 11367.0 11384.5 11385.5 11387.0 11388.5 11390.0 11391.0 11392.5 11393.5 11398.5 11400.5 11605.0 11606.5 11610.5 11612.5 11614.5 11614.5 11617.5 11616.5 11636.5 11636.0 11663.0 11662.0 11673.5 11673.0 11724.5 11723.0 11745.0 11744.0 11777.0 11775.5 11799.0 11796.5 11834.5 11833.0 11898.5 11899.0. 11909.0 11910.0 11967.5 11970.0 11999.0 12002.5 12050.5 12048.5 12062.0 12060.5 12064.0 12064.0 12079.5 12079.0 12086.5 12086.5 12095.0 12094.0 12106.5 12104.5 12164.5 12170.0 12168.0 12172.5 12183.0 12184.5 12202.0 12201.5 12219.0 12222.0 12234.5 12236.0 12245.0 12247.0 12256.0 12257.0 12266.0 12268.5 12346.0 12348.0 12355.0 12356.5 12368.5 12369.0 12572.0 12571.0 12577.5 12578.0 12623.5 12622.0 12667.0 12668.5 12675.5 12678.0 12718.5 12719.5 12759.5 12758.0 12803.0 12801.5 12816.0 12815.0 • • 12825.5 12823.5 12861.0 12859.5 12911.0 12905.0 12941.0 12937.0 13008.5 13007.5 13020.5 13019.5 13031.5 13028.5 13057.5 13052.5 13104.0 13097.5 13185.5 13184.5 13188.5 13187.5 13191.5 13189.5 13201.0 13199.5 13204.0 13203.0 13207.0 13205.5 13214.5 13213.0 13270.5 13271.0 13277.0 13278.0 13284.0 13284.5 13289.0 13289.5 13292.0 13292.5 13296.5 13298.0 13298.0 13300.5 13300.5 13304.0 13307.5 13310.5 13317.5 13320.0 13336.5 13336.5 13376.0 13377.0 13397.0 13397.0 13418.5 13416.5 13428.5 13425.0 13433.0 13429.5 13436.5 13432.5 13441.5 13438.0 13448.0 13445.0 13579.0 13576.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 8 11352.0 11775.0 MWD 9 11775.0 12162.0 MWD 10 12162.0 13576.0 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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11350.5 13579 12464.8 4458 11350.5 13579 ROP MWD FT/H 0.06 570.9 65.536 3904 11627.5 13579 GR MWD API 26.86 555.25 76.9008 4043 11350.5 13548 First Reading For Entire File..........11350. 5 Last Reading For Entire File...........13579 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/26 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.......06/01/26 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11352.0 11744.5 ROP 11627.0 11775.0 LOG HEADER DATA DATE LOGGED: 08-SEP-05 SOFTWARE • ~ SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11775.0 TOP LOG INTERVAL (FT) 11626.0 BOTTOM LOG INTERVAL (FT) 11775.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.1 MAXIMUM ANGLE: 91.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 11614.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 146.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11352 11775 11563.5 847 11352 11775 ROP MWD080 FT/H 0.06 104.21 32.1299 297 11627 11775 GR MWD080 API 26.86 555.25 71.1001 434 11352 11744.5 First Reading For Entire File..........11352 Last Reading For Entire File...........11775 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/26 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.......06/01/26 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11745.0 12131.0 ROP 11775.5 12162.0 LOG HEADER DATA DATE LOGGED: 09-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12162.0 • TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • 11775.0 12162.0 87.6 94.3 TOOL NUMBER TLG002 4.125 11614.0 Flo Pro 8.60 65.0 9.5 24000 8.0 .000 .000 .000 .000 .0 150.0 .0 .0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 Last First • ~ Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11745 12162 11953.5 835 11745 12162 ROP MWD090 FT/H 0.59 59.62 34.9751 774 11775.5 12162 GR MWD090 API 33.39 114.7 68.5639 773 11745 12131 First Reading For Entire File..........11745 Last Reading For Entire File...........12162 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/26 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.......06/01/26 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12131.5 13545.0 ROP 12162.5 13576.0 LOG HEADER DATA DATE LOGGED: 12-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13576.0 TOP LOG INTERVAL (FT) 12162.0 BOTTOM LOG INTERVAL (FT) 13576.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG .. • MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 86.8 95.4 TOOL NUMBER TLG015 4.125 11614.0 Flo Pro 8.60 65.0 9.0 24000 8.0 .000 .000 .000 .000 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 .0 167.0 .0 .0 Last Name Service Unit Min Reading DEPT FT 12131.5 13576 Max Mean Nsam 13576 12853.8 2890 First Reading 12131.5 • ROP MWD100 FT/H 0.32 570.9 77.1918 2828 12162.5 13576 GR MWD100 API 34.12 294.3 79.4076 2828 12131.5 13545 First Reading For Entire File..........12131.5 Last Reading For Entire File...........13576 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/26 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/01/26 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 .....................06/01/26 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