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Home My WebLink About212-0407. 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 F-08B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-040 50-029-20135-02-00 12701 Surface Intermediate Liner Liner Liner 9019 2678 10067 1546 651 3262 10880 13-3/8" 9-5/8" 7" 3-3/16" 2-3/8" 8723 22 - 2700 20 - 10087 9520 - 11066 10435 - 11086 9439 - 12701 22 - 2700 20 - 8174 7844 - 8865 8408 - 8881 7798 - 9019 12607, Unknown 2670 3090 7020 11780 10880, 11381 4930 5750 8160 11200 10544 - 12655 4-1/2" 12.6# / 7" 26# / 4-1/2" 13cr80 / N-80 18 - 9546 / 9520 - 9559 / 10435 - 10447 8483 - 9019 Conductor 79 20" 22 - 101 22 - 101 1530 520 4-1/2" Baker S3 Packer 10435, 8408 9488, 10435 7826, 8408 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 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 0028281 18 - 7859 / 7844 - 7866 / 8408 - 8416 N/A N/A 252 158 21405 11228 21 3 1500 1500 1100 1000 N/A 13b. Pools active after work:Prudhoe Oil 4-1/2" OTIS WD Packer 9488, 7826 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 1:13 pm, Mar 19, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.03.19 11:33:22 - 08'00' Torin Roschinger (4662) RBDMS JSB 032725 DSR-3/28/25JJL 4/9/25 ACTIVITY DATE SUMMARY 3/15/2025 (Freeze protect for E-line) TFS U4, Pumped 9 bbls 60/40 and 34 bbls crude down flowline in WSR form to freeze protect for E-line, Preesured up flowline to 1500 psi per DSO, flags and tags hung on WV, DSO informed of departure, ****Well left in Alaska E-line control**** 3/15/2025 ***WELL SHUT IN ON ARRIVAL*** RIG UP AK E-LINE (PERF/PLUG) PT 250L 3000H, FUNCTION WLVS THUNDERBIRD FREEZE PROTECT FLOWLINE RIH WITH 1.69" 10' SNAKE STRIP GUN CORRELATE TO SLB MCNL DATED 13MAY12 PERFORATE 10,564-10,574 CCL STOP DEPTH=10,556.9' (CCL-TS=7.1'), CONFIRM SHOTS FIRED LAY DOWN FOR THE EVENING ***WELL SHUT IN ON DEPARTURE***JOB TO BE CONTINUED 16-MAR-25 3/16/2025 ***JOB CONTINUES FROM 16-MAR-25 WSR*** (ADPERF / SET PLUG) RIG UP AND PT PCE 250 L 3000 H PERFORATE 10,554-10,564 / 10' 1.69" STRIP GUN 6 SPF CCL STOP DEPTH= 10,546.9' (CCL-TS=7.1') PERFORATE 10,544-10,554 / 10' 1.69" STRIP GUN 6 SPF CCL STOP DEPTH= 10,536.9 (CCL-TS=7.1') SET 1.71" CIBP @ 10.880 CCL STOP DEPTH=10,866.4 (CCL-ME=13.6') RDMO AKEL ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE 3/16/2025 T/I/O=2400/1900/0 (Assist E-line W/ flush perf derbis) Pumped 40 bbls crude down the TBG to begin flush. TBG locked up after 40 bbls @ 3000 psi. Notified WSL of well status. Well left in control of Eline upon departure Daily Report of Well Operations PBU F-08B Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250216 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # BRU 232-04 50283100230000 132037 1/18/2025 AK E-LINE Perf CLU 08 50133205340000 204005 2/13/2025 YELLOWJACKET SCBL CLU 10RD2 50133205530200 224135 1/2/2025 YELLOWJACKET SCBL CLU 10RD2 50133205530200 224135 12/13/2024 YELLOWJACKET SCBL CLU 7 50133205310000 203191 1/25/2025 YELLOWJACKET SCBL IRU 44-36 50283200890000 193022 1/21/2025 AK E-LINE Plug/Perf KALOTSA 10 50133207320000 224147 2/11/2025 YELLOWJACKET SCBL KALOTSA 9 50133207310000 224145 1/26/2025 YELLOWJACKET SCBL KBU 22-06Y 50133206500000 215044 1/11/2025 YELLOWJACKET SCBL KU 13-06A 50133207160000 223112 1/12/2025 YELLOWJACKET SCBL MRU M-25 50733203910000 187086 1/15/2024 AK E-LINE PPROF NCIU A-21 50883201990000 224086 1/6/2024 AK E-LINE Plug/Perf PBU 06-05A 50029202980100 224115 1/14/2025 HALLIBURTON RBT PBU 09-35B 50029213140200 224122 2/3/2025 HALLIBURTON RBT PBU B-12B 50029203320200 224133 1/20/2025 HALLIBURTON RBT PBU D-12 50029204430000 180015 12/19/2024 BAKER SPN PBU F-08B 50029201350200 212040 1/27/2025 HALLIBURTON RBT PBU NK-41A 50029227780100 197158 12/18/2024 YELLOWJACKET CBL PBU S-100A 50029229620100 224083 1/5/2025 HALLIBURTON RBT Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. 162-037 T40080 T40081 T40082 T40082 T40083 T40084 T40085 T40086 T40087 T40088 T40089 T40090 T40091 T40092 T40093 T40094 T40095 T40096 T40097 PBU F-08B 50029201350200 212040 1/27/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.18 13:06:47 -09'00' 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 F-08B Extended Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-040 50-029-20135-02-00 12701 Surface Intermediate Liner Liner Liner 9019 2678 10067 1546 651 3262 11381 13-3/8" 9-5/8" 7" 3-3/16" 2-3/8" 9037 22 - 2700 20 - 10087 9520 - 11066 10435 - 11086 9439 - 12701 22 - 2700 20 - 8174 7844 - 8865 8408 - 8881 7798 - 9019 12607 2670 3090 7020 11780 11381 4930 5750 8160 11200 11350 - 12655 4-1/2" 12.6# / 7" 26# / 4-1/2" 12.6# 13cr80 / N-80 18 - 9546 / 9520 - 9559 / 10435 - 10447 9033 - 9019 Conductor 79 20" 22 - 101 22 - 101 1530 520 4-1/2" Baker S3 Packer 10435, 8408 9488, 10435 7826, 8408 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 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 0028281 18 - 7859 / 7844 -7866 / 8408 - 8416 N/A N/A 231 855 21838 13652 12 71 1050 650 1140 1100 324-229 13b. Pools active after work:Prudhoe Oil 4-1/2" OTIS WD Packer 9488, 7826 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 11:12 am, May 08, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.05.08 10:36:32 -08'00' Torin Roschinger (4662) RBDMS JSB 051524 DSR-5/8/24WCB 7-30-2024 ACTIVITY DATE SUMMARY 4/30/2024 LRS CTU #1, 1.5" Blue Coil Job Objective: Set CIBP, Extended AddPerf MIRU CTU. Issues with powerpack, unable to raise mast. ...Continued on WSR 5-1-24... 5/1/2024 LRS CTU #1 - 1.50" Coil ***Cont. from WSR 4-30-24** Job Objective: Set CIBP, Extended AddPerf Contiue Rig up CTU. Repair issues with powerpack fuel supply. Perform weekly BOP test. Make up 1.75" DJN drift BHA and RIH. Load well with 1% KCl w/ SafeLube. Drift down to tag at 12570' CTMD, pick up 50' from weight back and paint gren TD flag at 12520'. POOH maintaing hole fill. M/U HES GR/CCL logging tool, RIH maintaining hole fill. log up from 12538 ...Continued to WSR on 5/2/24.. 5/2/2024 LRS CTU #1 - 1.50" Coil ***Cont. from WSR 5/1/24** Job Objective: Set CIBP, Extended AddPerf Continue loging from 12535, flag at 11750, top of log at 10,500'. POOH maintaining hole fill. Make up 2-3/8" NS CBIP setting BHA and RIH. Tie-in to the flag and set CIBP with top at 11831'. POOH maintaining hole fill. Confirm well kill and deploy 365' of 1.56" millenium perf guns, 6spf (340' loaded). RIH and tie-in to CIBP top. Perforate 11350'-11505', 11515'-11678', and 11693'-11715''. No-flow test good, circulate across the top. Perform kick while tripping drill. Un-deploy guns while maintaining hole fill. Ball recovered, All shots fires and guns L/D, Well capped with 16bbls 60/40. RDMO ...Job Complete.. Daily Report of Well Operations PBU F-08B gg gg Make up 2-3/8" NS CBIP setting BHA and RIH. Tie-in to the flag and set CIBP with top at 11831'. POOH The adperfs are shown correctly on the new WBS, below. The CIBP's depth has a typo on the WBS. It should read "11831". I corrected the typo. -WCB g() 11350'-11505', 11515'-11678', and 11693'-11715 11831' is the correct depth. The above is a typo. -WCB 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 F-08B Extended Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-040 50-029-20135-02-00 341J ADL 0028281 12701 Surface Intermediate Liner Liner Liner 9019 2678 10067 1546 651 3262 12663 13-3/8" 9-5/8" 7" 3-3/16" 2-3/8" 9019 22 - 2700 20 - 10087 9520 - 11066 10435 - 11086 9439 - 12701 2400 22 - 2700 20 - 8174 7844 - 8865 8408 - 8881 7798 - 9019 12607 2670 3090 7020 11780 None 4930 5750 8160 11200 11580 - 12655 4-1/2" 12.6# / 7" 26# / 4-1/2" 12.6#13cr80 / N-80 18 - 9546 / 9520 - 9559 / 10435 - 104479033 - 9019 Conductor 79 20" 22 - 101 22 - 101 1530 520 4-1/2" Baker S3 Packer 4-1/2" OTIS WD Packer 9488, 7826 10435, 8408 Date: Aras Worthington for Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-930-5990 PRUDHOE BAY 5/6/2024 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 No SSSV Installed By Grace Christianson at 12:54 pm, Apr 19, 2024 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2024.04.19 12:11:02 - 08'00' Aras Worthington (4643) 324-230 10-404 SFD 4/20/2024MGR19APR24 2400 DSR-4/23/24*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.26 08:25:23 -08'00'04/26/24 Set CIBP & Ext AdPerf Well: F-08B Well Name:F-08B API Number:50-029-20135-02 Current Status:Shut in HGOR Pad:F-Pad Estimated Start Date:5/06/24 Rig:CTU Reg. Approval Reqd?10-403 & 10-404 Date Reg. Approval Recvd: Regulatory Contact:Abbie Barker Permit to Drill Number:212-040 First Call Engineer:Michael Hibbert Contact:907-903-5990 Current Bottom Hole Pressure:3250 psi Field Estimate KWF: KWF 7.2 PPG Plan on using 1% KCL/Seawater MPSP:2400 psi (BHP - .1psi/ft gas gradient + safety factor) Bottomhole Temp:193 deg Max Dev:94 deg At 11,451 MD Min ID:1.78 ID Aluminum Bushing at 9,446 MD Brief Well Summary: F-08B coil sidetrack was drilled in 5/12 and completed with 200 of Z2A perforations. It remained competitive until January of 2015. Well remained shut in until April 2017. F-08B was used as a cycle well with ~7 POPs until 2020. In July 2019, a plug was set and 90 of 2A was perforated. This result was relatively poor. In June 2022, the CIBP was milled and all perforations were produced which resulted in ~11 months of competitive production. The well has been mostly shut-in since March 2023 due to being HGOR, but is cycled regularly with short POPs (2-3 days) with typically several weeks shut-in. Objective: The purpose of this procedure is to isolate most of the current perforations and then re-perf/add-perf up-hole to increase rate and lower the well's GOR by accessing unproduced sands along the lateral. NOTES: Well hasexhibited some minor TxIA communication that is seen via TIOs. Manageable by bleeds. Needs 1.5 CT due to 2-3/8 liner. Procedure: Coil Set CIBP 1. MIRU 1.5 CTU include considerations for extended perforating deployment. Rig up PCE/BOPE. 2. 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. 3. RIH with GR/CCL and ~1.75 nozzle to plug/perf depths. Pull correlation log and paint flags for plug set/perforating. 4. POOH. 5. MU 2-3/8 CIBP. RIH and set at 11,830. Tag to confirm good set. This will shut-off all but 90 of perforations. POOH. Coil Extended Perforating Notes: Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating Set CIBP & Ext AdPerf Well: F-08B bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. Bullhead ~184 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) Well will still have open perforations post plug set. a. Wellbore volume to top perf = 153 bbls b. 4-1/2 Tubing/Liner 9,439 X .0152bpf = 144 bbls c. 2-3/8 Liner 2,141 X 0.0039 = 9 bbl 2. Prepare for deployment of TCP guns. 3. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 4.*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. 5.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 1.56 guns or similar Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 11,350 11,505 11,505 11,515 11,515 11,678 11,678 11,693 11,693 11,715 155 Blank 163 Blank 22 365 1,460 lbs (4 ppf) 6. RIH with perf gun and tie-in to coil flag correlation, consider tagging the CIBP if there is any discrepancy with depths. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 7. After perforating, PUH to top of liner or into tubing tail to ensure debris doesnt fall in on the guns and stick the BHA. Confirm well is dead and re-kill, if necessary, before pulling to surface. 8. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 9. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 10. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 11. RDMO. Turn well over to Operations to POP. Make up PCE. - mgr Set CIBP & Ext AdPerf Well: F-08B Attachments: Current Wellbore Schematic Proposed Wellbore Schematic Tie in Log BOP Schematic Standing Orders Equipment Layout Sundry Change Form Set CIBP & Ext AdPerf Well: F-08B Current Schematic: Set CIBP & Ext AdPerf Well: F-08B Proposed Schematic: Set 2-3/8 CIBP at 11,830 Isolating these perf intervals Perforate the following intervals: 11,350 11,505 11,515 11,678 11,693 11,715 C C C C C Set CIBP & Ext AdPerf Well: F-08B Tie-in Log Set CIBP & Ext AdPerf Well: F-08B Perforate the following intervals: 11,350 11,505 11,515 11,678 11,693 11,715 Set CIBP & Ext AdPerf Well: F-08B Set 2-3/8 CIBP at 11,830 Isolating these perf intervals Perforate the following intervals: 11,350 11,505 11,515 11,678 11,693 11,715 Set CIBP & Ext AdPerf Well: F-08B BOP Schematic Set CIBP & Ext AdPerf Well: F-08B Set CIBP & Ext AdPerf Well: F-08B Set CIBP & Ext AdPerf Well: F-08B 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 HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUN 18 1. Operations Performed f 4 Abandon 11Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations s Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approvetl Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set COP 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Shatigraphic ❑ Exploratory ❑ Service EI6. 5. Permit to Drill Number: 212-040 3. Address'. P.O. Box 196512 Anchorage, AK 99519-6612 API Number 50-029-20135-02-00 7. Property Designation (Lease Number): ADL 028280 & 028281 :::Well measured Name and Number. PBU F-0813 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: Size: MD: TVD: Burst: Collapse: Conductor Total Depth: measured 12701 feet Plugs measured 11800 feet 13-3/8" true vertical 9019 feel Junk measured 12573, 12575 feet Effective Depth: measured 11800 feet Packer measured 9488, 10435 feet 7866-8865 true vertical 9029 feet Packer true vertical 7826, 8408 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 79 20" 22-101 22-101 1530 520 Surface 2678 13-3/8" 22-2700 22-2700 5380 2670 Intermediate 10067 9-5/8" 20-10087 20-8174 5750 / 6870 3090/4760 Liner 1507 7" 9559-11066 7866-8865 8160 7020 Liner 651 3-3/16" 10435-11086 8408-8881 Liner 3262 2-3/8" 9439-12701 7798-9019 11200 11780 Perforation Depth: Measured depth: 11580 -12655 feet True vertical depth. 9033-9019 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 18-9546 7" 26# N-80 9520-9559 4-1/2" Baker S-3 Penn Packer 9488 Packers and SSSV (type, measured and 4-112" Otis WD Packer 10435 true vertical depth) No SSSV Installed 12. St mulaaon or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 18-7859 7844-7866 7826 8408 13. Representative Daily Average Production or Injection Data 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ Oil -Bbl Gas-Mc7 Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 240 24312 20 1962 1014 Subsequent to operation: 321 5583 50 1368 560 14.Attachments:(reulredmra)MC25.070.25.071,&25.2x1) Daily Report of WeII Operations 0 Copies of Logs and Surveys Run ❑ 15. Well Class atter work: Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby cerbfy that the foregoing is true and correct to the best of my knowledge. Authorized Name: Haffener, Jordan Sundry Number or N/A if C.O. Exempt: WA Contact Name: Haffener, Jordan Authorized Title: Production Engineer Contact Email: Jordan.Haffener0biocom Authorized Signature: e:e=—-J Contact Phone: +1 9075645383 Form 10404 Revised 04/2017 �J r-�''-Date: iiriRZr,•1v.K l9 9B MS Nt/JUN 19 2019 Submit Original Only Daily Report of Well Operations PBU F -08B ACTNITYnATP ci IEI\IAOV CTU #8 / 1.50" Coil / Job Objective: CIBP & Adperf MIRU. Standby due to injury 5/172019 **Continued on 5/18/19 WSR** CTU #8 / 1.50" coil / Job Objective: CIBP & Adperf MU & RIH w/ HES memory GR/CCL toolstring w/ 1.75" nozzle on bottom. Log from 11,900' to 11,400'. Paint RED flag at 11,750'. POOH. RIH 8 set 2-3/8" BOT CIBP at 11800_ Pressure test CIBP to 1079psi -PASS. POH, recover 12" ball. Cut coil for chrome management. RIH with HES 1.56" x 32' Perfecta gun (#1). Tag & correct depth off CIBP and perforate interval 11,638.76' - 11,670'. POOH. 5/182019 "Continued on 5/19/19 WSR** CTU #8 / 1.50" coil / Job Objective: CIBP & Adperf POOH with pert gun #1. Shots fired and ball recovered. Standby until ascending/descending ladder issue is resolved. MU and RIH with HES 1.56" x 32' Perfecta gun (#2). Tag CIBP and correct depth. Perforate 11,610'- 11,640'. POOH. 5/19/2019 **Continued on 520/19 WSR** CTU #8 /1.50" Coil /Job Objective: CIBP &Adperf POOH with perf gun #2. Shots fired and ball recovered. MU & RIH with HES 1.56" x 32' Perfecta gun (#3). Tag CIBP and correct depth. Perforate 11,580'- 11,610'. POOH. Shots fired and ball recovered. RDMO. Freeze protect I LIU 39bbbis 50/50. 5/20/2019 **Job Com lete** TFM= 4"CIW WELLHEAD= 13-5/8'MOEVOY ACTUATOR= BAKER NML KB. ELE SPF BF. ELEV = 34.92 KOP= 2700' Max Angle = 94' @ 11451' Datum lvD= 1105T Datum TVD= 8800'SS " TRACK CSG, 13-3/8- CSG. 72 • 20' CONDUci'OR 101' 94#, F"0, D =19.124" 9-58" CSG, 40#, 615' L-80 HVDRL 563 XO TO TC11 80 TO!, D = 8.835" 2129' BUTT. D = 12 I9-5/8" FDWCO FO CB&NrE R --I 421 MINIMUM ID =1.78" @ 9446' MILLED OUT ALUMINUM BUSHING DEPLOYMENTSLEEVE 9-58" 7' ID = 3.958" C4S, .0383 but. D = 6276' = 61 SIV, 33/16" LMR, 6.2#, L-80, .0076 bpf, D = 2.80" 1 PERFORATION SUK WRY R=F LOG: SWS MOLAL ON 05/13/12 ANGLEATTOPPEPR 91" @ 11580' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 1.56^ 6 11580 - 11670 O 05/19/19 1 18 05/26/12 20 05IM12 1.56" 6 11870 - 11900 C 05/24/14 1.56" 6 11900 - 11930 C 05/23/14 1.56^ 6 11930 - 11960 C 05/23/14 1.56^ 6 12160 -12250 C 08/17/13 1.56" 6 12455 - 12655 C 05/14/12 I PBTD .0039 hot. D= 1.995" 11 SAFETY NOTES: WELL ANGLE> 70° @ 11315'. " 4-1r2" CHROME TBG'** "HOWCO FO CEN134TE R " HOWCO FO CBVENTBR rAC1 FT MA NI WPI C ST I MD ND I DEV TYPE I VLV LATCH PORT DATE 2 1 1 3795 7638 3769 6493 1 22 40 1 MMG HMC I DOME SO R( R( 1 18 05/26/12 20 05IM12 9425' rj4-1/2"HESXNlP1)=3.813" CO"Mm 9439' 3.70" DEPLOY SLV, D=3.00" JQ 3-1/2" X 3^ LNR XO, D = 2.70^ =� 2.25' DEPLOY SLV, D=1.79" 12120/02 C ALlMJl1M BUSHING @9446' (MLLE) OUT) ,9489' 9-5/8^ X 4-1/2" BKR S-3 PKR D = 3.875" 9512' 4-112^ FES xNIP, D= 3.813' BEHIND 9533' 4-1/2" F1ES XN NIP, D = 3.725^ I CT LINER LTP w / 40' PBR & HGR, JD=? WDFKR D=4.0" BEHIND CT LINER I (MILLED 12/04/02) 10447 4-1/2" W/LEG, D = 3.956" MILLOUT WINDOW (F -08A) 11086' - 11074' MILLOIIT WINDOW (F -08B) 11086'-11091' DATE REV BY CO"Mm DATE REV BY I COMA NTS 09108176 INITIAL COMPLETION 05/27/14RMI-V SERMILL CIBRADFE RF(5/24/14) 12120/02 C CTD SIDETRACK(F-OSA) 08/17/14 RDW PJ MLL CBP& PUSH OH 07/14107 N2ES RWO 05/28/19 BGUMI) SETCBP&ADFBRFS 05/15112 4&UNC-7, CTDSIDETRACK(F-08B) 08/13/12 AKIPJC FINAL DRLG CORRECTIONS 09/04/13 ALWJIVE SET CBP/ADPERFS(08/1&17113) 2-318" PRLJOHOE BAY UNIT WELL: F -08B PERMIT No: '2120400 API No: 5D-029-20135-02 SLC 2, TI IN, R13F, 2570' FNI_ & 2403' FWL BP Exploration (Alaska) o II I o as a co M E e^ m E f0 m Z ��Z o z c 2 o E O Q E a) } } } N c lT E E w E E _ ca _ f6 N os U m J U > E 0 m a) 4 5 � >-1 !i l4 c O) >. 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O a 1 III w -J U m o Z Q w J o ro .C zCL :-:, N r a E V U ti Qco co 4 9 l'""`' Z N Z \ 1 In am w CO 0 a L.....!iiic Q i1 I . a to Q z° . E �� E Q ro U Z 116- d 0• tT / I� a 0 N iI min I d d N CC o ,9_ C ✓ t0 a STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COMMIS I REPORT OF SUNDRY WELL OPERATIONS !UN 2 5 2014 • 1.Operations Abandon L] Repair WeIL1 Plug Perforations ❑ Perforate E Othe Performed: Alter Casing❑ Pull TubinJ Stimulate-Frac ❑ Waiver Time Extensioi❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Wel] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Development] Exploratory I] 212-040-0 3.Address: P.O.Box 196612 StratigraphiD Service 6.API Number: Anchorage,AK 99519-6612 50-029-20135-02-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL0028281 PBU F-08B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12701 feet Plugs measured 12030 feet true vertical 9018.83 feet Junk measured 12573 feet Effective Depth measured 12030 feet Packer measured See Attachment feet true vertical 9024.47 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 20"94#H-40 20-101 20-101 1530 520 Surface 2681 13-3/8"72#N-80 19-2700 19-2699.86 4930 2670 Intermediate 2089 9-5/8"40#L-80 18-2107 18-2106.95 5750 3090 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11870-11900 feet 11900-11930 feet 11930-11960 feet 12160-12190 feet 12190-12220 feet 12220-12250 feet 12455-12655 feet True Vertical depth 9029.11-9027.88 feet 9027.88-9026.76 feet 9026.76-9026.59 feet 9022.29-9022.92 feet 9022.92-9023.38 feet 9023.38-9023.8 feet 9017.55-9018.81 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 278 16247 20 0 1214 Subsequent to operation: 194 15753 10 0 1150 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator❑ Development(] Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil E Gas ❑ WDSP❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUCI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact GarryCatron Email Garry.CatronBP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 6/25/2014 RBCMS JUN 2 6 20 ' Form 10-404 Revised 10/2012 /4 - 7/24- Submit Original Only Packers and SSV's Attachment ADL0028281 SW Name Type MD TVD Depscription F-08B PACKER 9477 _ 7819.5 4-1/2" Baker S-3 Perm Packer F-08B PACKER 9599 7888.21 7" Baker Packer w RN0 (OOO � NOOOOO iIMNr , NC) Nr- � V EC• O') t) ON- 0 � c0 M M - T MWWWMWOONF T O r T (O f- O) 0 (O T •- 000 ) (Oo0c0 N 00 a) 00 00 N N- I` llllll tomr- O) LO0 N M N %-0MW oo) 0) c0c N f` 0 N- W T N OD O W(O 0 0 0 O TO O N- O M O2 m s T O N T O N T T T T N O) O) o • co M • co owc, mulmmoo , oN N T N O0) O0) 0 T — 2 = 0 • D O O O O 00 T 0000000 000? V Of 1- 11ZJOOJZ200 = ** *r: ** Z * * * J • N * O N. N N 00 00 p0 N CV T N V ;91919 .C4: i M T- O O N ('7 T- 4 s d• ONt,- MA- NO ) � J W in ooWWWWWIQiZZ Z W W W W W W m m Q lzZ Z Z Z D D D U Z J J J J 0 H H • R _? 2 / 5 / �% / # \ 2 ® ± a 6 - -§ $ c $ % E / i / \ \ a/ 0 �\ U) 0 E5 5 o _\ q a E & < 6 $ \ / \ . ; 19 c co o 2 ® CL k / / > b / CL- Co § \ ƒ 0 o \ O 0— .- Ta \ - 0 ® - $ -0 ƒ E % c $ / \ ¥ I § c % ® e c3 cw / -0 o CO -6.-37 / / f -0w / % % § / CL / % b \ r- 0 .0 a 0) 0 Q. w 2 @ b \ I ? e $ o 1- w o Gk _ Opo Qa o C ° < w o e = Cl) o a — n — . 2222 / & .0- °— k / 2 3t 0 0 t � '[ I = a 2 g n ,- e O O o _ - � — = - / c 0 / 6 / 0 �¥ cOa 0 — o « 0 00 .471 Cti < CO ) . 0 0 / 0) E / § ` 0 0 / O 9 U o w .0 n A 0 \ \ A \ \ H CO I O. R 2 t •e CD = U i z J # O O O U \ \ C _ � # a # \ _ o / / C o cc) Lo _ C ° N c m 0- g ° coc E C C ) co C -6 4— o . U) E / / 0)\ Co k„zr ,- \ c / f 0 D I / 0 _10 $ & = g m / / a $ H -& _ H » ° co = g / $ © \ f 2 § G # R U a n 0. / f / # o i © 9 # \ § / # / .0 CD IX 7-.7 ¥ ƒ E / . 0 ,_ 00c \ H 0 \ co I@ - U 9 O S 2 .a ° 9 „sw » ° 9 9 = k O - H > CD Q ce ) CD CD - ƒ f J % ' S / / ® ow epee $ IEt — CI S 3 / $ q ƒ f w £ \ % ƒ 2 _ ƒ -Fa -0\ A - . e 7 e 5 E § £ \ % * 0 / $ & $ - / a0 i E ° \ % o % E / % E ® 2 _ - / $ a 2— f / 7 - 7 0 2 7 ¢ & 2 0) > / $ L Cr) > ) E 0 \ q &\ a 2 \ $ C 0 a) co /-1 = .J \ . -- . �\ .§ p. / .2% / § / o _ 0 _ 0 ° 0 o 2 k %k U ± -0 2 = U 2 12 p : U U Q * U _1 ¢ t N \ / \ 2 N a 4 CV N e e I.9 in r n TREE 4"CNV SAFE' 1TES:WELL ANGLE>70°@ 11315'. WELLHEAD= 13-5/8"li t:EVOY O ACTUATOR= BAKERC "'4-1. .;HROMETBG'** MAL.KB.ELE 54 8' 20"CONDUCTOR H 101' *• ( 2072' H9-5/8-HES CBvIU ITER BF.rib/= 34.92' KOP= 2700' 94#,1340, 4 2097' J—4-1/2"HES X NP,D=3.813' Max Angle= 94"@ 11451' D=19 124" 4 Datum M3= 11053' 9-5/8'CSG,40#, — 615' I 2106' H 9-518"PBR(12') Datura TVD= 8800'SS L-80 HY DRL 2135' H 9-5/8"HOWCO FO CEMENTER • a 563 XO TO TC11 . . 2660' H9-5/8"HOWCO FO CEMENTER 9-5/8"TIEBACK CSG,40#,L-80 TCI,ID=8.835" --I 2129' GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,N-80 BUTT,D=12.347' H 2700' 2 3795 3769 22 MMG DOME RK 16 05/26/12 • [9-5/8"HOWCO FO CEMENTER H 4212' 1 7638 6493 40 WAG SO RK 20 05/26/12 9425' H4-1/2"HES X NP,0=3.813" MINIMUM ID = 1.78" @ 9446' 9439' 43.70"DEPLOY SLV,D=3.00'1 MILLED OUT ALUMINUM BUSHING iii 9445' —H3-1/2"x 3"LNR XO,D=2.70" DEPLOYMENT SLEEVE - 9446' 225"DEPLOY SLV,D=1.78" I�� 1ALUMINUM BUSHING @9446'(MLLED OUT) 7'TBG STUB(TAGGED 07/08/07) H 9520' 1-- 9499' H 9-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" 1 9512' H4-1/2"HES X NP,D=3.813" BEHIND 4-1/2'TBG, 12.6#, 13CR-80 VAM TOP, H 9546' ^1.,.„ 9533' 4-1/2"HES XN NP,D=3.725" CT LINER .0152 bpf,D=3.958' 7"TBG,26#,N-80 AB-TC-4S, .0383 bpf,D=6.276" - 9559' 9646' —{4-1/2"HES WLEG,D=3.958" 9559' —19-5/8"X 7"BOT LTP w/40'PSR&HGR ID=7 I 9-518"CSG,47#,N-80 BUTT,D=8.681" H 10087' 1-4111 10435' —17"X 4-1/2"OTE VV)PKR,0=4.0' 3-3/16"LNR STUB(07/09/07) - 10435' I . BEHIND /l'i 10441' --14-1/2'OTIS X NP,D=3.813" i CT U NER 'I 10445' —4-1/2"OTIS XN NP,ID=3.800" I 7"MARKER JOINT H 11040' • (MLLED12/04/02) 10447' H 4-1/2"W/LEG,D=3.958" MLLOUT WINDOW(F-08A) 11066'- 11074' 7"LMR,29#,N-80 BUTT,.0371 bpf,D=6.184" H 11066 3-3/16"WHIPS OCK T / 1 `tits MLLOUT WINDOW(F-08B) 11086'- 11091' (05 02/ 2) H 11085 3-3116"LNR,6.2#,L-80, .0076 bpf,D=2.80" H 11101' PERFORATION SUMMARY REF LOG: SWS MCNL ON 05/13/12 ANGLE AT TOP PERF 92`@ 11870' Note.Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SI-OT SQZ 1.56" 6 11870- 11900 0 05/24/14 1 56" 6 11900- 11930 0 05/23/14 1.56" 6 11930- 11960 0 05/23/14 1 56" 6 12160- 12250 C 08/17/13 ' 12030' —I2-3/8"WFD CEP(05/22/14) 1 56" 6 12455- 12655 C 05/14/12 'NH 12573' HFISH:2-3/8'CEP MLLE)&PUSHED(05/21/14) MID H 12663' -----77 2-3/8"LNR,4.7#,L-80 STL, 0039 bpf,ID=1.995" -- 12701' 1.---4.. DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 09/08/76 INITIAL COMPLETION 05/30/12 RKT/JMD GLV C/O(05/26/12) WELL: F-08B 12/20/02 NORDIC 1 CTD SIDETRACK(F-08A) 08/13/12 AK/PJC FINAL DRLG CORRECTIONS PERMIT No °`2120400 07/14/07 N2ES RWO 09/04/13 ALMJMD SET CBP/ADFERFS(08/16-17/13) AR No- 50-029-20135-02 05/15/12 NORDIC 2 CTD SIDETRACK(F-088) J 05/27/14 RNWJMD SET CBR'MLL CBRADPERFS(5/24/14) SEC 2,T11N,R13E,2570'FN. &2403'FWL 05/18/12 PJC DRLG HO CORRECTIONS 05/19/12 PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) STATE OF ALASKA RECEIVED A AKA OIL AND GAS CONSERVATION COMM. .1ON SEP 0 5 2013 REPORT OF SUNDRY WELL OPERATIONS (� 1.Operations Abandon U Repair Well U Plug Perforations U Perforate Lf Other Li AOG CC Performed: Alter Casing ❑ Pull TubingO Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.ShutdownD Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ 212-040-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20135-02-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028281 t PBU F-08B • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 12701 feet Plugs measured 12410 feet true vertical 9018.83 feet Junk measured None feet Effective Depth measured 12410 feet Packer measured See Attachment feet true vertical 9017.65 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 81 20"94#H-40 20-101 20-101 1530 520 Surface 2681 13-3/8"72#N-80 19-2700 19-2699.86 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12160-12190 feet 12190-12220 feet 12220-12250 feet 12455-12655 feet True Vertical depth 9022.29-9022.92 feet 9022.92-9023.38 feet 9023.38-9023.8 feet 9017.55-9018.81 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 282 20251 10 0 991 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Q. Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG D GINJ ❑ SUSP ❑ SPLUCO 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.SummerhaVs(c�BP.Com Printed Name Nita Summerhaysi Title Petrotechnical Data Technician Signature /.WA Phone 564-4035 Date 9/4/2013 VI- RBDMS SEP - 9 2 4 `7/t 0/ /3 Form 10-404 Revised 10/2012 /I V I Submit Original Only Daily Report of Well Operations ADL0028281 CTU #3 1.5 Job Objective: Set CIBP/Addperfs. MIRU. Kill well down backside w/ 192 bbl 1% KCI w/SafeLube. RIH w/ drift BHA w/ 1.75" DJN. Tag PBTD at 12,675' CTM. POOH. RIH w/WFT MHA and PDS MGR/CCL to flag at 12662'. Log MGR/CCL to 9350' and paint flag at 12351'. POH 8/15/2013 ***Continued on 8/16/13 WSR*** CTU #3 w/ 1.5" CT(Cl V=23.2) Objective-GSO w/CIBP w/90' of add perfs Finish POH w/ PDS MGR/CCL. RIH w/WFT 2-3/8" CIBP assy and set at 12,410.0' mid-element(12,409.73'top of plug). POH. RIH with perf gun#1: SWS 1.56" PJ guns at 6 spf. Tag CIBP for depth correction. PUH and perforate from 12,220' - 12,250'. POH. RIH with perf gun #2: SWS 1.56" PJ guns at 6 spf. 8/16/2013 ***Continued on 8/17/13 WSR*** CTS/ 1.5" CT(Cl V=22.9) Objective-GSO w/CIBP w/90' add perfs Continue RIH w/ perf gun#2. Perforate 12190-12220'w/SWS 1.56" PJ guns at 6 spf. POH. RIH w/perf gun#3. Perforate 12160-12190' w/ SWS PJ guns at 6 spf. POH. RDMO to Z-05. ***Job Complete*** (well is S/I and freeze protected with 32 bbl 50/50 methanol, ready to 8/17/2013 POP) FLUIDS PUMPED BBLS 368 1% KLC WITH SAFELUBE 34 50/50 METH 402 TOTAL m Q o 0 o 0 0 0 0 0 0 N LU N O) CO f- O O 0 o N- CO lO l0 C N- M V 0 U) O 8 0 0 0 0 0 0 0 i M CO Lf) t- Cr) M V CO LO N — N- 00 O) t N m 00 L1') CO V' co f— 00 M LO 0) CO CO V r--- co �00 00 0) co co 0 0 M p co co co (A O CO CO N f� O LLO CO N- O O CO CO CO CS) CO N CO N f- N- CO F' co N- LO CO LO CO O) (A N N L!") co 00 C) N- Cvj 00 (- CO N CO ti co r N- N- N 4.0CD CO SC E - OCO (A000OO � O f� p N p V (A LO LO N N Cr) CA C) CO r• 0 4-1 2 fQ OD o M LO co (N CP N-CNA 0) ON M C p 0) 0) N rnC) O � J o 0 Q O p2Co 00 1:3) V Z cD co C Z CO fn IrU -I CA _ - N CO N_ N o (NJ N- ;.',1 - ON CO l) lOM N N N CA 6 t O �'- CO o <- 10 CO N CD N C co N LO — 0) CO LO N- <- J Et Z Z p O O w O f D p 0 LL Z_ Z_ Z U z w w O O W m m m OZZCCCCDDDD UJJafl. (nl- F- H Packers and SSV's Attachment ADL0028281 SW Name Type MD TVD Depscription F-08B PACKER 9488 7770.99 4-1/2" Baker S-3 Perm Packer F-08B PACKER 9559 7811.07 7" BOT Packer F-08B PACKER 10435 8353.4 4-1/2" Otis WD Packer (WELLHEAD= 13-5/8"Mc EVOY F_0 8 B Si 4-1/2"NOTES:RH O E TT ANGLE>70° 11315'. 'ACTUATOR= BAKER C INITIAL KB.ELE 54.8' 1 A 1 ��_ �, 20"CONDUCTOR H 101' ` 2072' H 9-5/8"HES CENAE�fTER itE. 94#,H-40, 4 KOP= 2700' '• �- 209T —14-1/2"HES X NP,D=3.813" 'Max Angle= 94"@ 11451' 0=19.124" Datum NC= 11053' 9-5/8"CSG,40#, H 615' - I 2106' 9-5/8"PBR(17) Datum TVD= 8800'SS L-80 HY DRL • 2135' H 9-5/8'HOVVCO FO CEMENTER •563 XO TO TC11 • • 2660' --19-5/8"HOWCO FO CE3NBVTBR 9-5/8'TIEBACK CSG,40#,L-80 TCI,ID=8.835' —1 2129' 4 GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,N-80 BUTT,D=12.347" —{ 2700' 2 3795 3769 22 WAS DOME RK 16 05/26/12 0 1 7638 6493 40 MAG SO RK 20 05/26/12 9-5/8"HOWCO FO CEMENTER H 4212' j 9425' —14-1/2"I tM X NP,D=3.813" 1 MINIMUM ID = 1.78" @ 9446' 9439'1-13.70"0B'LOY SLV,D=3.00'1 MILLED OUT ALUMINUM BUSHING iii.44 9445' H 3-1/2"X 3'LNR XO,ID=2.70' DEPLOYMENT SLEEVE I. 9446' 2.25"DEPLOY SLV,D=1.78" ALUMINUM BUSHING @9446'(MLLED OUT) 7"TBG STUB(TAGGED 07/08/07) —{ 9520' 9488' H 9-5/8"X 4-1/2'BKR S-3 PKID=3.875" NI I,9512' H4-1/2"HES X NP,D=3.813- BEHIND 4-1/2'TBG,12.6#,13CR-80 VAM TOP, —1 9546' -- = I 9533' —4-112"HES XN Nom,D=3.725" CT UNER .0152 bpf,D=3.958' 7'TBG,26#,N1-80 AB-TC-4S,.0383 bpf,D=6.276' — 9559' 9646' H4-1/2"HES WLEG,D=3.958" 1.14 9669' H 9-5/8"X 7'BOT LTP w/40'PBR 8 HGR,ID= 1 9-5/8'CSG,47#,N-80 BUTT,D=8.681" —1 10087' 10435' —{T X 4-1/2"OTIS VVD PKR,D=4.0' 3-3/16"LNR STUB(07/09/07) —{ 10436' j � BEHIND 10441' —14-1/2"011S X NP,D=3.813" ''i CT UN:'N 10445' 4-1/2"OTIS XN NIP,ID=3.800' (MLLED 12/04/02) 1044T 4-1/2"W/LEG,D=3.958" 7"MARKER JOINT —1 11040' MLLOUT WINDOW(F-08A) 11066'- 11074' 7"LHR,29#,N-80 BUTT,.0371 bpf,D=6.184" —i 11066' MLLOUT WINDOW(F-08B) 11086'- 11091' 3-3/16'WHIPSTOCK(05/02/12) H 11085' \ 3-3/16"LNR,6.2#,L-80,.0076 bpf,D=2.80' —f 11101' PERFORATION SUMMARY i REF LOG: SWS MCNL ON 05/13/12 _ ANGLE AT TOP PERF:89"@ 12160' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 1.56' 6 12160-12250 0 08/17/13 12410' —I 2-3/8"CEP(08/16/13) 1.56" 6 12455-12655 C 05/14/12 — PBTD H 12663' ----:=.'. 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf,ID=1.995" — 12701' 1----411-- DATE 1 .DATE REV BY COMY6'TTS DATE REV BY COMMENTS PRUDHOE BAY (1NT 09108/76 IMTIAL COMPLETION 05/30/12 RKT/JMD GLV G0(05/26/12) VVELL: F-08B 12/20102 NORDIC 1 CTD SIDETRACK(F-08A) 08/13/12 AK/PJC FINAL DRLG CORRECTIONS PERMT No: 2120400 07114/07 NZES RWO 09/04/13 ALMUMD SET CBP/ADPERFS(08/16-17/13) AR Nb: 50-029-20135-02 05115/12 NORDIC 2 CTD SIDETRACK(F-08B) SEC 2,T11N,R13E,2570'FM..&2403'FWL 05/18/12 PJC DRLG HO CORRECTIONS 05/19/12 PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) IITA BAKER PRINT DISTRIBUTION LIST o 6 2013 HUGHES AOGCC COMPANY BP Exploration(Alaska)Inc. INTERMEDIATE FINAL Yes (mandatory) 2_-o 2 WELL NAME RUN NUMBER 22-1 (mandatory) FIELD Prudhoe Bay BH SALESMAN Okechukwu(Okey)Anyanwu (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: TODAYS DATE: 5/31/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur NniN i S #OF COPIES #OF COPIES ' U U U U 1 BP Exploration(Alaska)Inc. I 3 I 1 I Petrotechnical Data Center LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 2 IConocePhillips Alaska Inc. I I 1 I +Attn Ricky Elgarico IPO Box 100360 Anchorage,Alaska 99510 I 3 lExxonMobil,Alaska I 1 I 1 I I IAttn Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 4 State of Alaska-AOGCC I I 1 I 1 I I Christine Shartzer 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 5DNR-Division of Oil&Gas r I I 1 I {Attn:Sean Clifton W 7th Ave,i 550 Suite 800 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 0 5 5 0 0 0 TOTALS FOR ALL PAGES: 0 5 5 0 0 0 ( ö ) bp Date 10-04-2012 0 Transmittal Number:93260 RECEf VEC BPXA WELL DATA TRANSMITTAL 0 C T 04 2012 Enclosed are the materials listed below. AOGCC (BPXA FIELD LOG DATA) If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 0r0707-22A ;%Z- 4"05.- 07-35A -35A ---Zr-- -.)e.)-7 13-15i4 �a G3 ' 1 /4 13-15APB1 Z —/2_6 �'vt/%� /= v� LZv ,5 , (- 13-15APB2 _'.041§AW"' c c=- - Z12.--c,-7Z; B-20A ,Z/2 D? C-01B • .I Z%2-mac C-01BPB1 C-27C 2-1 --�4Z (-08B 24Z O 4' ) C'i. —�Zoec4_ %ca u .--/------7•D �c�&-T EIz 2/(- (L6 AT 6./7- /3 Please Sign and Return one copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E.Benson Blvd.PO Box 196612 Anchorage,AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ® Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development• ❑Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One 0 Service 0 Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 5/15/2012 • 212-040 • 3. Address: 6.Date Spudded: 3 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 5(,412012 50-029-20135-02-00' 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 5/10/2012 • PBU F-08B • 2570'FNL,2877' FEL, Sec.02,T11 N, R13E, UM 8. KB(ft above MSL): 54 • 15.Field/Pool(s): Top of Productive Horizon: a;, 1206' FNL, 1197' FEL, Sec. 10,T11 N, R13E, UM GL(ft above MSL):31-3 tq Prudhoe Bay/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): 1277' FNL,2467' FEL, Sec. 10,T11 N, R13E, UM 12663' 9019' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 651959 • y- 5974230 • Zone- ASP4 • 12701' 9019'• ADL 028280&028281 TPI: x- 648443 y- 5970243 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 647175 • y- •►1 Zone- ASP4 None 18.Directional Survey: ® Y y i• s,„ 4 1Z 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD/GR/RES, GR/CCL/MCNL 11086' 8881' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM- TOP BOTTOM SIZE CEMENTING RECORD PULLED 30" 157.53# Conductor Surface 80' _Surface 80' 36" 135 sx Arctic Set 13-3/8" 72# N-80 Surface 2700' Surface 2700' 18-1/2" 3697 sx Permafrost II 9-5/8" 40#/47# L-80/N-80 Surface 10087' Surface 8174' 12-1/4" 1650 sx H9wco Liaht.200 sx Class'G' 7" 29# N-80 9559' 11066' 7866' 8865' 8-1/2" 752 sx Clas'0' 3-3/16" 6.2" L-80 10429' 11086'_ 8404' 8881' 3-3/4" 125 sx Class'G' 2-3/8" 4.7# L-80 9439' 12701' 7798' ,9019' 3" 48 sx Class'G' 24. Open to production or injection? ® Yes 0 No 25. TUBING RECORD If Yes,list each interval open (MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 1.56"Gun Diameter,6 spf 4-1/2", 12.6#, 13CR80/L-80 9546!10435'-10447' 9488'/7826', 10435'/8408', MD TVD MD TVD 7",26#, N-80 9520'-9596' 12455'-12655' 9018'-9019' /e 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. RE,CEI D DEPTH INTERVAL(MD) AMOUNT AND 2500' Freeze Protect w/45 BbIDs Diesel MATERIAL OF USED si 4-` JUN 0 $ 2012 - 17. AOGCC PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): May 28,2012 Gas Lift Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 6/1/2012 6 Test Period 4. 285 0 16 76 5598 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 250 700 24-Hour Rate 4 1138 0 63 26 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None IBDMS JUN 121012eiE QQu�o 0Form 10-407 Revised 12/2009 CONTINUED ON REVERSE .t. Z� �f� Original QY�ly 29. GEOLOGIC MARKERS(List all formations an jrkers encountered): 30. FORMATION TESTS NAME MD ND Well Tested? 0 Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 23SB/Zone 2B 11097' 8891' None 22TS 11162' 8942' 21 TS/Zone 2A 11233' 8987' Formation at Total Depth(Name): Zone 2A 11233' 8987' 31.List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the • -•oing is t - rrect to the best of my knowledge.A / Signed: Joe Lastufka 1i Title: Drilling Technologist Date: 1'!7 I I PBU F-08: 212-040 Prepared By Name/Number. Joe Lastufka, 564-4091 Well Number Permit No./Approval No. Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only WELL WELLHEAD= 13-5/8" fvtEVOY F_0 8 B SP 4-�r2NCHR0 ETBC ANGLE>70°@ 11315'. ACTUATOR= BAKER C KB. ELEV= 54.8' , -� BF. ELEV= 34,92' 20"CONDUCTOR —1 101' 1 2072' —{9-518"HES CEMENTER 94 '��. 2097' —14-1/2"HES X NIP,ID=3.813" 2700' KOP= si :• Max Angle= 94'©11451' ID=19.124" 4 a Datum MD 11053' 9-5/8"CSG,40#, 615' 1 2106' —19-5/8"PBR(12') [tum TVD= 8800'SS L-80 HYDRIC 2135' —19-5/8"HOWCO FO CEMENTER 563 XO TO TC11 . • 2660' --I9-5/8"HOWCO FO CEMENTER 9-5/8"TIEBACK CSG,40#, L-80 TCII,ID=8.835" — 2129' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-318"CSG,72#,N-80 BUTT,ID=12.347" H 2700' 2 3795 3769 22 MMG DOME RK 16 05/26/12 • 1 7638 6493 40 MMG SO RK 20 05/26/12 9-5/8"HOWCO FO CEMENTER -I 4212' [ r 9425' —14-1/2"HES X NIP, ID=3.813" MINIMUM ID = 1.78" @ 9446' 1 9439' —13.70"DEPLOY SLV, ID=3.00" MILLED OUT ALUMINUM BUSHING iii 9445' —13-1/2"X 3"LNR XO,ID=2.70" DEPLOYMENT SLEEVE 9446' --3"DEPLOY SLV, ID=2.25" 111 ALUMINUM BUSHING©9452'(MILLED OUT) 7"TBG STUB(TAGGED 07/08/07) 9520' 9488' H9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" I h 9512' —141/2"HES X NIP,ID=3.813" BEHIND I 4-1/2"TBG,12.6#,13C R-80 VAM TOP, —{ 9546' ' 9533' —4-1/2"HES XN NIP, ID=3.725' CT LINER .0152 bpf,ID=3.958" 9646' —14-1/2"HES WLEG,ID=3.958" 7"TBG,26#,N-80 A B-TC-4S, .0383 bpf, ID=6.276" H 9559' 7.• 9669' —19-5/8"X 7"BOT LTP w/40'PBR&HGR,ID=? l 41I\ 9-5/8"CSG,47#,N-80 BUTT, ID=8.681" —{ 10087' 10435' —17"X 4-1/2"OTIS WD PKR, ID=4.0" I 3-3/16"LNR STUB(07/09/07) H 10435' . BEHIND Ci 10441' 4112"OTIS X NIP,ID=3.813" CT LINER I ' 10445' —4-1/7 OTIS XN NIP,ID=3.800" (MILLED 12/04/02) 10447' —14-1/2'W/LEG, ID=3.958" 7"MARKER JOINT — 11040' MILLOUT WNDOW(F-08A) 11066'-11074' t tit 7"LNR,29#,N-80 BUTT,.0371 bpf, ID=6.184" H 11066' MILLOUT WINDOW(07-08B) 11086'-11091' 3-3/16"WHIPSTOCK(05/02/12) —1 11085' 3-3/16"LNR,6.2#, L-80,.0076 bpf, ID=2.80" H 11101' PERFORATION SUMMARY t REF LOG: SWS MCNL ON 05/13/12 ANGLE AT TOP PERF:90"@ 12455' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE - `r. 1.56" 6 12455-12655 0 05/14/12 PBTD —1 12663' — 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf, ID=1.995" —, 12701' 41__, F-028 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09108176 INITIAL COMPLETION 05/30/12 RKT/JMD GLV CIO(05/26/12) WELL' F-08B 12/20102 NORDIC 1 CTD SIDETRACK(F-08A) F1iMIT No: `2120400 07114107 N2ES MVO API No: 50-029-20135-02 05115112 NORDIC 2 CTD SIDETRACK(F-08B) SEC 2,T11 N,R13E,2570'FNL&2403'FWL 05/18/12 PJC DRLG HO CORRECTIONS 05/19/12 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alas ka) 111111111 BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB F Pad F-08 - Slot 08 / Lat: 070°20'11.829"9 Long: 0148°46'01.316"W F-08B Survey: MWD Survey Report - Geographic 11 May, 2012 vI bp BAKER HUGHES Survey Report-Geographic0 INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-08-Slot 08 Project: Prudhoe Bay TVD Reference: ORIG KELLY BUSHING @ 54.80ft Site: PB F Pad MD Reference: ORIG KELLY BUSHING @ 54.80ft Well: F-08 North Reference: True Wellbore: F-08B Survey Calculation Method: Minimum Curvature Design: F-08B Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB F Pad,TR-11-13 Site Position: Northing: 5,972,527.29ft Latitude: 70°19'55.283 N From: Map Easting: 650,960.70ft Longitude: 148°46'31.468 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.15 ° Well F-08 API No 500292013500 Well Position +N/-S 0.00 ft Northing: 5,974,230.00 ft • Latitude: 70°20'11.829 N +E/-W 0.00 ft Easting: 651,959.00ft - Longitude: 148°46'1.316 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 39.30ft • Wellbore F-08B API No 500292013502 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°I (°l (nT) BGGM2011 5/3/2012 21.00 81.04 57,659 Design F-08B Audit Notes: Version: Phase: ACTUAL Tie On Depth: 11,053.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) 11 19.30 0.00 0.00 230.66 Survey Program Date: 5/11/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 11,053.00 1 :Camera based mag multi sho(F-08) CB-MAG-MS Camera based mag multi shot 11,053.00 11,053.00 MWD(F-08A) MWD MWD-Standard 11,085.65 12,701.00 MWD(F-08B) MWD MWD-Standard 5/11/2012 9:03:29AM Page 2 COMPASS 2003.16 Build 73 BAKER 0 by HUGHES Survey Report-Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-08-Slot 08 Project: Prudhoe Bay TVD Reference: ORIG KELLY BUSHING @ 54.80ft Site: PB F Pad MD Reference: ORIG KELLY BUSHING @ 54.80ft Well: F-08 North Reference: True Wellbore: F-08B Survey Calculation Method: Minimum Curvature Design: F-08B Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 11,053.00 39.24 246.30 8,854.53 -3,924.83 -3,477.95 5,970,235.79 648,561.55 70°19'33.221 N 148°47'42.837 W TIP 11,085.65 32.13 257.17 8,881.06 -3,930.92 -3,495.91 5,970,229.34 648,543.71 70°19'33.161 N 148°47'43.361 W KOP 11,120.46 36.47 268.05 8,909.84 -3,933.33 -3,515.30 5,970,226.54 648,524.37 70°19'33.137 N 148°47'43.927 W 11,150.52 40.80 275.54 8,933.33 -3,932.69 -3,534.03 5,970,226.80 648,505.64 70°19'33.143 N 148°47'44.473 W 11,180.02 46.85 282.37 8,954.61 -3,929.45 -3,554.16 5,970,229.63 648,485.45 70°19'33.175 N 148°47'45.061 W 11,210.34 53.81 288.66 8,973.97 -3,923.15 -3,576.60 5,970,235.47 648,462.89 70°19'33.237 N 148°47'45.716 W 11,240.34 60.39 294.89 8,990.26 -3,913.77 -3,599.94 5,970,244.38 648,439.37 70°19'33.329 N 148°47'46.398 W 11,270.06 60.89 301.68 9,004.85 -3,901.51 -3,622.73 5,970,256.18 648,416.34 70°19'33.449 N 148°47'47.063 W 11,299.84 67.19 307.85 9,017.89 -3,886.23 -3,644.68 5,970,271.01 648,394.09 70°19'33.599 N 148°47'47.704 W 11,330.27 74.27 313.17 9,027.93 -3,867.56 -3,666.47 5,970,289.22 648,371.92 70°19'33.783 N 148°47'48.340 W 11,360.12 81.31 308.05 9,034.24 -3,848.61 -3,688.61 5,970,307.73 648,349.40 70°19'33.969 N 148°47'48.987 W 11,390.48 87.36 298.92 9,037.25 -3,831.97 -3,713.78 5,970,323.85 648,323.90 70°19'34.133 N 148°47'49.722 W 11,420.31 92.09 302.07 9,037.39 -3,816.84 -3,739.47 5,970,338.45 648,297.91 70°19'34.281 N 148°47'50.472 W 11,450.50 93.56 307.37 9,035.90 -3,799.68 -3,764.24 5,970,355.11 648,272.80 70°19'34.450 N 148°47'51.195 W I 11,480.21 92.73 312.93 9,034.27 -3,780.56 -3,786.91 5,970,373.77 648,249.75 70°19'34.638 N 148°47'51.857 W 11,510.31 90.21 313.95 9,033.50 -3,759.87 -3,808.76 5,970,394.01 648,227.49 70°19'34.841 N 148°47'52.495 W 11,540.25 89.85 308.96 9,033.48 -3,740.05 -3,831.19 5,970,413.36 648,204.66 70°19'35.036 N 148°47'53.150 W 11,570.88 90.34 304.33 9,033.43 -3,721.78 -3,855.76 5,970,431.14 648,179.73 70°19'35.216 N 148°47'53.868 W 11,602.49 92.24 299.84 9,032.72 -3,704.99 -3,882.52 5,970,447.37 648,152.63 70°19'35.381 N 148°47'54.649 W 11,631.88 92.33 294.46 9,031.55 -3,691.60 -3,908.64 5,970,460.23 648,126.25 70°19'35.512 N 148°47'55.412 W 11,662.68 89.57 293.00 9,031.04 -3,679.21 -3,936.83 5,970,472.05 648,097.81 70°19'35.634 N 148°47'56.235 W 11,691.44 92.33 298.41 9,030.56 -3,666.74 -3,962.73 5,970,483.99 648,071.67 70°19'35.756 N 148°47'56.991 W 11,723.74 90.86 295.12 9,029.66 -3,652.20 -3,991.56 5,970,497.94 648,042.56 70°19'35.899 N 148°47'57.833 W 11,750.66 90.77 290.76 9,029.28 -3,641.71 -4,016.34 5,970,507.92 648,017.57 70°19'36.002 N 148°47'58.556 W 11,787.22 90.83 284.77 9,028.77 -3,630.57 -4,051.14 5,970,518.36 647,982.56 70°19'36.112 N 148°47'59.572 W 11,814.43 88.74 280.41 9,028.87 -3,624.64 -4,077.68 5,970,523.75 647,955.90 70°19'36.170 N 148°48'0.347 W 11,847.39 89.63 275.73 9,029.34 -3,620.01 -4,110.30 5,970,527.71 647,923.19 70°19'36.215 N 148°48'1.300 W 11,880.50 92.42 271.68 9,028.74 -3,617.87 -4,143.33 5,970,529.18 647,890.13 70°19'36.236 N 148°48'2.264 W 11,910.66 92.77 265.77 9,027.38 -3,618.54 -4,173.44 5,970,527.90 647,860.05 70°19'36.229 N 148°48'3.143 W 11,941.08 89.75 259.74 9,026.71 -3,622.38 -4,203.59 5,970,523.46 647,829.98 70°19'36.191 N 148°48'4.023 W 11,970.50 91.66 253.87 9,026.35 -3,629.09 -4,232.22 5,970,516.17 647,801.50 70°19'36.125 N 148°48'4.858 W 12,002.08 91.63 248.51 9,025.44 -3,639.26 -4,262.09 5,970,505.39 647,771.84 70°19'36.025 N 148°48'5.730 W 12,031.02 92.36 243.47 9,024.43 -3,651.03 -4,288.50 5,970,493.10 647,745.68 70°19'35.909 N 148°48'6.501 W 12,062.20 91.47 236.36 9,023.39 -3,666.64 -4,315.45 5,970,476.94 647,719.05 70°19'35.756 N 148°48'7.287 W 12,090.64 91.69 241.12 9,022.60 -3,681.39 -4,339.74 5,970,461.71 647,695.06 70°19'35.610 N 148°48'7.996 W 12,120.47 90.58 246.23 9,022.01 -3,694.61 -4,366.46 5,970,447.95 647,668.62 70°19'35.480 N 148°48'8.776 W 12,150.05 89.02 249.84 9,022.11 -3,705.67 -4,393.89 5,970,436.33 647,641.42 70°19'35.371 N 148°48'9.576 W 12,180.73 88.71 245.58 9,022.72 -3,717.30 -4,422.26 5,970,424.13 647,613.29 70°19'35.257 N 148°48'10.405 W 12,210.89 89.26 242.70 9,023.26 -3,730.45 -4,449.40 5,970,410.43 647,586.43 70°19'35.127 N 148°48'11.196 W 12,240.03 89.08 238.23 9,023.68 -3,744.81 -4,474.74 5,970,395.56 647,561.39 70°19'34.986 N 148°48'11.936 W 12,271.68 90.58 234.15 9,023.77 -3,762.42 -4,501.03 5,970,377.43 647,535.46 70°19'34.812 N 148°48'12.703 W, 12,300.35 91.38 230.70 9,023.28 -3,779.90 -4,523.75 5,970,359.50 647,513.10 70°19'34.640 N 148°48'13.366 W 12,332.56 94.88 232.22 9,021.52 -3,799.93 -4,548.90 5,970,338.96 647,488.36 70°19'34.443 N 148°48'14.100 W 12,375.67 92.40 238.19 9,018.78 -3,824.47 -4,584.21 5,970,313.71 647,453.56 70°19'34.202 N 148°48'15.130 W 12,401.43 91.69 243.67 9,017.86 -3,836.97 -4,606.70 5,970,300.76 647,431.33 70°19'34.079 N 148°48'15.786 W', 12,433.99 89.75 246.80 9,017.46 -3,850.61 -4,636.26 5,970,286.53 647,402.05 70°19'33.944 N 148°48'16.649 W 12,461.11 89.69 250.50 9,017.59 -3,860.48 -4,661.52 5,970,276.15 647,377.01 70°19'33.847 N 148°48'17.386 W 12,490.87 90.55 247.11 9,017.53 -3,871.24 -4,689.26 5,970,264.83 647,349.49 70°19'33.741 N 148°48'18.195 W', 12,520.83 90.34 243.11 9,017.29 -3,883.84 -4,716.43 5,970,251.68 647,322.58 70°19'33.617 N 148°48'18.988 W' 12,550.15 89.32 240.78 9,017.38 -3,897.63 -4,742.30 5,970,237.37 647,296.99 70°19'33.481 N 148°48'19.743 W 12,583.30 89.66 237.06 9,017.68 -3,914.74 -4,770.69 5,970,219.69 647,268.96 70°19'33.313 N 148°48'20.572 W 12,613.85 88.06 233.84 9,018.28 -3,932.06 -4,795.84 5,970,201.86 647,244.17 70°19'33.142 N 148°48'21.305 W 12,643.98 89.97 230.42 9,018.80 -3,950.55 -4,819.62 5,970,182.90 647,220.77 70°19'32.960 N 148°48'21.999 W 5/11/2012 9:03:29AM Page 3 COMPASS 2003.16 Build 73 P11 bp BAKER 0 HUGHES Survey Report-Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-08-Slot 08 Project: Prudhoe Bay TVD Reference: ORIG KELLY BUSHING @ 54.80ft Site: PB F Pad MD Reference: ORIG KELLY BUSHING @ 54.80ft Well: F-08 North Reference: True Wellbore: F-08B Survey Calculation Method: Minimum Curvature Design: F-08B Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 12,701.00 89.97 230.42 9,018.83 -3,986.88 -4,863.57 5,970,145.69 647,177.57 70°19'32.603 N 148°48'23.281 W - TO-2 3/8" 5/11/2012 9:03:29AM Page 4 COMPASS 2003.16 Build 73 North America -ALASKA- BP Page 1 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C:(2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 3/24/1974 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°46'01.316"W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 4/30/2012 06:00 - 09:00 3.00 MOB P PRE BEGIN RON EVENT FOR NORDIC 2 AT 06:00 ON 4/30/2012. STAGE RIG ON DS15-09 WHILE MAKING FINAL PREPARATIONS FOR RIG MOVE. 09:00 - 17:00 8.00 MOB P PRE MOVE RIG 12 MILES FROM DS 15 TO F PAD. 17:00 - 19:00 2.00 MOB P PRE STAGE RIG ON F PAD. CREWS COMPLETE CHANGEOUT. FINALIZE RIG MAT PLACEMENT AROUND F-08 WELL. 19:00-UPDATE AOGCC REPRESENTATIVE BOB NOBLE WITH INTENTION TO TEST BOPE AT 01:00 5/1/2012. MR. NOBLE WAIVES STATE'S RIGHT TO WITNESS BOP TEST UNLESS TESTING BEGINS AFTER 6 AM ON i 5/1/2012. 19:00 - 20:00 1.00 MOB P PRE DHD ON LOCATION TO BLEED DOWN OA. PRESSURE BLEEDS FROM 200 PSI TO 0 PSI IN SECONDS. MONITOR BUILD UP. PRESSURE GAINS 12 PSI IN FINAL 15 MIN OF 30 MIN PERIOD. 20:00 - 21:00 1.00 MOB P PRE HOLD PJSM AND SPOT RIG OVER F-08 WELL. -ALL TREE AND WELLHEAD VALVES CONFIRMED CLOSED. -WELLWORK TRANSFER PERMIT OPEN WITH PAD OPERATOR. -TBG=TWC, IA=31 PSI,OA=32 PSI -F PAD OPERATOR DECLINES WITNESS FOR PULLING RIG OVER WELL. 21:00 - 22:00 1.00 RIGU P PRE ACCEPT RIG AT 21:00 ON 4/30/2012. SHORE UP CELLAR AREA. SPOT CUTTINGS BOX. 22:00 - 23:00 1.00 RIGU P PRE GENERAL RIG UP OPERATIONS. TAKE CONTROL OF SSV WITH PANEL IN SLB OPS CAB. FUNCTION TEST(VALVE CLOSES WITH PROPER 4.5"STEM EXPOSED). OPEN AND CLOSE SWAB VALVE TO CONFIRM 23 CORRECT TURNS TO FUNCTION. 23:00 - 00:00 1.00 BOPSUR P PRE PRESSURE TEST SWAB CAP AGAINST CLOSED SWAB VALVE AND SSV TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS,SEE ATTACHED CHART). • DOUBLE BARRIERS ESTABLISHED FOR BREAKING CONTAINMENT TO NIPPLE UP BOPS. REMOVE TREE CAP AT SWAB CAP FLANGE. Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 2 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°46'01.316"W _ Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) (ft) 5/1/2012 00:00 - 01:30 1.50 BOPSUR P PRE SET BOP STACK ON CAMERON 4-1/8"TREE. NIPPLE UP BOPS TO SWAB FLANGE WITH FOLLOWING STACK CONFIGURATION: -7-1/16"HYDRIL GK ANNULAR PREVENTER -TOT BLIND-SHEAR RAMS -TOT 2-3/8"COMBI PIPE SLIP/RAMS -MUD CROSS WITH 2-1/16"MANUAL GATE VALVES+4-1/16"HCR VALVES ON BOTH CHOKE AND KILL LINES -TOT 2-3/8"X 3-1/2"VB RAMS -TOT 2-3/8"COMBI PIPE SLIP/RAMS. SPOT SATELLITE CAMP AND AUXILLARY EQUIPMENT. RIG UP FLOWBACK TANK AND 'HARDLINE. 01:30 - 02:00 0.50 BOPSUR P PRE RIG UP GOOSENECK. 02:00 - 03:00 1.00 BOPSUR P PRE INSTALL LUBRICATOR AND PACKOFF ASSEMBLY. RIG UP INJECTOR. 03:00 - 08:00 5.00 BOPSUR P PRE PULL NEW 2-3/8"COIL FROM REEL HOUSE OVER TO RIG FLOOR AND SECURE IN INJECTOR. GET SHELL TEST ON BOPS. BEGIN BOP TEST. TEST WITNESS WAS WAIVED BY BOB NOBLE WITH AOGCC. 08:00 - 11:30 3.50 BOPSUR P PRE CONTINUE PRESSURE TEST BOPS. TEST ALL CHOKE VALVES. TEST ANNULAR PREVENTER, BLIND/SHEAR, UPPER AND LOWER PIPE SLIP RAMS AND VBR RAMS. NO FAILURES. TEST 2 TIW VALVES. 11:30 - 12:00 0.50 BOPSUR P PRE PERFORM RIG EVAC EXERCISE WITH HIGH LEVEL H2S ALARM. ALL PERSONNEL MUSTER AT THE PRIMARY MUSTER POINT AND ARE ACCOUNTED FOR IN 2 MIN. CONDUCT AAR FOLLOWING THE DRILL. 12:00 - 13:00 j 1.00 BOPSUR P PRE PICK UP INJECTOR AND TEST THE E-LINE, DOESN'T PASS. TROUBLESHOOT IN REEL. UNHOOK CABLE FROM BULKHEAD,STILL DOESN'T TEST. 13:00 - 14:30 1.50 BOPSUR N PRE DISCUSS WITH SLB CTS MANAGEMENT IN DEADHORSE. BAD SPOT IN CABLE IS SUSPECTED CLOSE TO THE BULKHEAD. DECIDE TO BREAK DOWN THE REMAINING E-LINE IRON IN THE REEL TO EXPOSE AS MUCH ELINE AS POSSIBLE TO FIND THE BAD SPOT. PJSM FOR WORKING INSIDE REEL. EXPOSE 3 FT OF WIRE IN THE REEL AND CUT IT OFF. RE-TEST IS GOOD. 14:30 - 20:00 5.50 BOPSUR N PRE PUMP BACKWARDS TO FILL REEL AND PUSH SLACK TOWARDS REEL, NEED ANOTHER 2-3 FT OF CABLE TO MAKE UP BULKHEAD GET REQUIRED CABLE AND MU BULKHEAD AGAIN. CONDUCTIVITY TEST AND CABLE GOOD. 20:00 - 21:30 1.50 BOPSUR P PRE PJSM,MAKE UP BAKER SLIM CONNECTOR. PULL TEST SAME. PRESSURE TEST _ CONNECTOR TO 250/3500 PSI. 21:30 - 22:00 0.50 BOPSUR P PRE PRESSURE TEST INNER REEL VALVE AND PACK-OFF TO 250/3500 PSI,GOOD TEST Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 3 of 13 Operation Summary Report Common Well Name: F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 3/24/1974 12:00:OOAM ,Rig Release: Rig Contractor:NORDIC CALISTA UWI:/Lat:070°2011.829"9 Long: 10148°4601.316'W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 23:00 0.50 BOPSUR P PRE PUMP SLACK FORWARD @3.8BPM MEG TEST E-LINE,GOOD 23:00 - 00:00 1.00 BOPSUR P PRE INSTALL BHI DUAL FLAPPER CHECK VALVE AND PRESSURE TEST SAME TO 250/3500 PSI 5/2/2012 00:00 - 02:00 2.00 BOPSUR P PRE PJSM WITH VAVLE CREW TO PULL TWC. MU LUBRICATOR AND PRESSURE TEST SAME TO 250/3500 PSI AGAINST CLOSED SWAB,SSV AND MASTER 02:00 - 03:00 1.00 BOPSUR P PRE OPEN SWAB,SSV AND MASTER VALVES. PULL TWC,WELL ON VAC TWC RECOVERED MISSING 0-RING,LIKELY LOST DOWNHOLE DUE TO VAC. CLOSE MASTER AND SWAB. 03:00 - 04:20 ' 1.33 BOPSUR P PRE RIG UP TO BULLHEAD FILL STACK WITH MEOH,STAB INJECTOR, TEST QTS TO 250/3500 PSI. OPEN MASTER AND SWAB 04:20 - 05:30 1.17 BOPSUR P PRE BULLHEAD WELL WITH 8.4 PPG KCL,2.5 BPM DOWN COIL,2 BPM DOWN KILL LINE FOR 4.5 BPM TOTAL PUMP RATE AT 2200 PSI AND 290 BBLS PUMPED 05:30 - 07:00 1.50 BOPSUR P PRE FLOW CHECK WELL FOR 30 MIN. FILL WELL ACROSS TOP AND ASSESS LOSS RATE. ABOUT 20-25 BBUHR. 07:00 - 08:20 1.33 BOPSUR P PRE DISCUSS WITH CTD SUPT AND ODE. DECISION IS MADE TO INCLUDE JARS IN THE DRIFT RUN DUE TO LOST 0-RING WHEN PULLING TWC. 08:20 - 08:30 0.17 STWHIP P WEXIT JARS ON LOCATION. PJSM FOR M/U DRIFT BHA. 08:30 - 09:00 0.50 STWHIP P j WEXIT M/U BHA#1 -WHIPSTOCK DRIFT WITH JARS, 2-3/8"COILTRAK. BHA OAL=64.34 FT. 09:00 - 11:40 2.67 STWHIP P WEXIT RIH WITH BHA#1. UP WT AT 10400 FT IS 42K. 11:40 - 13:00 1.33 STWHIP P WEXIT TIE IN DEPTH FROM 10535 FT. CORRECT-38 FT. LOG ANOTHER GR PEAK AT 10850 FT TO CONFIRM,ZERO CORRECTION. 13:00 - 13:25 0.42 STWHIP P WEXIT CONTINUE RIH WITH WHIPSTOCK DRIFT. SLOW DOWN AND ZERO DWOB AT 11090 FT. LOOK FOR A TAG. TAG AT 11104 FT WITH PRESSURE INCREASE 6K ON DWOB. PICK UPWITH SLIGHT OVERPULL TO 11050 FT AND TRY AGAIN. ZERO DWOB AND RIH 10 FT/MIN FROM 11050 FT. INCREASE IN DWOB OF LESS THAN 100 LB DOWN TO 11101 FT. STOP THERE SO AS NOT TO TAG THE XO AGAIN. 13:25 - 15:30 2.08 STWHIP P WEXIT PICKUP OFF BOTTOM AND FLOW CHECK FOR 5 MIN. FLOW CHECK IS GOOD. POOH. 15:30 - 18:00 2.50 STWHIP P WEXIT UD WHIPSTOCK DRIFT AND JARS. M/U BHA#2-WHIPSTOCK AND 2-3/8" COILTRAK. Printed 5/29/2012 10:23:06AM North America-ALASKA- BP Page 4 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site: PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWt/Lat:070°20'11.829"9 Long: 0148°46'01.316'W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 18:00 - 21:00 3.00 STWHIP P WEXIT RIH WITH WHIPSTOCK AT 75 FPM SLOWING DOWN TO 10 FPM AT ALL JEWELRY. 13 BPH LOSSES WHILE PUMPING AT 0.45 BPM THROUGH OPEN EDC. IAP=5 PSI,OAP=215 PSI 21:00 - 21:15 0.25 STWHIP P WEXIT ORIENT WHIPSTOCK FACE TO 62 ROHS AT 10,050'MD.PUW AT 10,300'MD=45K 21:15 - 21:45 0.50 STWHIP P WEXIT TIE-IN AT 10,900'MD WITH A(-38') CORRECTION 21:45 - 22:00 0.25 STWHIP P WEXIT RIH TO SETTING_DEPTH OF 11085'MD T4P OF WHIPSTOCK. VERIFY WS ORIENTATION OF 62 DEG ROHS. J�� SET TRIPS ON PUMP TO 4000 PSI,CLOSE EDC WHIPSTOCK SET AT 3400 PSI AND WOB OF 3K ALONG WITH FULL RETURNS CONFIRMED SET. 22:00 - 22:10 0.17 STWHIP P WEXIT PULL UP OUR OF WS,FLOW CHECK WELL FOR 5 MIN, CLOSE EDC. 22:10 - 00:00 1.83 STWHIP P WEXIT POH AT 80 FPM WHILE CIRCULATING 1.5 BPM AT 2050 PSI TO 3200'MD, 5/3/2012 00:00 - 00:30 0.50 STWHIP P WEXIT POOH FROM 3200'MD TO 67'MD TOTAL OF 2 BBLS LOST TO FORMATION DURING POH. 00:30 - 01:15 0.75 STWHIP P WEXIT PJSM WHILE FLOW CHECKING WELL UNSTAB INJECTOR AND SLOWLY COME UP TO CONNECTOR SINCE SLIMHOLE BHA LAY DOWN WS RUNNING BHA 01:00 - 01:30 0.50 STMILL P WEXIT RIG EVAC DRILL ALL HANDS ACCOUNTED FOR INCLUDING 4 TRUCK DRIVERS AND BTT REPS FOLLOW WITH AAR 01:45 - 02:15 0.50 STMILL P WEXIT PICK UP WINDOW MILLING BHA#3 WITH HC 2.74"WINDOW MILL,HC 2.74"STRING REAMER, STRAIGHT MOTOR,2 JTS CSH, COILTRAK. VERIFY GUAGE ON MILL AND REAMER,2.75" GO,2.74"NO-GO. 02:15 - 02:30 0.25 STMILL P WEXIT STAB INJECTOR AND TEST QTS TO 250/3500 PSI. 02:30 - 07:30 5.00 STMILL P WEXIT RIH TO TIE-IN DEPTH—10,900' SWAP WELL TO MUD THROUGH OPEN EDC. 07:30 - 08:00 0.50 STMILL P WEXIT GET SPP AT 11080 FT AFTER WELL IS SWAPPED TO MUD. 08:00 - 08:30 0.50 STMILL P WEXIT TAG WHIPSTOCK AND START MILLING WINDOW. TIME MILL THE FIRST 1 FT. 08:30 - 08:40 0.17 STMILL P WEXIT CONTINUE MILLING WINDOW FROM A PINCH POINT OF 11085.5 FT. 08:40 - 09:00 0.33 STMILL P WEXIT STALL AT THE END OF A TIME STEP AT 11085.9 FT. CLEAN PICKUP,START 0.2 FT HIGHER UP. 09:00 - 10:00 1.00 STMILL P WEXIT MILLING WINDOW AT 11086.0 FT. DWOB= 1.86KLBS. CIRC PRESSURE=3020 PSI. BLEED IA FROM 750 PSI TO 120 PSI. 10:00 - 11:00 1.00 STMILL P WEXIT MILL WINDOW AT 11086.6 FT. DWOB= 3.09KLBS. CIRC PRESSURE=3259 PSI. 11:00 - 12:15 1.25 STMILL P WEXIT MILL WINDOW AT 11087.1 FT. DWOB= 2.90KLBS. CIRC PRESSURE=3333 PSI. Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 5 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°4601.316"W Active Datum:ORIG KELLY BUSHING©54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:15 - 13:05 0.83 STMILL P WEXIT MILL WINDOW AT 11088.0 FT. DWOB=1.11 KLBS. CIRC PRESSURE=3164 PSI. 13:05 - 14:50 1.75 STMILL P WEXIT MILL WINDOW AT 11088.91 FT. DWOB=1.30 KLBS. CIRC PRESSURE=3060 PSI 14:50 - 15:30 0.67 STMILL P WEXIT MILL WINDOW AT 11090.4 FT. DWOB= 1.40KLBS. CIRC PRESS E -3090 PSI. 15:30 - 16:30 1.00 STMILL P WEXIT LIKELY CASING EXIT •T 11090.: FT. CONTINUE TIME MILL ' - •. HER 1 FT TO ALLOW THE STRING REAMER TO WORK. 16:30 - 18:30 2.00 STMILL P WEXIT MILL RATHOLE AT 5-10 FT/HR WITH 2K DWOB V,. TO 11101'MD. SAMPLE FROM 11091 FT IS 25%FORMATION. 111(1-/ 18:30 - 20:00 1.50 STMILL P WEXIT DRESS WINDOW BY BACKREAMING UP .Y THROUGH WIDOW FOLLOWED BY 3 PASSES AT 1 FPM WHILE CIRCULATING. (J�3 20:00 - 20:30 0.50 STMILL P WEXIT DRY DRIFT WINDOW 20:30 - 20:45 0.25 STMILL P WEXIT FLOW CHECK WELL,NO FLOW 20:45 - 23:00 2.25 STMILL P WEXIT POH WITH WINDOW MILLING BHA AT 70 FPM PUMPING 3BPM @ 3710 PSI WITH EDC OPEN. 23:00 - 23:20 0.33 STMILL P WEXIT FLOW CHECK AT 500'MD PRIOR TO PULLING BHA THROUGH STACK. 23:20 - 00:00 0.67 STMILL P WEXIT PJSM, LD MILLING BHA,MINIMAL WEARON MILLS,WINDOW MILL AND STRINGMILL GUAGED AT 2.74 GO,2.73 NO-GO. 5/4/2012 00:00 - 01:00 1.00 STWHIP P WEXIT LAY DOWN MILLING BHA AND GAUGE. WINDOW MILL GAUGED AT 2.73,STRING MILL AT2.74,MINIMAL WEAR 01:00 - 01:45 0.75 DRILL P PROD1 PJSM,SIMULATE CIRCULATING OUT KICK THROUGH MUD GAS SEPARATOR USING THE SUPERCHOKE, PUMPED 1 BPM WHILE PERFORMING DRILL.AAR HELD TO DISCUSS EFFICIENCY FOR WHEN THIS OPERATION MIGHT BE NEEDED AT COLDER TEMPS 01:45 - 04:00 2.25 DRILL P PROD1 PJSM,CUT AND SLIP DRILLING LINE,50', HOLD AAR 04:00 - 05:00 1.00 DRILL P PROD1 PJSM,MU BUILD SECTION BHA#4 WITH 1.6 DEG MOTOR AND 2.7"X 3"HCC BIT 05:00 - 06:00 1.00 DRILL P PROD1 RIH WITH BUILD BHA 06:00 - 06:30 0.50 DRILL P PROD1 CONTINUE RIH WITH BUILD BHA. 06:30 - 07:10 0.67 DRILL P PROD1 CONTINUE RIH WITH 1.6 DEG BUILD ASSEMBLY. 07:10 - 07:40 0.50 DRILL P PROD1 TIE IN DEPTH FROM 10900 FT. CORRECT-38 FT. PASS THROUGH WINDOW AT 60R ORIENTATION. 07:40 - 12:30 4.83 DRILL P PROD1 START DRILLING SLOWLY FROM 11101 FT. AVERAGE ROP IS 20-40 FT/HR WITH 1-2K DWOB. DRILL AT 45R INITIALLY TO GAIN SEPARATION FROM PARENT WELL. 12:30 - 13:10 0.67 DRILL P PROD1 CONTINUE DRILLING PAST 11230 FT. PUMP 20 BBLS HI-VIS PILL. DRILL TO 11250 FT. Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 6 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:0O:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°46'01.316'W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:10 - 18:00 4.83 DRILL P PROD1 WIPER TRIP FROM 11250 FT ABOVE WINDOW FOR TIE IN. PULL THROUGH WINDOW AND PERFORM A JOG HERE, THEN OPEN EDC. PUMP 2.72 BPM @ 3900 PSI THROUGH OPEN EDC. TIE IN DEPTH AT TSGR(+1.5')THEN LOG PAST RA MARKER. 18:00 - 19:30 1.50 DRILL P PROD1 CONTINUE DRILLING BUILD FROM 11250'TO 11270' PUMPING 1.5 BPM IN/OUT,2670 CIRC PRESSURE,1K WOB,8.7 PPG MUD,10.4 PPG ECD, IAP 370 PSI,OAP 210 PSI 19:30 - 19:40 0.17 DRILL P PROD1 'FIRE DRILL WITH AAR, PROPER NOTIFICATIONS AND RESPONSE BY ALL CREW MEMBERS,CONTINUE DRILLING 'DURING FIRE DRILL 19:40 - 22:00 2.33 DRILL ' P PROD1 DRILLING BUILD SECTION FROM 11270'TO 11300'MD,2610 CIRC PRESSURE, ROP 20 FPH,1.5 BPM IN/OUT,8.8 PPG WITH 10.43 ECD,2.5K WOB 22:00 - 00:00 2.00 DRILL P PROD1 DRILLING BUILD SECTION FROM 11300'TO 11330'MD.2670 CIRC PRESSURE. ROP 27 FPH.1.5 BPM IN/OUT,8.8 PPG WITH 10.44 ECD,2.1KWOB 5/5/2012 16:40 - 17:45 1.08 DRILL P PROD1 WIPER TRIP TO BELOW WINDOW 17:45 - 21:00 3.25 DRILL P PROD1 CONTINUE DRILLING LATERAL FROM 11550' TO 11700' MD AT 30-60 FPM PUMPING 8.6 PPG POWEREPRO AT 1.65 BPM IN/OUT 3320 PSI, 1.8K WOB ECD 10 7 PPG. IAP 510 PSI. OAP 206 PSI 21:00 - 22:00 1.00 DRILL P PROD1 WIPER TRIP TO BELOW WINDOW AT 11,105' MD,PUMP 1.64 BPM AT 3060 PSI 22:00 - 00:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 11,700'TO 11,810'MD, '3220 PSI FS,1.64 BPM IN/OUT @ 3550 PSI, 10.93 PPG ECD,ROP-70 FPM 00:00 - 02:45 2.75 DRILL P PROD1 DRILL BUILD SECTION FROM 11,330 TO 11,405, PUMP 20 BBLS HIGH VIS SWEEP ON BOTTOM 02:45 - 03:15 0.50 DRILL P PROD1 POH TO ABOVE WINDOW AND PERFORM FLOW CHECK AT 11060'MD 03:15 - 06:00 2.75 DRILL P PROD1 POH PUMPING 3.3 BPM 3660 PSI 06:00 - 06:30 0.50 DRILL P PROD1 L/D BHA#4. BIT IS 4-3,RINGED OUT NOSE. FUNCTION TEST BOPS. _ 06:30 - 07:10 0.67 DRILL P PROD1 'FILL WELL WITH 1.4 BBLS. CLOSE SWAB VALVE TO PREP FOR WELL KILL DRILL THROUGH MGS. PJSM FOR PUMPING THROUGH MGS. 07:10 - 07:25 0.25 DRILL P PROD1 PUT INJECTOR ON WELL WITH CLOSED SWAB VALVE,GET SLOW CIRCULATING PRESSURE OF 1100 PSI AT 1 BPM. SHUT IN HCR,TRAP 600 PSI WHP,CALL THIS SIDPP FOR THE PURPOSE OF THE DRILL. PROCEED AS PER STANDING ORDERS. EQUALIZE PRESSURE ACROSS THE HCR WITH THE TEST PUMP THEN ISOLATE THE TEST PUMP. Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 7 of 13 Operation Summary Report Common Well Name: F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project: Prudhoe Bay , Site: PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 10148°46'01.316"W Active Datum:ORIG KELLY BUSHING©54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:25 - 07:50 0.42 DRILL P PROD1 PJSM TO DISCUSS PUMP START UP AND CHOKE OPERATION. CALCULATE ICP= 1700 PSI. BEGIN FIRST CIRCULATION OF DRILLERS METHOD. USE REMOTE CHOKE TO HOLD ICP CONSTANT UNTIL PUMP IS BOUGHT UP TO SPEED,THEN HOLD CT PRESSURE CONSTANT EQUAL TO ICP. 07:50 - 08:20 0.50 DRILL P PROD1CIRCULATION COMPLETE,SHUT DOWN PUMP. BLEED OFF 0.5 BBL AND PRESSURE GOES TO ZERO. FLOW CHECK WELL. NO FLOW. END WELL KILL DRILL AT THIS POINT. CONDUCT AAR. 08:20 - 08:30 0.17 DRILL P PROD1 PJSM FOR P/U BHA#5. 08:30 - 09:30 1.00 DRILL P PROD1 P/U BHA#5. 1.0 DEG XTREME WITH HYC BICENTER,2-3/8"COILTRAK WITH RES. BHA OAL=67.91 FT. 09:30 - 10:30 1.00 DRILL P PROD1 iPT QTS,WON'T TEST. FAILS HI PRESSURE TEST. PJSM THEN PULL BHA BACK OUT OF WELL TO CHANGE OUT 0-RING ON QTS. CHANGE OUT 0-RING THEN M/U BHA AGAIN, M/U CT RISER. CHECK TREE BOLTS FOR TORQUE,ALL GOOD. 10:30 - 12:40 2.17 DRILL P PROD1 PT QTS IS GOOD. RIH BHA#5. PUMP 0.6 BPM/1200 PSI THROUGH OPEN EDC WHILE RIH. 12:40 - 13:30 0.83 DRILL P PROD1 TIE IN DEPTH FROM 10900 FT. CORRECT-39 FT. TRIP SHEET IS-5 BBLS TO THIS POINT. CLOSE EDC. 13:30 - 16:40 3.17 DRILL P PROD1 PASS THROUGH WINDOW AT 60R. RIH TO BOTTOM AND DRILL FROM 11400 FT TO 11550 FT. GOOD ROP INITIALLY 40-60 FT/HR WITH 2K DWOB. COMPLETE MUD SWAP WHILE DRILLING. 5/6/2012 00:00 - 01:00 1.00 DRILL P PROD1 DRILL FROM 11,810'TO 11,850'. PUMP 10 BBL HI-VIS SWEEP ON BOTTOM,CIRC PRESSURE INCREASED 500 PSI TO 3950 PSI WITH PILL IN THE COIL,STAYED ELEVATED WHEN PILL WAS OUT OF THE BIT. 01:00 - 03:45 2.75 DRILL P PROD1 LONG WIPER TRIP UP INTO 4-1/2"TUBING AT 9500'.OPEN UP EDC AND CIRCULATE AT 3 BPM IN CASED HOLE.TIE-IN AT RA TAG WITH 1+3)'CORRECTION. 03:45 - 06:30 2.75 DRILL P PROD1 DRILL AHEAD FROM 11,850'MD WITH FS OF 3400 PSI,1.65 BPM IN/OUT 3550 PSI,2.5K WOB,10.73 ECD,ROP 15 FPM 06:30 - 08:00 1.50 DRILL P PROD1 CONTINUE DRILLING FROM 11900 FT. ROP IS QUITE VARIABLE 0-120 FT/HR WITH 3K DWOB. DRILL AT 70L TO CONTINUE LH TURN AND MAINTAIN 3 TVD FT ABOVE MHO. DRILL TO 12000 FT. ECD= 11.4 PPG. PUMP 15 BBLS HI-VIS PILL AROUND. 08:00 - 09:00 1.00 DRILL P PROD1 WIPER TRIP FROM 12000 FT TO WINDOW. CLEAN PASS UP AND DOWN. Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 8 of 13 Operation Summary Report Common Well Name: F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 3/24/1974 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 014804601.316'9 Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date I From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 09:30 0.50 DRILL P PROD1 DRILL FROM 12000 FT. HOLD 85L FOR NOW TO CONTINUE LH TURN. DRILL TO 12027 FT. 09:30 - 11:20 1.83 DRILL P PROD1 PICK UP SLOWLY TO TROUBLESHOOT RESISTIVITY TOOL,NOT WORKING. EDC STILL FUNCTIONAL. REBOOT BHI COMPUTER, DRILL SOME MORE TO TEST RESISTIVITY. DRILL TO 12053 FT AND GET SLOW PUMP PRESSURES. 11:20 - 13:15 1.92 DRILL P PROD1 DRILL TO 12074 FT ERRATIC DRILLING, HAVE TO PUT ABOUT 3K DWOB TO GET IT TO DRILL. STILL AVERAGING ABOUT 30 FT/HR. DRILL AT 1.7/1.69 BPM @ 3500 PSI FREE SPIN. ECD=11.55 PPG. 13:15 - 13:50 0.58 DRILL P PROD1 DRILLING AT 12131 FT. PUMP 10 BBLS HI-VIS PILL AROUND. 13:50 - 17:30 3.67 DRILL P PROD1 POOH. AVERAGE ROP HAS FALLEN BELOW 20 FT/HR. HAVE TO STACK CONSIDERABLE WEIGHT TO KEEP IT DRILLING. PULL THROUGH WINDOW AND PERFORM A JOG ABOVE THE WINDOW. PERFORM FLOW CHECK JUST ABOVE WINDOW. OPEN EDC. FLOW CHECK IS NEGATIVE. POOH PUMP 3.2 BPM @ 3800 PSL 17:30 - 18:00 0.50 DRILL P PROD1 PJSM WHILE FLOW CHECKING WELL PRIOR TO BRING BHA ACROSS BOP. LAY DOWN BHA,BIT SHOWED SIGNIFICANT WEAR ON CUTTING SURFACE 18:00 - 18:30 0.50 DRILL P PROD1 PJSM, DISCONNECT BHI HEAD 18:30 - 19:30 1.00 DRILL P PROD1 PJSM, RIG UP COIL CUTTER.CUT 100'FOR CHROME MANAGEMENT.RIG DOWN CUTTER. 19:30 - 20:00 0.50 DRILL P PROD1 INSTALL BTT COIL CONNECTOR AND PULL TEST SAME TO 30K. 20:00 - 21:00 1.00 DRILL P PROD1 HEAD UP BHI CABLE CONNECTION, PERFORM CONDUCTIVITY TEST ON WIRES. 21:00 - 23:30 2.50 DRILL P PROD1 PRESSURE TEST CABLE HEAD TO 250/3800 PSI.INSTALL CHECKS.CHART PRESSURE TEST OF CHECKS AND SHELL TEST TO 250/3800 PSI. 23:30 - 00:00 0.50 DRILL P PROD1 SLB MECHANIC ADJUSTING HYDRAULIC LINES ON SSV SYSTEM 5/7/2012 00:00 - 01:00 1.00 DRILL P PROD1 SLB MECHANIC CHECK AND PT SSV HYDRAULIC LINES 01:00 - 01:45 0.75 DRILL P PROD1 MU BHA#6 WITH REPLACEMENT HYC 2.7"X 3"BICENTER BIT,BHA=67.91' 01:45 - 02:00 0.25 DRILL P PROD1 STAB ON INJECTOR AND TEST QTS TO 250/3500 PSI. 02:00 - 04:00 2.00 DRILL P PROD1 RIH WITH LATERAL BHA#6 04:00 - 04:35 0.58 DRILL P PROD1 TIE-IN AT 10,900'WITH(-39)'CORRECTION. 04:35 - 06:30 1.92 DRILL P PROD1 RIH AT 30 FPM CIRCULATING AT 1.6 BPM AND 2780 PSI TO 12,131'MD TO DRILL AHEAD LATERAL. 06:30 - 08:30 2.00 DRILL P PROD1 START DRILLING FROM 12147 FT. Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 9 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM Rig Release: Rig Contractor NORDIC CALISTA UWI:/Lat:070°2011.829"9 Long: 0148°46'01.3169 Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 11:30 3.00 DRILL P PROD1 CONTINUE DRILLING FROM 12150 FT. SLOW ROP GETTING STARTED. FREQUENT STALLING WITH CLEAN PICKUPS. 1.65/1.64 BPM @ 3400 PSI FREE SPIN. ECD= 11.75 PPG. DRILLING IS VERY ERRATIC, NOT SLIDING WELL. CLEAN PICKUPS. GOOD REACTIVE TORQUE WITH EACH STALL. PUMP 10 BBLS LO-VIS PILL AROUND, REDUCES ANNULAR FRICTION BY ABOUT 200 PSI, BETTER DRILLING FOR A SHORT TIME. 11:30 - 13:00 1.50 DRILL P PROW DRILL TO 12167 FT. NEED TO DRILL ANOTHER 10 FT TO GET THE GR PAST WHERE THE SLOW DRILLING STARTED. 13:00 - 13:50 0.83 DRILL P PROD1 SHORT WIPER TRIP FROM 12169 WHILE NEW MUD IS BEING CIRCULATED AROUND. 13:50 - 14:05 0.25 DRILL P PROD1 NEW MUD ALL THE WAY AROUND. DRILL FROM 12167 FT. 14:05 - 18:30 4.42 DRILL P PROD1 NO PROGRESS. MOTOR STALLING EASILY WITH LITTLE DWOB. POOH TO CHECK BIT AND MOTOR. 18:30 - 19:30 1.00 DRILL P PROD1 LAY DOWN MOTOR AND BIT,BIT SHOWS DAMAGE TO NOSE CUTTERS. PICK UP NEW MOTOR AND HCC 2.7"X 3"BICENTER BIT. l STAB COIL AND TEST QTS TO 250/3500 PSI 19:30 - 21:30 2.00 DRILL P PROD1 RIH WITH BHA#7=NEW MOTOR AND BIT PUMPING 0.5 BPM AT 1200 PSL 21:30 - 22:05 0.58 DRILL P PROD1 TIE-IN AT 10,900'WITH(-41.5)'CORRECTION. 22:05 - 23:00 0.92 DRILL P PROD1 CONTINUE IN HOLE. 23:00 - 23:15 0.25 DRILL P PROD1 OBTAIN SPRS AT 12,000'MD PUMP#1:0.5 BPM=1392 PSI,1.0 BPM=1871 PSI,1.6 BPM=2622 PSI PUMP#2:0.5 BPM= 1399 PSI,1.0 BPM=1970 PSI,1.6 BPM=2703 PSI 23:15 - 00:00 0.75 DRILL P PROD1 DRILL AHEAD FROM 12,169'MD,DIFFICULTY GETTING STARTED DRILLING,STALLS WITH CLEAN PICK-UPS 5/8/2012 00:00 - 02:30 2.50 DRILL P PROD1 DRILL AHEAD WITH VERY SLOW ROP AND FREQUENT STALLS PUMPING 1.8 BPM IN/OUT AT 3250 PSI.SAMPLE SHOWS SANDSTONE WITH SAMPLE SHOWS 15%CHERT. 02:30 - 07:00 4.50 DRILL P PROD1 DRILL AHEAD,ROP INCREASES TO 40 FPH AS BHA PASSES HARD INTERVAL AT 12,160'. PUMP 1.6 BPM IN/OUT, FS 3000 PSI,1.3 K WOB,11.1 ECD PICK-UP EVERY 10-20'TO KEEP MOTOR FROM STALLING, PICK-UPS CLEAN. 12,200'SAMPLE SHOWS ALMOST NO CHERT. DRILL TO 12288 FT. NO FURTHER PROGRESS MADE AT THIS SPOT IN 1.5 HRS. 07:00 - 10:00 3.00 DRILL P PROD1 POOH. FLOW CHECK AT SURFACE IS NEGATIVE. TRIP SHEET IS-7 BBLS.LAY DOWN BHA#7 10:00 - 11:00 1.00 DRILL P PROD1 LIFT UP CT INJECTOR. CHANGE OUT BIT. 11:00 - 13:10 2.17 DRILL P PROD1 TEST QTS AND START TO RIH W/BHA#8- NEW HYCALOG BI-CENTER BIT Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 10 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°46'01.316'W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:10 - 13:30 0.33 DRILL P PROD1 TIE IN AT 10900'=-40'CORRECTION 13:30 - 1415 0.75 DRILL P PROD1 RIH AND TAG @ 12283' PU=42K,RIH=18K,FS=2750# 1.64 14:15 - 14:30 0.25 DRILL P PROD1 PU AND OBTAIN SLOW PUMP RATES PMP#1 =51 SPM-1.6 BPM-2717PS1 32 1.0 1900 16 0.5 1384 PMP#2=51 1.5 2710 32 1.0 1930 16 0.5 1310 14:30 - 18:30 4.00 DRILL P PROD1 DRILL AHEAD FROM 12,285'. '3450 PSI FS AT 1.60 BPM IN/OUT. 250 PSI MTR WORK. 2.5-3.5K#DHWOB. VARY PUMP RATE AND DHWOB. NO FORWARD PROGRESS 18:30 - 19:15 0.75 DRILL P PROD1 INCREASE PUMP RATE TO 1.8 BPM AND MADE 15'OF PROGRESS TO 12,301'WITH 0.7-1.0 WOB. 19:15 - 21:30 2.25 DRILL P PROD1 NO FORWARD PROGRESS,VARY PUMP RATE AND WOB WITH NO CHANGE CALL ODE AND NS SUPT WITH PLAN TO TRIP OUT OF HOLE FOR A BIT CHECK. 21:30 - 22:30 1.00 DRILL P PROD1 POH FROM 12300'MD TO 11070'AT 30 FPM CIRCULATING 1.5 BPM. 22:30 - 22:40 0.17 DRILL P PROD1 FLOW CHECK WELL ABOVE WINDOW FOR 5 MIN,OPEN EDC AND INCREASE PUMP RATE TO 3.5 BPM,3310 PSI. 22:40 - 00:00 1.33 DRILL P PROD1 POH FROM 11,070'TO 4300'MD AT 90 FPM PUMPING 3.5 BPM. 5/9/2012 00:00 - 00:20 0.33 DRILL P PROD1 POH FROM 4300'TO 2000' 00:20 - 00:35 0.25 DRILL P PROD1 PJSM FOR BHA HANDLING 00:35 - 00:45 0.17 DRILL P PROD1 FLOW CHECK WELL BEFORE PULLING BHA ACROSS BOPE 00:45 - 01:25 0.67 DRILL P PROD1 UNSTAB INJECTOR, STAND BACK COILTRAK, LAY DOWN MOTOR AND BIT. HYC BIT IS IN GOOD CONDITION,1 CHIPPED CUTTER, RANKED A 1.1, CLAY BALLED UP IN BETWEEN BLADES FROM SHOULDER TO GUAGE. 01:25 - 01:45 0.33 DRILL P PROD1 GEO EVALUATES SAMPLE FROM BIT AND DETERMINES IT IS CLAYSTONE AND CHERT. 01:45 - 02:15 0.50 DRILL P PROD1 MU NEW MOTOR AND SAME HYC BI-CENTER FROM BHA#8.STAB COIL,TEST QTS TO 250/3500 PSI. 02:15 - 04:15 2.00 DRILL P PROD1 RIH AT 90 FPM WITH EDC CLOSED CIRCULATING 0.4 BPM AT 1010 PSI.START MIXING 2 DRUMS SCREEN-CLEAN INTO MUD SYSTEM 04:15 - 04:45 0.50 DRILL P PROD1 TIE-IN FROM 10,900'MD WITH(-42.5)' CORRECTION. 04:45 - 06:00 1.25 DRILL P PROD1 STAY IN CASED HOLE AT 10,907'TO CONDITION MUD SYSTEM WITH SCREEN-CLEAN AND KLASTOP Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 11 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°46'01.316"W_ Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) I 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS OPERATIONS AND EQUIPMENT STATUS. MAKE ALL CHECKS AND ROUNDS INSIDE AND OUTSIDE. CONTINUE TO CIRCULATE WELL TO CONDITION MUD WITH SCREEN CLEAN AND KLA-STOP. 06:30 - 07:30 1.00 DRILL P PROD1 (CLOSE EDC. RIH TO BOTTOM. 07:30 - 12:00 4.50 DRILL P PROD1 DRILL AHEAD FROM 12,303'. 3150 PSI FS AT 1.78 BPM IN/OUT. 200-250 PSI MTR WORK. DHWOB: 1-2K#. BEGAN DRILLING ONCE ON BTM. DIFFICULT TO KEEP BHA SLIDING. PLENTY OF MOTOR WORK AND WEIGHT TO BIT. ABLE TO MAKE FOOTAGE IN 2'TO 5' INCREMENTS. ADD ADDITIONAL KLA-STOP(2 DRUMS) AND SCREEN KLEEN(2 DRUMS) DRILL TO 12,413'. MAKE VERY FREQUENT SHORT WIPERS WHEN BHA STOPS SLIDING. MONITOR COI L LIFE DUE TO HIGH CYCLE FREQUENCY. GEO NOW NOTING A LOT OF CHERT IN CUTTINGS SAMPLES. 12:00 - 13:00 1.00'. DRILL P PROD1 DRILL AHEAD FROM 12413'. 3050 PSI FS AT 1.61 BPM IN/OUT. UNABLE TO MAKE ADDITIONAL PROGRESS. HOLD PJSM WITH DRILLERS. 13:00 14:15 1.25 DRILL P PROD1 MAKE WIPER TRIP TO WINDOW. FLOW CHECK AT WINDOW. WELL STABLE. 14:15 - 17:15 3.00 DRILL P PROD1 OPEN EDC. CIRCULATE OUT OF HOLE. REDUCE TRIP SPEED IN 7"TO AID HOLE CLEANING. HOLD UNANNOUNCED KICK WHILE TRIPPING DRILL. GOOD CREW RESPONSE. HOLD AAR TO DISCUSS DRILL. CONTINUE TO CIRCULATE OUT OF HOLE. HOLE BHA HANDLING PJSM NEAR SURFACE. 17:15 - 18:00 0.75 DRILL P PROD1 FLOW CHECK. WELL STABLE. GET OFF WELL. UNSTAB COIL. PJSM FOR LD BHA. STAND BACK BHA. HYC BIT VERY WORN, MINIMAL CLAY BALLING. GRADE 4-4. 18:00 - 19:00 1.00 DRILL P PROD1 TEST BHI FLOAT SUB TO 250/3800 PSI 119:00 - 20:30 1.50 DRILL P PROD1 MU NEW HCC 3.0"BICENTER WITH SLICK COATING(TO REDUCE CLAY BUILD UP). ADD AGITATOR TO BHA. STAB INJECTOR,TEST QTS TO 250/3500 PSI. 20:30 - 22:30 2.00 DRILL P PROD1 RIH WITH BHA#10,AT 300'CHECK TO VERIFY AGGITATOR IS WORKING.CONTINUE IN HOLE AT 90 FPM. 22:30 - 22:50 0.33 DRILL P PROD1 TIE-IN AT 10,900 WITH(-41.5)'CORRECTION Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 12 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) ----- ---..-_.... -- ----___.___---- Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:/Lat:07002011.829"9 Long: 0148°46'01.316"W _ Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:50 - 00:00 1.17 DRILL P PROD1 CONTINUE IN HOLE ORIENTING TO 62 ROHS THROUGH WINDOW. OBTAIN SPRS AT 12,400'MD PUMP#1: 0.5 BPM=1660 PSI,1.0 BPM=2447 PSI,1.4 BPM=3275 PSI PUMP#1: 0.5 BPM=1655 PSI,1.0 BPM=2350 PSI,1.4 BPM=3260 PSI 5/10/2012 00:00 - 02:30 2.50 DRILL P PROD1 PU WEIGHT 45K,3050 FS TAG 12,413'AND START DRILLING AT 1.4 BPM IN/OUT AND 3220 PSI,0-1.5K WOB,SLOW START DRILLING 4-8'AT A TIME AND THEN PICKING UP FOR SHORT WIPERS.AGITATOR IS NOT TRANSFERRING WEIGHT AS ANTICIPATED,NEGATIVE SURFACE WEIGHT REQUIRED TO GET WOB. 02:30 - 04:00 1.50 DRILL P PROD1 CONTINUE DRILLING WITH NEGATIVE SURFACE WEIGHT(5-10K)FOR WOB DOWNHOLE, PUMPING 1.4 BPM IN/OUT,3480 PSI,WOB 0-1.2K, ECD 11.1 PPG, DRILL-5'AT A TIME AND PICK UP WHEN WOB DROPS TO 0. _ I SAMPLE AT 12,450'SHOWS 50%CHERT. 04:00 - 06:00 2.00 DRILL P PROD1 DRILLING PERFORMANCE MAINTAINING.1.0 WOB WITH-14K SURFACE WEIGHT. PUMPING 1.42/1.4 IN/OUT AT 3380 PSI,11.10 PPG ECD 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS WELL AND RIG STATUS. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. CONTINUE WIPER TRIP TO WINDOW. 06:30 - 08:15 1.75 DRILL P J PROD1 WIPER TRIP TO WINDOW. 3622 PSI @ 1.65 BPM IN. PVT:251 BBLS. HOLE SMOOTH. 08:15 - 12:00 3.75 DRILL P PROD1 DRILL AHEAD FROM 12,549' 3620 PSI FS AT 1.56 BPM IN/OUT. 250 PSI MTR WORK. DHWOB: 1.5-2.0K#. BHP/ECD/TVD:5323 PSV11.1 PPG/8968' IA/OA/PVT:27 PSI/212 PSI/245 BBLS. ADD 100'BBLS NEW MUD TO SYSTEM. CONTINUE DRILLING IN SHORT INTERVALS. MAKE 30'-100'SHORT WIPERS AFTER BHA STOPS MOVING TO GET STARTED AGAIN. DRILL AHEAD TO 12,619' 12:00 - 14:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 12,619. 3630 PSI FS AT 1.56 BPM IN/OUT. 200-300 PSI MTR WORK. 1.5-2.0K#DHWOB. DRILL TO 12644'. 14:00 - 17:45 3.75 DRILL P PROD1 WIPER TRIP TO WINDOW. MIX 10%STEEL LUBE PILL IN PILL PIT. PUMP 5 BBLS LO VIS MUD,20 BBLS STEEL LUBE PILL,5 BBLS LO-VIS MUD. DISPLACE WITH EDC OPEN.SPOT IN 3-3/16" LINER AND 7"LINER FROM 11,070'. ALLOW TO SOAK FOR 30 MIN WHILE MOVING COIL. CLOSE EDC. WIPER BACK TO TD. Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 13 of 13 Operation Summary Report Common Well Name:F-08 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:4/30/2012 End Date: X3-011 MW-C: (2,062,333.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°4601.316W Active Datum:ORIG KELLY BUSHING©54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:45 - 21:20 3.58 DRILL P PROD1 DRILL AHEAD FROM 12,644'MD 3870 PSI FS AT 1.59 BPM IN/OUT. 110 PSI MTR WORK. DHWOB: 1.1-2.0K#. BHP/ECD/TVD:5418 PSV11.1 PPG/8964' IA/OA/PVT:70 PSI/212 PSI/315 BBLS. DRILL TO 12704'MD. 21:20 - 00:00 2.67 DRILL P PROD1 TOWN GEO CALLED TO CONFIRM TD DUE TO - UNCERTAINTY OF 14N.CALLED ODE TO INFORM ABOUT TD DECISION. 'PERFORM LONG WIPER TO 9500'SINCE EDC SHOULDN'T BE OPENED AFTER PUMPING BEADS IN LINER PILL. 5/11/2012 00:00 - 01:20 1.33 DRILL P PROD1 RIH AFTER WIPER TRIP,TIE-IN AT RA TAG WITH(+2)'CORRECTION. OBTAIN SPRS AT 12,500'MD PUMP#1:0.5 BPM=2001 PSI,1.0 BPM=2750 PSI,1.5 BPM=3705 PSI PUMP#1:0.5 BPM= 1925 PSI,1.0 BPM=2605 PSI,1.5 BPM=3680 PSI CONFIRM TD OF 12701'MD 01:20 - 02:00 0.67 DRILL P PROD1 ATTEMPT FLOW CHECK ON BOTTOM,BUT PIPE STARTED TO PULL HEAVY WITH 12K OVERPULL,CIRCULATE AND POH AT 1 FPM WHILE PUMPING 30 BBL LINER PILL OF NEW 8.6 POWERPRO WITH 50#TORQLESS BEADS. 02:00 - 03:00 1.00 DRILL P PROD1 POH FROM 12,630'. KICK WHILE TRIPPING DRILL FOLLOWED BY 'AAR,ALL HANDS RESPONDED 03:00 - 03:10 0.17 DRILL P PROD1 FLOWCHECK ABOVE WINDOW AT 11,060'MD. 03:10 - 03:30 0.33 DRILL P PROD1 CONTINUE OUT OF HOLE 03:30 - 04:30 1.00 DRILL P PROD1 LOG CCL FROM 9765 TO 9265'ACROSS LINER TOP SETTING DEPTH AT 15 FPM. 04:30 - 06:00 1.50 DRILL P PROD1 POH AT 90 FPM,PAINT EOP FLAGS AT 9125' AND 7585'.CONTINUE OUT OF HOLE PUMPING 1 BPM AT 1615 PSI. Printed 5/29/2012 10:23:06AM North America -ALASKA- BP Page 1 of 6 Operation Summary Report Common Well Name:F-08 AFE No Event Type:COM-ONSHORE(CON) I Start Date:5/11/2012 End Date: 5/15/2012 X3-011 MW-C: (1,128,862.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°46'01.316"W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/11/2012 06:00 - 06:30 0.50 RUNCOM P RUNCMP CREW CHANGE. DISCUSS OPERATIONS AND RIG STATUS. MAKE EQUIPMENT CHECKS AND RIG ROUNDS.CONTINUE FLOW CHECK. 06:30 - 07:15 0.75 RUNCOM P RUNCMP GET OFF WELL. UNSTAB COIL. LD BHA.BIT SHOWS HEAVY WEAR. NOSE AND GAUGE CUTTERS BROKEN AND WORN.REMOVE TOOLS FROM RIG FLOOR. 07:15 - 08:15 1.00 RUNCOM P RUNCMP FUNCTION TEST BOPE FROM DRILLER'S CONSOLE,ALL EQUIPMENT FUNCTIONED PROPERLY. 08:15 11:30 3.25 RUNCOM - P RUNCMP CIRCULATE COIL TO EXTRUDE EXCESS E-LINE. RECOVER 310'OF WIRE. INSTALL BAKER COIL CONNECTOR. PULL AND PRESS TEST SAME(30k#and 3800 psi)CIRCULATE AND RECOVER 3/4"BALL.CLEAN HIGH PRESSURE FILTER BYPASS. REASSEMBLE AND PT SAME. 11:30 - 12:45 1.25 RUNCOM P RUNCMP RU FLOOR TO RUN LINER.BRING SELBRT TOOL INTO PIPE SHED. HOLD DETAILED PJSM WITH CREW TO REVIEW LINER RUNNING PROCEDURE. DISCUSS WELL SHUT-IN,HOLE AND LINER FILL, ROLES AND RESPONSIBILITIES. 12:45 - 19:30 6.75 RUNCOMr P RUNCMP MU FLOAT EQUIPMENT AND SHOE TRACK. MU 101 JTS 2-3/8"4.7#/FT L-80 SOLID LINER WITH CEMENTRALIZERS. DRIFT ALL CONNECTIONS. MU TORQUE 500-600 FT-LBS. FILL LINER EVERY 10 JOINTS WITH WATER. 19:30 - 20:00 0.50 RUNCOM P RUNCMP PU LINER RUNNING ASSY,4 JTS OF 2-1/16" CSH,CROSSOVER AND QUICK CONNECT. 20:00 - 20:20 0.33 RUNCOM P RUNCMP STAB INJECTOR AND TEST QTS TO 250/3500 PSI,GOOD TEST.SET PUMP TRIPS TO 1500 PSI. 20:20 - 22:30 2.17 RUNCOM P RUNCMP RIH WITH LINER BHA PUMPING 0.3 BPM AT 1400 PSI. 22:30 - 22:30 0.00 RUNCOM P RUNCMP AT 10938'SAW FLAG AND CORRECTED(-41)' TO EOP FLAG DEPTH. 22:30 - 00:00 1.50 RUNCOM P RUNCMP CONTINUE IN HOLE, INCREASE PUMP TRIPS TO 1900 PSI. PUMPING 0.3 BPM AND 1850 PSI TAG TD AT 12,701',PU WEIGHT 43K,STACK 10K ON BOTTOM TO CONFIRM TAG AT 12,701'. 5/12/2012 00:00 - 02:45 2.75 RUNCOM P RUNCMP PUMP 6 BBLS KCL, PULL UP TO 12,670, LO/TO REEL AND DROP 5/8"STEEL BALL.CHASE BALL WITH 3 MORE BBLS KCL THEN BACK TO MUD AT 3400 PSI AND 1.5 BPM. LISTEN AND HEAR BALL LEAVE THE REEL. RIH TO TD AND SET 10K DOWN AT 12,701'. CONTINUE PUMPING AT 1.5 IN/OUT AT 3440 PSI,100% RETURNS. BALL ON SEAT AT 148 BBLS PUMPED, PRESSURE UP TO 4250 TO RELEASE LINER, PICK UP 1.5'WITH 30K BREAKOVER WEIGHT TO CONFIRM RELEASE. Printed 5/29/2012 10:23:45AM North America -ALASKA- BP Page 2 of 6 Operation Summary Report Common Well Name: F-08 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/11/2012 End Date: 5/15/2012 IX3-011MW-C:(1,128,862.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°2011.829"9 Long: 0148°46'01.316'W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:45 - 06:00 3.25 RUNCOM P RUNCMP SET 12K LBS BACK ON TD AT 12701'AND SWAP WELL TO 1%KCL PUMPING DOWN COIL AT 1.5 BPM AND 2290 PSI. RU CEMENTERS. PT CEMET LINES TO 250 AND 5500 PSI WITH KCL. RECORD SAME.TEST PASSED. 06:00 - 06:30 0.50 RUNCOM P RUNCMP CREW CHANGE. DISCUSS OPS,CEMENT JOB,AND RIG STATUS. 06:30 - 09:45 3.25 RUNCOM P RUNCMP HOLD PJSM WITH SLB, NORDIC,AND OTHERS. DISCUSS HAZARDS, CONTINGENCIES, PROCEDURES, COMMUNICATIONS AND 61' PUMP SCHEDULE. BATCH MIX 10 BBLS CLASS G,15.8 PPG,5-25 ML FL CEMENT. PUMP 5 BBLS KCL. 10 BBLS CEMENT WITH SLB PUMPERS. CLEAN UP TO CEMENTERS. DISPLACE WITH 2 PPG BIO WITH RIG PUMP. 1.68 BPM @1335 PSI AVERAGE. SLOW RATE TO 1 BPM AS CEMENT NEARS SEBLRT TOOL. SPOT 8 BBLS CEMENT IN LINER. PU AO COIL TO OPEN SIDE EXHAUST. PURGE 2 BBLS CEMENT. OPEN BAKER CHOKE. RIH WITH COIL. SET 12K#DN WT ON LINER TOP. PRESSURE COIL TO 2080 PSI. LWP SHEARED. DISPLACE CEMENT AT 1.5 BPM @ 1450 PSI. 1:1 RTNS, SLOW RATE TO 0.65 BPM TO KEEP CIRC PRESSURE BELOW 3000 PSI. LAND PLUG AT 86 BBLS(CALCULATED VOLUME=ACTUAL) CHECK FLOATS. NO FLO. PRESSURE LINER TO 850 PSI, UNSTING FROM LINER. CIRC AT 0.5 BPM AT TOL FOR 5 BBLS. CEMENT IN PLACE AT 0945. 09:45 - 12:00 2.25 RUNCOM P RUNCMP CIRCULATE OUT OF HOLE. MAINTAIN 0.75 BPM RETURNS. HOLD PJSM NEAR SURFACE. 12:00 - 13:15 1.25 RUNCOM P RUNCMP FLOW CHECK. GET OFF WELL. UNSTAB COIL. LD LINER RUNNING TOOLS. RECOVER BALL ON FLOOR. 13:15 - 14:00 0.75 CONDHL P OTHCMP PREP FLOOR TO RUN CLEAN OUT BHA. TEST BTT BPV TO 250 AND 3500 PSI. CHART SAME. TEST PASSED. 14:00 - 18:00 4.00 CONDHL P OTHCMP MU 1.75"HCC DIAMOND MILL ON 1-11/16" MOTOR. RUN ON 108 JTS OF 1"CSH. 18:00 - 18:30 0.50 CONDHL P OTHCMP STAB INJECTOR AND TEST QTS TO 250/3500 _ PSI,GOOD TEST. _ 18:30 - 20:00 1.50 CONDHL P OTHCMP RIH WITH CLEAN OUT BHA AT 70 FPM PUMPING 0.3 BPM. OBTAIN SPRS AT 9400'BEFORE ENTERING LINER. PUMP#1:0.5 BPM=960 PSI,1.0 BPM=2009 PSI PUMP#2:0.5 BPM=974 PSI,1.0 BPM=2015 PSI Printed 5/29/2012 10:23:45AM North America -ALASKA- BP Page 3 of 6 Operation Summary Report Common Well Name: F-08 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/11/2012 End Date:5/15/2012 X3-011 MW-C: (1,128,862.00) Project:Prudhoe Bay Site: PB F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM I Rig Release: Rig Contractor:NORDIC CALISTA UWI:/Lat:070°2011.829"9 Long: 0148°46'01.316'W Active Datum:ORIG KELLY BUSHING©54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 23:00 3.00 CONDHL P OTHCMP ENTER LINER AT 9440',RIH AT 25 FPM PUMPING 1 BPM AT FS 2250 PSI, NO MOTOR WORK IN LINER 23:00 - 00:00 1.00 CONDHL P OTHCMP SLOW DOWN TO 4.5 FPM AS APPROACHING PBTD, PUMPING 1.0 BPM AT 2820 PSI WITH 8.5 PPG KCL.TAG AT 12,715', SET DOWN 4K WITH 150 PSI MOTOR WORK,CONFIRM SECOND TIME. 5/13/2012 00:00 - 02:00 : 2.00 CONDHL P OTHCMP RETURN MICROMOTION DENSITY DROPPED FROM 8.4 TO 8.15 PPG 12,670'.GAS i MONITOR AT SHAKER SHOWS 5PPM METHANE.SHUT DOWN PUMP AND FLOW CHECK WELL, NO FLOW.START PUMPING AGAIN WHEN PERSONAL H2S MONITOR SHOWED 5 PPM, DIVERT RETURNS TO TIGER TANK.CALL NS SUPT WITH PLAN FORWARD TO CIRCULATE UNTIL DENSITY RETURNS TO 8.4 OF KCL.CIRCULATE BOTTOMS UP OF 140 BBLS AT 1.2 BPM AND 3570 PSI. 02:00 - 02:30 0.50 CONDHL P OTHCMP BRING RETURNS BACK TO THE PITS.FLOW CHECK WELL, NO FLOW. CONDUCT AAR FOR GAS RESPONSE.LESSON LEARNED THAT RIG GAS ALARMS SHOULD BE CALIBRATED.CONFIRM H2S AND COMBUSTIBLE LEVELS ARE 0 PPM WITH BACKUP HAND HELD MONITOR. 02:30 - 03:00 0.50 CONDHL P OTHCMP POH AT 50 FPM PUMPING 1.2 BPM AND 3500 PSI 03:00 - 03:15 0.25 CONDHL P OTHCMP FLOW CHECK ABOVE WINDOW AT 11,060', NO FLOW 03:15 - 04:30 1.25 CONDHL P OTHCMP CONTINUE POH AT 90 FPM PUMPING 1.15 BPM AT 3160 PSL 04:30 - 06:00 1.50 CONDHL P OTHCMP FLOW CHECK AT SURFACE WHILE HAVING PJSM TO STAND BACK 1"CSH. ELECTRICIAN OUT TO CALIBRATE RIG GAS MONITORS. 06:00 - 06:30 0.50 CONDHL P OTHCMP CREW CHANGE. DISCUSS OPERATIONS AND EQUIPMENT STATUS. MAKE INSIDE AND OUTSIDE ROUNDS. CONTINUE TO STAND BACK CSH IN DERRICK. 06:30 - 10:30 4.00 CONDHL P OTHCMP CONTINUE TO POOH WITH CLEAN OUT BHA. LD PH6. STAND BACK CSH IN DERRICK. 10:30 - 11:30 1.00 CONDHL P OTHCMP HOLD H2S EVACUATION AND RENTRY DRILL. ALL HANDS RESPONDED AND EVACUATED TO MUSTER AREA. RIG WAS PROPERLY RE-ENTERED AND THE FALSE ALARM DETERMINATION MADE. HELD DETAILED AAR. 11:30 - 12:30 1.00 CONDHL P OTHCMP CHANGE PACK OFF ON INJECTOR. 4/' 12:30 - 13:45 1.25 CONDHL P OTHCMP_PERFORM 2-3/8"LINER LAP TEST FOR 30 MIN. CHART TEST. INIT PRS:2405 PSI FINAL PRS:2303 PSI BLEED OFF IN LAST 15 MIN<50%BLEED OFF IN FIRST 15 MIN FINAL BLEED OFF RATE<5 PSI PER MIN. PASSED. 13:45 - 14:00 0.25 EVAL P OTHCMP BRING SLB MEMORY TOOLS TO RIG FLOOR. Printed 5/29/2012 10:23:45AM North America -ALASKA- BP Page 4 of 6 Operation Summary Report Common Well Name:F-08 AFE No Event Type: COM-ONSHORE(CON) Start Date:5/11/2012 End Date: 5/15/2012 X3-011 MW-C: (1,128,862.00) Project: Prudhoe Bay Site: PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°46'01.316'W Active Datum:ORIG KELLY BUSHING©54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 14:30 0.50 EVAL P OTHCMP DISCUSS DROPS AUDIT REVIEW WITH CREW AND B.HOPKINS. 14:30 - 15:00 0.50 EVAL P OTHCMP HOLD PJSM TO DISCUSS MU OF SLB LOGGING TOOLS. REVIEW PROCEDURE. DISCUSS HAZARDS AND MITIGATION OF SAME. 15:00 - 18:20 3.33 EVAL P OTHCMP CLEAR FLOOR. MU MEMORY GR/CCL/GR TOOLS. INSTALL SOURCE IN TOOL.RIH WITH 108 JOINTS CS HYDRIL FROM DERRICK. 18:20 - 20:20 2.00 EVAL P OTHCMP RIH WITH BHA#13 PUMPING 0.4 BPM AND 400 PSI. 20:20 - 22:40 2.33 EVAL P OTHCMP STOP AT 9300'TO START LOGGING RUN. LOG DOWN AT 30 FPM THROUGH LINER TOP AND 1 i CONTINUE DOWN PUMPING 0.5 BPM AT 700 PSI.TAG PBTD WITH-1000 LBS AT 12,716.4' UNCORRECTED. 22:40 - 23:45 1.08 EVAL P OTHCMP LOG UP FROM PBTD TO 9300'AT 60 FPM PUMPING 0.6 BPM AT 660 PSI. PAINT FLAG AT 12,200(EOP=8696').LAY IN 20 BBL KCL PERF PILL FROM PBTD. 23:45 - 00:00 0.25 EVAL P I OTHCMP STOP LOGGING AT 9300',FLOW CHECK WELL,NO FLOW 5/14/2012 00:00 - 00:45 0.75 EVAL P OTHCMP POH WITH MCNL BHA AT 100 FPM PUMPING 0.9 BPM AT 1610 PSI. 00:45 - 01:00 0.25 EVAL P OTHCMP PJSM FOR STANDING BACK CS HYDRIL, DISCUSS USING SAFETY JOINT IF NEEDED. FLOW CHECK DURING MEETING,NO FLOW 01:00 - 01:30 0.50 EVAL P OTHCMP POP OFF INJECTOR AT 50'FROM CONNECTOR,INSPECT PIPE,STAND BACK INJECTOR. 01:30 - 04:30 3.00 EVAL P OTHCMP STAND BACK 108 JOINTS OF CS HYDRIL IN THE DERRICK 04:30 - 04:45 0.25 EVAL P OTHCMP STAB SAFETY JOINT WITH 5 STANDS IN HOLE FOR PJSM WITH MEMORY LOGGER FOR LAYING DOWN TOOL AND RADIOACTIVE HAZARD. 04:45 - 05:30 0.75 EVAL P OTHCMP 'STAND BACK 5 STANDS IN DERRICK, LAYDOWN MEMORY LOGGING ASSY. 05:30 - 06:00 0.50 EVAL P OTHCMP EVALUATE MEMORY LOG, PREP FOR PERFORATING 06:00 - 06:30 0.50 EVAL P OTHCMP CREW CHANGE. DISCUSS OPERATIONS AND RIG STATUS. MAKE ALL EQUIPMENT CHECKS AND ROUNDS. CONTINUE TO DOWNLOAD AND PROCESS MEMORY LOG DATA. 06:30 - 07:30 1.00 EVAL P OTHCMP PJSM. LOAD GUNS IN TO PIPE SHED.RIG UP FLOOR TO RUN GUNS. PROCESS LOG DATA. 07:30 - 10:30 3.00 PERFOB P OTHCMP HOLD PJSM WITH NORDIC AND SLB HANDS. MU 10 EA 20' 1.56"6 SPF 1606PJ GUNS. RUN ON 108 JTS CSH FROM DERRICK. INCLUDE CSH MARKER JOINT. 10:30 - 12:30 2.00 PERFOB P OTHCMP STAB COIL. GET ON WELL. TEST QTS TO 250 AND 3500 PSI. PASSED. RUN IN HOLE Printed 5/29/2012 10:23:45AM North America -ALASKA- BP Page 5 of 6 Operation Summary Report Common Well Name:F-08 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/11/2012 End Date: 5/15/2012 X3-011 MW-C: (1,128,862.00) Project: Prudhoe Bay Site:PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time:3/24/1974 12:00:00AM 1Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:07002011.829"9 Long: 0148°46'01.316"W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) (ft) 12:30 - 13:45 1.25 PERFOB P + OTHCMP TIE IN TO EOP FLAG AT 8696. APPLY-56' CORRECTION AS PER MEMORY LOG TIE IN. RIH. TAG PBTD AT 12659'. 13:45 - 15:00 1.25 PERFOB P OTHCMP. PUMP RATE SEQUENCE AS PER SLB PERFORATORS. PULL OFF BTM SLOWLY. PERF INTERVAL: 12,455'TO 12,655'. POSITIVE INDICATION GUNS FIRED ON SHOT INDICATOR. 15:00 - 18:30 3.50 PERFOB P OTHCMP CIRCULATE OUT OF HOLE. MAINTAIN 250 PSI WHP WITH CHOKE. MONITOR HOLE FILL. NO LOSSES NOTED. 18:30 - 21:30 3.00 PERFOB P OTHCMP PJSM FOR BHA,LAY DOWN 4 JOINTS OF 2-1/16"CSH,STAND BACK 49 STANDS OF 1" CSH. LOSSES 1 BPH,MAINTAIN HOLE FILLED EVERY 5 STANDS, FORMATION LOOSING 1 BPI-I. 21:30 22:00 0.50 PERFOB P j OTHCMP WITH 5 STANDS OF CSH IN HOLEABOVE PERF GUNS,STAB SAFETY JOINT FOR PJSM WITH PERORATING HANDS. 22:00 - 23:00 1.00 PERFOB P OTHCMP _STAND BACK 5 STANDS 1"CSH, LAY DOWN FIRING HEAD AND 200'OF 1.56"PERF GUNS (10 GUNS).ALL SHOTS FIRED. 23:00 - 00:00 1.00`, PERFOB P OTHCMP CLEAN AND CLEAR FLOOR OF PERFING EQUIPMENT,PREP TO RUN CSH IN HOLE TO THEN IT LAY DOWN. 5/15/2012 00:00 - 03:30 j 3.50 PERFOB P OTHCMP RIH WITH 108 JTS 1"CSH FROM DERRICK. FORMATION LOSING 1 BPH. 03:30 - 06:00 2.50 PERFOB P OTHCMP LD 1"CSH,MAINTAIN HOLE FILL EVERY 20 JOINTS.PREP FOR RIG MOVE. 06:00 - 06:30 0.50 PERFOB P OTHCMP CREW CHANGE. DISCUSS OPERATIONS AND RIG STATUS. MAKE EQUIPMENT CHECKS. CONTINUE TO POOH WITH CSH. 06:30 - 08:30 2.00 PERFOB P OTHCMP LD 1"CSH IN PIPE SHED. 08:30 - 09:30 1.00 RIGD P POST RU LITTLE RED SERVICES. PRESS TEST HARD LINE TO RIG. 250 PSI AND 3500 PSI. RECORD TEST. PASSED. RUN IN HOLE WITH NOZZLE BHA. FILL COIL WITH 45 BBLS DIESEL. 09:30 - 11:00 1.50 RIGD P POST CIRCULATE OUT OF HOLE. LAY IN DIESEL 1:1 TO FP FROM 2500'. 11:00 - 11:30 0.50 RIGD P POST AT SURFACE.FLOW CHECK. GET OFF WELL. UNSTAB COIL. LEAVE 2 BBLS DIESEL IN COIL FOR FP. 11:30 - 14:00 2.50 BOPSUR P POST HOLD PJSM. SET BPV WITH T-BAR. PT MASTER AND SWAB INDEPENDENTLY TO 250/3500 PSI. RECORD TESTS. PASSED. 14:00 - 17:00 3.00 BOPSUR P POST OPEN BOP CAVITIES. INSPECT RAMS. CHAGEOUT TOP AND BLADE SEALS ON BLIND RAMS. REPLACE SHAKER FRAME ASSEMBLY IN PITS. CONTINUE TO RD SUPPORT EQUIPMENT. LOAD OUT EQUIPMENT TO HAUL TO J-PAD. 17:00 - 19:30 2.50 BOPSUR P POST NIPPLE DOWN BOP STACK AND NIPPLE UP TREE CAP FLANGE WITH NEW RING GASKET. Printed 5/29/2012 10:23:45AM North America -ALASKA- BP Page 6 of 6 Operation Summary Report Common Well Name:F-08 AFE No Event Type: COM-ONSHORE(CON) Start Date:5/11/2012 End Date: 5/15/2012 X3-011 MW-C: (1,128,862.00) Project: Prudhoe Bay Site: PB F Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 3/24/1974 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°20'11.829"9 Long: 0148°46'01.316"W Active Datum:ORIG KELLY BUSHING @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 20:00 0.50 WHSUR P POST PRESSURE TEST TREE CAP AGAINST SWAB VALVE TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS,SEE :ATTACHED CHART) 20:00 - 21:00 1.00 RIGD P POST GENERAL RIG DOWN OPERATIONS IN PREPARATION FOR RIG MOVE. PULL CUTTINGS BOX AWAY FROM RIG. 21:00 - 22:00 1.00 RIGD P POST HOLD PJSM AND BACK OFF WELL. STAGE RIG ON PAD. PAD OPERATOR ON LOCATION FOR BACKING OFF WELL. 22:00 - 00:00 2.00 RIGD P POST PICKUP RIG MATS AND CLEAN UP AROUND F-08 WELLHEAD WHILE NORDIC 2 RIG STAGED ON F PAD. -ALL TREE AND WELLHEAD VALVES CLOSED TO PRESSURE GAUGES. -TREE,WELLHEAD AND CELLAR CLEAN -FINAL T/I/O=BPV/0/0 PSI -WELLWORK TRANSFER PERMIT CLOSED OUT WITH PAD OPERATOR. -WELL HANDOFF COMPLETED WITH WELLS GROUP COORDINATOR. END CON EVENT AND RELEASE NORDIC 2 RIG AT 23:59 ON 5/15/2012 PREPARE TO MOVE RIG TO J-27B. Printed 5/29/2012 10:23:45AM rr , , ' i--c , , ,\ ,, LI Lf2 A A s I L% J ! SEAN PARNELL,GOVERNOR o_.� ' uL�1 - L1 (jJ ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F-08B BP Exploration (Alaska), Inc. Al Permit No: 212-040 r-CG- .. 3,"'-1' Surface Location: 2710' FSL, 2877' , SEC. 2, T1 IN, R13E, UM Bottomhole Location: 1355' FNL, 2703' FEL, SEC. 10, T11N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. Sincerely, ‘(24 Cat P. Foerster . Chair DATED thisz� day of March, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) I STATE OF ALASKA I RECEIVED ALAS. JIL AND GAS CONSERVATION COMM., Ofd PERMIT TO DRILL 1 BAR 1 9 2012 20 AAC 25.005 f 1 a.Type of work: 1b.Proposed Well Class: 1 c. e i if w I is r osed for; ®Development Oil 0Service-Winj 0Single Zon$ a, ❑ Drill ®Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zo�he',I3 Oda bed6a�00'GaV� aie ' ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp r',nch0i TM hale Gas 2. Operator Name: 5.Bond: Blanket 0 Single Well _._--11"VPell dame and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 • PBU F-08B • 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 12980' - TVD 8963'ss • Prudhoe Bay/Prudhoe Bay, 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: 1. r7, ,, r-2_ ADL 028280&028281 2710'FSL,2877' , ec.02,T11N, R13E, UM . Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1204'FNL, 1153' FEL,Sec. 10,T11N, R13E, UM May 1,2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1355'FNL,2703'FEL, Sec. 10,T11N, R13E, UM 2560 15600' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 54,8' • feet 15.Distance to Nearest Well Open Surface: x- 651958 , y-5974230• Zone- ASP4 GL Elevation above MSL: 34.92' feet to Same Pool: 500' 16.Deviated Wells: Kickoff Depth: - 11085' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3194 ' Surface: 2314 - 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight , Grade Coupling Length MD ND MD _ TVD (including stage data) 3" 2-3/8" 4.7# L-80 , STL 3460' 9520' 7789'ss 12980'_8963'ss 51 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 12750' 9043' 11890' 12707' 9042' 12278' Casing Length Size; , Cement Volume MD , Conductor/Structural 80' 30" 135 sx Arcticset 80' 80' Surface 2700' 13-3/8" 3697 sx Permafrost II 2700' 2700' Intermediate 10087' 9-5/8" 1650sx Howco Light,200sx Class'G',687sx Class'G' 10087' 8174' Production _ Liner 1507' 7" 752 sx Class'G' 9559'-11066' 7866'-8865' Liner 2311' 3-3/16"x 2-7/8" 125 sx Class'G' 10429'-12740' 8404'-9043' Perforation Depth MD(ft): 11290'- 12694' Perforation Depth ND(ft): 9023'-9042' 20.Attachments: 0 Property Plat ® BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ® Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ron Phillips,564-5913 Printed Name Jo 'M Ai, ,; // Title Engineering Team Leader Prepared By Name/Number. Signature 4'', Phone 564-4711 Date 3 /6/f2 Joe Lastufka,564-4091 Commission Use Only ' Permit To ,/x API Number: Permit�p o ajte: See cover letter for Number: 2/.2-�%7� 50-029-20135-02-00 fj�.I,'( \j \ - other requirements Conditions of Approval: If box is checked,well may not beusedto explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: E,-✓r Other: 3�'®v (•5` gee 7es t Samples Req'd: 0 yes IBf<lo Mud Log Req'd: ❑�(es LI No HZS Measures: Yes 0 No Directional Survey Req'd: Yes 0 No Date 3'2 S -( 7-- JA_ / APPROVED BY THE COMMISSION COMMISSIONED ,/ Form 10-401 Revised 07/2009 This permit is valid for 24 mon f r al(20 AAC 25.005(9)) Submit In Duplicate l: 3/2 74t -'11k) To: Alaska Oil & Gas Conservation Commission bp From: Ron Phillips 0 CTD Engineer Date: March 14, 2012 Re: F-08B Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well F-08A. CTD Drill and Complete F-08B program: Riq Start Date: May 1st, 2012 History of F-08A. F-08A is a CST completed in Dec 2002 in Zone 2A above the MHO/HOT (did not tag the HOT). Upon completion, the well struggled to flow despite two N2 lifts. The well finally went on production after an HCI wash and the installation of a gas lift straddle. The sidetrack produced fulltime until late 2005 when it was shut-in for a tubing' leak. In July 2007, a RWO was completed which replaced the tubing and the Thermocase section of the 9-5/8" casing. The 5-3/4" CTD liner deployment sleeve was also cut off and removed before running the downsized 4-1/2" tubing. The well was POP'ed and remained fulltime for -2 years. In mid 2009, F-08A began cycling for high GOR. In July 2010 a CIBP was set at 11890' to isolate the current perfs, and 100' of perfs were added in the first half of the lateral. The well would not flow. An additional 60' of perfs were shot in Feb 2011. The well produced for a couple months before being shut-in for high GOR. End-of-life adperfs (25') were shot in the heel in April 2011, but they were unsuccessful. F-08A is currently shut-in for high GOR. The most recent caliper from 11/19/12 showed the tubing to be in good condition, with a maximum wall penetration of 19% recorded at 11,010', 10,667' and 10,438'. All sidetrack / screening pressure tests passed. Reason for sidetrack. F-08A is no longer a competitive producer, and there are no remaining well work options. The proposed sidetrack will access reserves in a Zone 2A target in southwestern F-pad. Proposed plan for F-08A The existing perforations will be isolated by setting a 3-3/16" packer whipstock set pre-rig. The primary cement job for the liner will cover the whipstock by 650'. The sidetrack, F-08B, will exit the existing 3-3/16" liner and kick off and land in the Ivishak Zone 2A. This sidetrack will be completed with a cemented and perforated 2-3/8" L-80 liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (scheduled to begin April 1St, 2012) 1. F MIT- IA to 3,000 psi (passed 11/21/12), MIT-OA to 2,000 psi (failed 11/21/12). 2. W Function LDS; PPPOT-T to 5,000 psi. 3. S Drift for 3-3/16" packer whipstock (2.56" x 9.25') to 11,1010'. e 7-s t /SbD 4. EP Set 3-3/16" packer whipstock at 11,085' MD (orientate 90°). K 5. V PT MV, SV, WV. 6. 0 Blind and bleed lines to zero, remove wellhouse and level pad. 7. V Set 4" CIW TWC 24 hrs prior to rig arrival. fill' Rig Sidetrack Operations: (Scheduled to begin on May 1St, 2012 using Nordic Rig 1) 1. MIRU Nordic Rig 1. 3S-vo e 6 1 7 2. NU 7-1/16" CT Drilling BOPE and test. 3. Mill 2.80" single string window in the 3-3/16" liner at 11,085' 4. Drill Build: 3" OH, 305' (35 deg/100 planned). 5. Drill Lateral in Z2A: 3" OH, 1,590' (12 deg/100 planned) with resistivity.' 6. Run 2-3/8" L-80 liner leaving TOL -9,520' MD. 7. Pump primary cement leaving TOC at 10,435' MD, 10.6 bbls of 15.8 ppg Class G cement planned. �T 8. Perform cleanout/log run with mill and motor. 14-0-4-) 9. Perform a logging run with MCNL/GR/CCL. 10. Test liner lap to 2,400 psi. 11. Perforate well (-500'). 12. Freeze protect well with diesel to 2,500' TVD. 13. Set BPV. ND 7-1/16" BOPE stack. 14. Freeze protect tree and PT tree cap to 3,500 psi. 15. RDMO Nordic 1. Post Rig: 1. Re-install wellhouse, flowline and pull BPV. 2. Set 4-1/2" liner top packer if needed with skickline, and test to 2,400 psi. Mud Program: • Well kill: 8.4 ppg seawater/ brine. • Milling/drilling: 8.6 ppg Geo-VIS for milling window and drilling (778 psi over-balance). Disposal: • All Class I & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at • DS 4 or Pad 3 at DS 6. • Fluids >1% hydrocarbons or flammables must go to Pad 3: • Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. • Fluids with PH >11 must go to GNI. Hole sizes: 3" from 11,085' MD- 12,980' MD. Liner Program: Solid, cemented, and perforated completion planned. • 2-3/8", L-80, 4.7 lb/ft STL liner 9,520' MD - 12,980' MD. • Planned 10.6 bbls of 15.8 class G cement will be used for liner cementing (assuming 3" hole size to TD and 10% excess in open hole). • TOC planned at 10,435' MD. • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. 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. Maximum planned hole angle is 92°, inclination at kick off point is 32°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property— 15,600' MD. • Distance to nearest well within pool —500' from J-10A. Anti-Collision • None Logging • MWD directional, Gamma Ray and Resistivity logs will be run over all of the open hole lateral °' section while drilling. Resistivity will not be run over the short build section. • Cased hole GR/CCL/MCNL logs will be run. - Perforating: • SWS 1.56", 6 spf, perf guns, 1" CSH work string, & 2-1/16" CSH • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Hazards • F-Pad is considered an H2S pad. Well F-24 had 120 ppm H2S on 7/11/2011. v • Most recent H2S level on F-08 is 10 ppm recorded on 2/08/2011. • The lost circulation risk in the F-08B is considered to be low and no fault crossings are planned. -- Reservoir Pressure • The reservoir pressure is estimated to be 3,194 psi at 8,800 TVDss (6.98 ppg equivalent) based on average offset pressures. • Max expected surface pressure with gas (0.10 psi/ft) to surface is 2,314 psi. " 4_ • An EMW of 8.4 ppg for this well will provide 686 psi over-balance to the reservoir. Ron Phillips Coiled Tubing Drilling Engineer 564-5913 CC: Well File Sondra Stewman/Elizabeth Barker/Terrie Hubble TREE= ' 4"CM/ SAr NOTES:WELL ANGLE>70°@ 11295'.*** WELLHEAD ACTUATOR g�--5/8 OOY S F-O 8A 4-1i� CHROME TBG*** KB.ELEV= 54.8' BF.ELEV= 34.92' : I KOP= 3200' Max Angle= 94°@ 11575' 30"CONDUCTOR, —1 80' ►` 2072' —19-5/8"HES CEMENTER Datum MD= 11053' Datum TVD= 8800'SS 157.53#,ID=? 2097' —4-1/2"HES X NIP,ID=3.813" FI9-5/8"CSG,40#,L-80 HYDRIC 563 XO TO TC11 - 615' , ii2106' —19-5/8"PBR 0-1 2135' H 9-5/8"HOWCO FO CEMENTER 9-5/8"CSG,40#,L-80 TCII,ID=8.835" H 2129' D- 2660' —9-5/8"HOWCO FO CEMENTER 13-3/8"CSG,72#,N-80 BUTT,ID=12.347" H 2700' , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3795 3769 22 MMG DMY RK 0 11/21/11 9-5/8"HOWCO FO CEMENTER —I 4212' I n D 1 7638 6493 40 MMG DMY RK 0 11/21/11 Minimum ID =2.372"@ 11101' , ' 9425' —14-1/2"HES X NIP,ID=3.813" 3-3/16" X 2-7/8" XO Q x--I 9488' —9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" 7"TBG STUB(TAGGED 07/04/07) -f 9512' I /\• i 9512' 1-14-1/2"HES X NIP,ID=3.813" 4-1/2"TBG, 12.6#, 13CR-80 VAM TOP, - 9545' I 9533' H4-1/2"HES XN NIP, ID=3.725" .0152 bpf,ID=3.958" 7"TBG,26#,N-80, .0383 bpf,ID=6.276" H 9596' \\\\• �I 9546' —I4-1/2"HES WLEG, ID=3.958" 9-5/8"CSG,47#,N-80 BUTT,ID=8.681" H 10087' 1 9559' 7"PBR,ID=? PERFORATION SUMMARY I 9599' —I 7"BOT PKR w/BOT HGR,ID=? I REF LOG: SWS MEMORY CNL/GR OF 12/19/02 ANGLE AT TOP PERF: 71°@ 11290' ' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 10435' I—I3-3/16"LNR STUB(07/09/07) 1.56" 6 11290-11295 O 04/03/11 1.56" 6 11295- 11315 0 04/02/11 2" 6 11340- 11365 O 07/15/10 H7"X 4-1/2"OTIS WD PKR,ID=4.0" 2" 6 11415- 11440 0 07/15/10 10441' —14-1/2"OTIS X NIP, ID=3.813" I BEHIND 2" 6 11470- 11500 0 02/03/11 I 10445' I 4-1/2"OTIS XN NIP,ID=3.800" CT LINER 2" 6 11582-11612 0 02/03/11 2" 6 11660-11685 0 07/15/10 /. (MILLED 12/04/02) 2" 6 11800-11825 0 07/15/10 10447' -14-1/2"W/LEG I 2" 4 12000- 12182 C 12/20/02 2" 4 12380- 12694 C 12/20/02 •. 1. ''' ��. 11040' —I 7"MARKER JOINT .4 te' , MILLOUT WINDOW(F-08A) 11066'- 11074' TOP OF CEMENT —I 10760' ` TOP OF WHIPSTOCK H 11053' •'4, • 11101' —13-3/16"X 2-7/8"XO, ID=2.372" BAKER MOD K BRIDGE PLUG — 11275' Megeeee. 12278' FISH-FASDRILL DEBRIS 7"LNR,29#,N-80 BUTT,.0371 bpf,ID=6.184" —I 11303' )/ (PUSHED TO BTM 09/13/07) 3-3/16"LNR,6.2#, L-80, 11101' PBTD — 12705' .0076 bpf,ID=2.80" 2-7/8"HES CIBP(07/15/10) — 11890' & 2-7/8"LNR,6.16#,L-80 STL,.0547 bpf, ID=2.372" — 12740' DATE REV BY COMMENTS . DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/08/76 ORIGINAL COMPLETION 07/28/10 HJW/PJC PERF/CIBP(07/15/10) WELL: F-08A 12/21/02 DAC/KK CTD SIDETRACK(F-08A) 02/12/11 LLVPJC ADPERFS(02/03/11) PERMIT No:'2022310 07/14/07 N2ES RWO 04/04/11 RRD/PJC ADPERF(04/02-03/11) API No: 50-029-20135-01 02/08/07 CJN/PAG PULL BKR IBP/GL MANDREL 11/28/11 DLW/JMD GLV C/O(11/21/11) SEC 2,T11N,R13E,2570'FNL&2403'FWL 04/06/07 ALH/PJC ARROW PATCH PULLED(02/07/07) 01/15/08 JCM/PJC DRLG DRAFT CORRECTIONS a BP Exploration(Alaska) Ktt= 4 UVV NELLHEAD= /8"McEVOY ,_-O 8 B SA1 NOTES:WELL ANGLE>70°@ 11295'.*** 4CTUATOR= OTIS 4-11, .,HROMETBG* * <B.ELEV= 54.8' proposed CST 3F.ELEV= 34.92'' <OP= 3200' I \lax Angle= 4°@ 11575' 9 Datum MD= 11053' 30"CONDUCTOR, — 80' 2072' H9-5/8"HES CEMENTER Datum TV D= 8800'SS 157.53#, ID=? 2097' H4-1/2"HES X NIP, ID=3.813" 9-5/8"CSG,40#, L-80 HYDRIC 563 XO TO TC11 H 615' I 2106' —I9-5/8"PBR 2135' H9-5/8"HOWCO FO CEMINTER 9-5/8"CSG,40#, L-80 TCII, ID=8.835" H 2129' 0 2660' —19-5/8"HOWCO FO CEMENTER GAS LIFT MANDRELS 13-3/8"CSG,72#,N-80 BUTT, ID=12.347" —1 2700' 1--A kT MD TVD DEV TYPE VLV LATCH PORT DATE 2 3795 3769 22 MVIG DMY RK 0 11/21/11 9-5/8"HOWCO FO CEMENTER H 4212' ii 0. 1 7638 6493 40 T 1G DMY RK 0 11/21/11 Minimum ID = 1.78" @ 9520' ' ' 9425' —14-1/2"HES X NIP, ID=3.813" 3" Deployment Sleeve TSGR = 10,535' MD X 9488' H9-5/8"X 4-1/2"BKR S-3 PKR,0=3.875" 7"TBG STUB(TAGGED 07/04/07) H 9512' 1-- I ' 9512' H4-1/2"HES X NIP, ID=3.813" Top of 2-3/8"liner at-9,520' - 4-1/2"TBG, 12.6#, 13CR-80 VAM TOP, H 9545' 56° 9533' —{4-1/2"HES XN NIP, ID=3.725" .0152 bpf, ID=3.958" • 9546' H4-1/2"HES WLEG, ID=3.958" 7"TBG,26#,N-80, .0383 bpf, ID=6.276" H 9596' 9-5/8"CSG,47#,N-80 BUTT,ID=8_681" H 10087' 9559' 7"PBR ID=? IIJZFORATION SUMMARY L 9599' H7"BOT PKR w/BOT HGR,ID=? REF LOG: SWS MEMORY CNUGR OF 12/19/02 ANGLE AT TOP PERF: 71°@ 11290' ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1 1.56" 6 11290- 11295 O 04/03/11 10435' H 3-3/16"LNR STUB(07/09/07) 1.56" 6 11295- 11315 O 04/02/11 2" 6 11340- 11365 O 07/15/10 FOC at-10,435' ��7 10435' H7"X 4-1/2"OTIS WD PKR,ID=4.0" 2" 6 11415- 11440 O 07/15/10 2" 6 11470- 11500 O 02/03/11 I 10441' H4-1/2"OTIS X NIP,ID=3.813" BEHIND 2" 6 11582-11612 O 02/03/11 10445' 4-1/2"OTIS XN NIP, ID=3.800" CT LINER 2" 6 11660-11685 O 07/15/10 (MILLED 12/04/02) 2" 6 11800-11825 O 07/15/10 2" 4 12000-12182 C 12/20/02 10447' {4-1/2"W/LEG 2" 4 12380 12694 C 12/20/02 0. v� 11040' —17"MARKER JOINT H ity �- 3-3/16"whipstock at 11,O MILLOUT WINDOW(F-08A) 11066'- 11074' TOP OF CEMENT 10760' 4..4 TOP OF WHIPSTOCK H 11053' 4'•:p� 33° 11101' H3-3/16"X 2-7/8"XO, ID=2.372" BAKER MOD K BRIDGE PLUG —1 11275' 3-3/16"LNR,6.2#,L-80, —I 11101' 7"LNR,29#, N-80 BUTT, .0371 bpf, ID=6.184" H 11303' Ailike .0076 bpf, ID=2.80" 12278' —FISH-FASDRILL DEBRIS 7? / ` (PUSHED TO BTM 09/13/07) C7/8"CIBP at 11,15i. 2-3/8"liner withTD at 12,980' 2-7/8"HES CEP-(07/I5/10)(07%10) r 11890' ,.a. PBTD H 12705' 2-7/8"LNR,6.16#,L-80 STC, .0547 bpf,ID=2.372" — 12740' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/08/76 ORIGINAL COMPLETION 07/28/10 HJW/PJC PERF/CIBP(07/15/10) WELL: 12/21/02 DAC/KK CTDSIDETRACK(F-08A) 02/12/11 LLIIPJC ADPERFS(02/03/11) PERMIT No: 2022310 07/14/07 N2ES RWO 04/04/11 ' RRD/PJC ADPERF(04/02-03/11) API No: 50-029-20135-01 02/08/07 CJN/PAG PULL BKR IBP/GL MANDREL 11/28/11 DLW/JMD GLV GO(11/21/11) SEC 2,T11 N,R13E,2570'FNL&2403'FWL 04/06/07 ALH/PJC ARROW PATCH PULLED(02/07/ 01/12/12 WJH proposed coil sidetrack 01/15/08 JCM/PJC DRLG DRAFT CORRECTIONS , BP Exploration(Alaska) a 0 0 co 1 0 a J a) a � 'i. C N ao — N w ° O ° d5 a V 0g= p 3 " 0; °° ` � Z a` fie iiii (13 a CO �= m z fla N. 0m a C C mi = = Z "6 "O M 0) 70N M p U U 0 N it) a) a) O) co paN )l) LO M_ O) (O O O O O N MpN Uavav v N H =0 o O o 'O O O N O` C E> o00 as E v 2rnrn > 0 a) 0 o z > a) 0 >— a LLco co E CO> m d co coO o O E C 0) O) C) d = J D3 C C C O Na0I- 2 OW 20 D ca w0 O y > J J 0 6 d 7 O O 0 'c O 2 .c « ) co co w a) . J 0 .c r lY 2 a1 C C F C a)) a) C N E (n C 'O C V 0 O 7 '6 O ` C V 10 TOO O y d w R •• ❑ it M O w d 0 d W T R E = x 'C O O O TIL O of co N I,- 0 Lci ▪ O J 9 Z (O ❑ N N co O = = = 1:1 cO CD O O �O N O O O N- CO O 0) o O) CD M LO co ❑. irj NO a) tr I 10 CA co Q C) u' C a t a CO o I— ❑ E o 3 0 .) O o d 7 > co I- + O N CO C a1 o W o a) 0, L CD C 40 C 0) IO C N a Z• W f/) C R - c ` Z W7) N o C) Z o Z Q J 0 } N Q CO a) O of l0 N 0 0 a a R — E .c ct a CD in CO a E M U Mpp In • m a m m Z o LL m Ijis... C = cc L t. Q ];, N-Z a = m O O O Q m a)0 ~ o O O O O U '8 O O Ed N Q O C< 0 a_I CU a COo r CO R -D f9 Z a) '', Il W co Z C7 C I,— C m O O C� _N U N IL d N N IL 0_ ll LL . m a .a) m a 3 O @ co fn . 0 2 Q O a ❑ N Z 00 O 7 m O O c Q i+ + + D Z z.„ Z 0_ 0_ u_ i a Q ' N a) 0) g 0 • E c c) u v ��N_ y E . j j In a) ra) ai h.W C .. co O C •y C .N C `7 U O " N Mid a) O C a N O O O O O O 0 C Z C ns sib nm a O y u) ON d tL a c rn u o m w E ' y _ w O. O a :) E. — - N rn y a r �' F' O m m y m a) R Q p d d O m as a) O a7 O p Z oain33 ❑ a 2c72 co 00U 0. 3 3 a 32 ❑ Q > > irk CO 0• 0 0 V) O CO 0 W 0 M 0 N- 0) 0 CO o (fl o CO o CI) N- CI 0 0 v, CO o a sp C C O N O 1` O W C) O CO O O O O O .- a) to a1 LD co co co a) O) O) a) 6) m -o a o (o 0 .c.) .o LL C`7 0) 0) 1- p (D C 0 0) 0) N m o) OS e = = 0) V N- N LO CD co co V a) Coco CD CO CO 000 00D a h CO N- V ,- N (O CO v CD I,- a) O CO Q CD V N to to CD (n O CD V O N4 M N LO• U) N 0 N CO M CO N CD CO N CD V CO CO co p, _ . 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CO COIO 0 In CO LO LO O w w N 0 E O aN I� V D NV O O O O O V 0 0 m. >, R 0) co N N N V CO _ r CO V CO N _ 0 N N N N N N CO CO CO V V V LL) LO UO-CI CO C o• > 0oY $ O O O O O O O O O o O o 0 0 0 • > c (o - 12 -c N- N- N- h N- I- N- N- N- I- h I- N- N- r-- ...1 W F- 2 Z u) 0 mCO (Oo) 0) 0 a) o) a) co a) co a) co a) rn a) 0)aai o O LLLLfLLO O LO O O LO LO O LO O C CO C C Z t 0 Co CO (0 10 LO 1- CO V CO LO CO N V CO CO 00 W CO CD N O O a) 6 CO a) LL) M N a- CO CO CO O• .-• V; CO LO M LO 1� 6 V LO M N • co co N aIO 0 2 2 ' a) O O LL) a) 0 CD U' h coO M M COL01 C V V LO LO LO LO CO CO CO I- a) o M O 1 M C..; C`� 07 Ca 0 U M 0 0 CD N- CO CO CO a) O) a) u) N co a) O co co 0 V co N Lt) M N V N o N LO N r CO 0) '- Lf) N CO 6 V V V V LL) co E ' N C) CO CO V (O V Lb h V CO M N (e so, 0 a) 0) a) 0) Q) 0 CO 1- N- n N- CO CD CD (D Co i4 Z < U) C`? C? M M C�) r) Q o m 3 3 Z . 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O N Q' CD CO v v CO CO v v CD I,- CD CO O CO 0 1- N 00 C O N CD D) O M CO N O N- 0 M -4- CO 0) CO 0) N CO LYW C'7 Cn 1- + W W u-) W CO CC) n LO 0 CO r ti CO CO 0 N. D CC)W CV sr N O O co co N V �O• hM .1-CV N M N CO CO O N N SCO N.N aN N.:C N 7 O O I- C� f� O O O' f�0 Co m -! h CD 00)Z 00) V C) N 00) COCCD• • CA Z co Z M Z M 0MO M M M M M M Z Z CO 0 0 0 CD N 0 CD 0 0) r n O MM M 0) aD CD aD CD E M M M O OO O 0 0 0 0 0 0 0 O O COZ 00 a CO a co F- oo CO co co co co co a 00 N> n> ~ d' 4 V V' 4 4 in.> CO V'F N F lD M 0 CO CO U) CD 0 N F a O O Cf) O 0 C)O 01 co CO co 00) C)) ca co 4 co co N co N t` O O O 0) CO 0 0) O O a a d) a O O O 0 O O 2 O= O= OO o'= O O� O O O•M CO O o -6,3 -c, -_ ... LD o N) co N O O M Ln M Cy'... 0 0)O) O O N CO 0- d 0 M co fco V 0)co CO r !6 a- � 0) 0) CO Q m m m CO o° o° 1 = = N to R L� C- M O) O CD OM O4 0 C O= U O. 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Ise _ ,�.� + Lo m�LL �i , 1-i 4...): Li, Igoe... 2mLL " in 3 m q M1 a C <., d T o o m N 11::::1E : N 111O sIiiiN N " N N N rr,.r BP BAKER HUGHES Travelling Cylinder Report INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-08-Slot 08 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB F Pad MD Reference: 8:08 3/24/1974 00:00 @ 54.80ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: F-08 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore F-08B Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 1 Offset TVD Reference: Offset Datum Reference Plan 1 Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Method: MD Interval 10.00ft Error Model: ISCWSA Depth Range: 11,053.00 to 11,600.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 35.00ft Error Surface: Elliptical Conic Survey Tool Program Date 1/16/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 11,053.00 1 :Camera based mag multi sho(F-08) CB-MAG-MS Camera based mag multi shot 11,112.07 11,053.00 MWD(F-08A) MWD MWD-Standard 11,053.00 12,980.00 Plan 1 (F-08B) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 2,700.00 2,645.06 13 3/8" 13.375 17.500 10,087.00 8,119.09 9 5/8" 9.625 12.250 12,980.00 8,962.59 2 3/8" 2.375 3.000 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB F Pad F-08-F-08A-F-08A 11,090.00 11,090.00 0.06 2.10 -1.04 FAIL-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/16/2012 2.08:14PM Page 2 of 4 COMPASS 2003.16 Build 73 • fii = BP HUGHES Travelling Cylinder Report 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-08-Slot 08 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB F Pad MD Reference: 8:08 3/24/1974 00:00 @ 54.80ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: F-08 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore F-08B Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 1 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-08-F-08A-F-08A Offset Site Error: 0.00ft Survey Program: 100-CB-MAG-MS,11112-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (f) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (f) (ft) (ft) (ft) 11,060.00 8,805.22 11,060.00 8,805.22 0.06 0.07 -88.99 -3,926.51 -3,481.96 0.22 0.00 0.68 -0.49 FAIL-Major Risk,CC 11,070.00 8,813.26 11,070.00 8,813.26 0.10 0.16 -88.35 -3,928.55 -3,487.54 0.22 0.00 1.19 -0.77 FAIL-Major Risk 11,080.00 8,821.52 11,080.00 8,821.52 0.13 0.25 -87.73 -3,930.16 -3,492.94 0.22 0.00 1.65 -1.02 FAIL-Major Risk 11,090.00 8,829.96 11,090.00 8,829.99 0.16 0.34 45.09 -3,931.34 -3,498.12 0.22 0.06 2.10 -1.04 FAIL-Major Risk,ES,SF 11,099.99 8,838.43 11,100.00 8,838.64 0.19 0.44 46.10 -3,932.08 -3,503.09 0.22 0.47 2.56 -0.82 FAIL-Major Risk 11,109.98 8,846.88 11,110.00 8,847.44 0.22 0.53 49.04 -3,932.40 -3,507.82 0.22 1.27 3.01 -0.13 FAIL-Major Risk 11,119.98 8,855.33 11,120.00 8,856.32 0.25 0.57 55.30 -3,932.21 -3,512.41 0.22 2.25 3.27 0.86 Pass-Major Risk 11,130.00 8,863.75 11,130.00 8,865.15 0.27 0.59 58.23 -3,931.39 -3,517.03 0.22 3.26 3.48 1.80 Pass-Major Risk 11,140.04 8,872.10 11,140.00 8,873.88 0.30 0.61 59.96 -3,929.94 -3,521.69 0.22 4.30 3.68 2.79 Pass-Major Risk 11,150.13 8,880.38 11,150.00 8,882.40 0.33 0.64 60.89 -3,927.94 -3,526.52 0.22 5.16 3.88 3.59 Pass-Major Risk 11,160.26 8,888.55 11,160.00 8,890.59 0.36 0.66 61.05 -3,925.49 -3,531.70 0.22 5.61 4.06 3.97 Pass-Major Risk 11,170.41 8,896.57 11,170.00 8,898.44 0.39 0.68 60.52 -3,922.58 -3,537.17 0.22 5.71 4.23 4.01 Pass-Major Risk 11,180.57 8,904.38 11,180.00 8,906.01 0.41 0.71 59.33 -3,919.08 -3,542.68 0.22 5.72 4.39 3.69 Pass-Major Risk 11,190.75 8,911.97 11,190.00 8,913.27 0.44 0.73 57.48 -3,914.98 -3,548.20 0.22 5.71 4.53 3.31 Pass-Major Risk 11,200.94 8,919.30 11,200.00 8,920.24 0.47 0.76 55.28 -3,910.33 -3,553.66 0.22 5.68 4.65 2.92 Pass-Major Risk 11,211.14 8,926.35 11,210.00 8,926.99 0.49 0.78 54.30 -3,905.20 -3,558.95 0.22 5.70 4.75 2.68 Pass-Major Risk 11,221.36 8,933.07 11,220.00 8,933.53 0.52 0.81 54.77 -3,899.60 -3,564.03 0.22 5.77 4.83 2.58 Pass-Major Risk 11,231.58 8,939.45 11,230.00 8,939.81 0.54 0.83 56.38 -3,893.55 -3,568.93 0.22 5.86 4.88 2.55 Pass-Major Risk 11,241.81 8,945.45 11,240.00 8,945.71 0.57 0.85 57.93 -3,887.05 -3,573.72 0.22 5.89 4.92 2.46 Pass-Major Risk 11252.03 8,951.05 11,250.00 8,951.20 0.59 0.87 59.31 -3,880.12 -3,578.40 0.22 5.85 4.93 2.30 Pass-Major Risk 11,262.25 8,956.22 11,260.00 8,956.23 0.61 0.89 60.26 -3,872.78 -3,582.95 0.22 5.75 4.92 2.07 Pass-Major Risk 11,272.46 8,960.95 11,270.00 8,960.78 0.84 0.91 60.60 -3,865.04 -3,587.35 0.22 5.60 4.89 1.78 Pass-Major Risk 11,282.59 8,965.19 11,280.00 8,964.83 0.66 0.93 59.99 -3,856.94 -3,591.58 0.22 5.43 4,86 1.44 Pass-Major Risk 11,292.30 8,968.90 11,290.00 8,968.35 0.68 0.95 54.78 -3,848.50 -3,595.63 0.22 5.83 5.12 1.24 Pass-Major Risk 11,301.96 8,972.25 11,300.00 8,971.33 0.70 0.97 49.78 -3,839.79 -3,599.53 0.22 7.01 5.38 1.92 Pass-Major Risk 11,311.50 8,975.23 11,310.00 8,973.76 0.73 0.99 44.90 -3,830.93 -3,603.47 0.22 8.71 5.68 3.17 Pass-Major Risk 11,320.90 8,977.83 11,320.00 8,975.63 0.76 1.01 40.39 -3,821.96 -3,607.49 0.22 10.90 6.00 4.95 Pass-Major Risk 11,330.11 8,980.05 11,330.00 8,976.94 0.79 1.03 36.43 -3,812.90 -3,611.50 0.22 13.62 6.33 7.29 Pass-Major Risk 11,339.03 8,981.88 11,340.00 8,977.78 0.82 1.04 33.43 -3,803.68 -3,615.26 0.22 17.04 6.66 10.37 Pass-Major Risk 11,347.59 8,983.33 11,350.00 8,978.16 0.85 1.06 31.04 -3,794.30 -3,618.71 0.22 21.16 7.00 14.17 Pass-Major Risk 11,355.73 8,984.43 11,360.00 8,978.07 0.88 1.08 28.94 -3,784.81 -3,621.85 0.22 25.95 7.33 18.64 Pass-Major Risk 11,363.00 8,985.19 11,370.00 8,977.74 0.91 1.09 27.57 -3,775.15 -3,624.40 0.22 31.51 7.68 23.92 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/16/2012 2:08:14PM Page 3 of 4 COMPASS 2003.16 Build 73 rico — 1 C al , -I s j al r N Q b e FS-. 0 _ g 1 a GI 9116 1 , 7, '..... .:211116 g. - lip,. 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TRANSMITTAL LETTER CHECKLIST WELL NAME 611 C4& PTD# 2 (7 c2�� cDevelopment Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: (rUudjube....- POOL: (-?"-C-cc_LIC9-e--- Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - . API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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