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212-026
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' 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: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:31 -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 B-20A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-026 50-029-20842-01-00 11708 Conductor Surface Intermediate Liner Liner 9042 80 2639 9156 735 2785 10460 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 9046 35 - 115 39 - 2678 34 - 9190 8933 - 9668 8923 - 11708 35 - 115 39 - 2677 34 - 8440 8206 - 8889 8197 - 9042 10500 2670 4760 5410 10530 10460 5380 6870 7240 10160 9875 - 11650 4-1/2" 12.6# 13Cr80 34 - 9044 9045 - 9041 Structural 4-1/2" Baker S3 Packer 8830 8113 Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com 907-564-4667 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 0028310 34 - 8307 N/A N/A 303 458 28866 22550 336 840 500 500 940 440 325-317 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8830, 8113 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:58 am, Aug 07, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.07 05:05:06 - 08'00' Torin Roschinger (4662) DSR-9/10/25 rbdms jsb 080825 JJL 8/12/25 ACTIVITY DATE SUMMARY 7/15/2025 LRS CTU #1 - 1.50" Blue Coil: Job Objective: Drift/Log, Set CIBP, Ext. AddPerf - MIRU,, Spot in and start R/U. Test BOP's. NU BOP's & function test . MU YJ CTC/MHA wtih HES GR/CCL log in a 2.20" carrier. PT PCE 4200 psi. BH well with 225 bbl of 1% KCL.Well went on a vac at around 158 bbls. Pumped 225 total at 4.6 bpm. RIH for Drift/Log with pump at min rate (No WHP) ...Job in Progress... 7/16/2025 LRS CTU #1 - 1.50" Blue Coil Job Objective: Drift/Log, Set CIBP, Ext. AddPerf RIH with Drift/Log BHA. Set down at 10,153', Wash down to 10,192' CTM. Unable to get down. POOH for motor & mill. RIH w/YJ motor + 2.30" junk mill. No significant motorwork seen down to 10,550'. One stall seen at 10539'. Backream liner and then dry drift back to 10550'. MU/RIH with HES memory tool inside 2.2" carrier + 2.25" DJN. Paint blue flag at 10150', log up to 8900', POOH. RIH w/ YJOS 2-7/8" CIBP Setting BHA. L/K with 150 bbl of 1% KCL. --Bump test ctc against brass, bump test H2S/LEL meters. ***In progress*** 7/17/2025 LRS CTU #1 - 1.50" Blue Coil Job Objective: Drift/Log, Set CIBP, Ext. AddPerf Could not enter liner. POOH to add centralizer to YJOS plug setting bha. RIH w/ YJOS 2-7/8" CIBP Setting BHA + Hydraulic Centralizer. Set 2-7/8" CIBP at 10,500'. Plug leaks at 2.6bpm at ~500psi. POOH to set another CIBP. 2nd CIBP set at 10460', set down weight (2k), PU hole pumping pipe disp to LTP, circulate a kill from bottom and attempt MITT (Failed). 1bpm ~1650psi LLR. POOH pumping pipe disp/keeping positive WHP. Will proceed with perforating. At Surface, perform no flow checks. Check thread compatibility between Safety Joint & Guns. MU HES perforating BHA. Deploy 24, 2" MaxForce perforating guns. RIH w/ 310' of 2" MaxForce guns. ***Review Standing Orders & Perform Well Control Drill with Night Shift*** ***In Progress*** 7/18/2025 LRS CTU #1 - 1.50" Blue Coil Job Objective: Drift/Log, Set CIBP, Ext. AddPerf Stop at red flag, correct to top shot. Perforate intervals 9875' - 9950' & 10140' - 10375'. POOH. Perform a good No-Flow test. Pop off, un-deploy 24, 2" MaxForce guns. All shots confirmed fired. FP well with 38bbl diesel. ***Review Standing Orders & Perform Well Control Drill with Night Shift*** ***Job complete*** Daily Report of Well Operations PBU B-20A 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 thes 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 B-20A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-026 50-029-20842-01-00 341J ADL 0028310 11708 Conductor Surface Intermediate Liner Liner 9042 80 2639 9156 735 2785 11668 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 9042 35 - 115 39 - 2678 34 - 9190 8933 - 9668 8923 - 11708 2450 35 - 115 39 - 2677 34 - 8440 8206 - 8889 8197 - 9042 None 2670 4760 5410 10530 None 5380 6870 7240 10160 10550 - 11650 4-1/2" 12.6# 13Cr80 34 - 90449043 - 9041 Structural 4-1/2" Baker S3 Packer No SSSV Installed 8830, 8113 Date: Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com 907-564-4667 PRUDHOE BAY 7/1/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:15 pm, May 21, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.05.21 16:05:00 - 08'00' Torin Roschinger (4662) 325-317 DSR-6/3/25 10-404 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment JJL 6/3/25 A.Dewhurst 23JUN25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.24 06:00:43 -08'00'06/24/25 RBDMS JSB 062425 Plug and Ext Perf B-20A PTD:212-026 Well Name:B-20A API Number:50-029-20842-01 Current Status:Operable Producer Rig:CTU Estimated Start Date:7/1/2025 Estimated Duration:3days Reg.Approval Req’std?10-403, 10-404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker First Call Engineer:Leif Knatterud (907) 564-4667 (O)(432) 227-4342 (M) Second Call Engineer:Finn Oestgaard (907) 564-5026 (O)(907) 350-8420 (M) Current Bottom Hole Pressure:3250 psi @ 8,800’ TVD 7.1 PPGE | (Estimated) Maximum Expected BHP:3400 psi @ 8,800’ TVD 7.5 PPGE | (Highest Ivishak BHP) Max. Anticipated Surface Pressure:2520psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2200psi (2/3/2023) Min ID:2.377” @ 10,287’ 3-3/16” x 2-7/8” XO Max Angle:95 Deg @ 10,202’ Brief Well Summary: CTD sidetrack completed in 2012 as a zone 2A well. Well has been a solid producer with majority on time until the end of 2021. Gas rates jumped and well started to cycle in 2022. The LTP was suspect. SL/EL pulled the LTP and calipered deployment sleeve on 2/23/23. Liner showed significant corrosion. Ran a modified LTP with D&D tubing stop to be able to set 4-1/2” packer in good tubing closer to the deployment sleeve. Well on time has improved since setting the LTP, but well has still been near MGOR. Objective:This program will isolate the lower liner with a CIBP, test for liner/LTP integrity and then perforate up-hole to improve on time of well with lower GOR. Procedure: 1. MU GR/CCL with ~2.25” JSN drift (NS Bridge plug 278-210 is 2.1” OD). RIH to ~10,600’. Flag pipe and pull tie-in log. a. Flag pipe for plug set (10,500’) and perforating depth (9,875’-10,375’) (310’ perf add). b. Last drift: To deviation (~9900 with 2.61” cent) 2/22/2023 2. POOH. Correlate with SLB Memory CNL 6/10/12(see attached log – Jewelry Log Pass). Correct flag and send to Corey Ramstad and OE. 3. MU NS 278-210 Bridge Plug or similar. RIH. 4. Prior to entering liner fluid pack well down CTBS with KWF. See bullhead volumes below in step 11. 5. Set CIBP at 10,500’. 6. Pull up above LTP and Perform liner integrity test to 2000 psi. 7. If liner integrity test loses more than 50psi/min call to discuss path forward with OE. 8. Record results in AWGRS 9. POOH. Coil – Extended Perforating – If liner integrity test passed then proceed with extended perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating Plug and Ext Perf B-20A PTD:212-026 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. 10. 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. 11. Bullhead 1.2X wellbore volume - 180 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. a. Wellbore volume to top perf = 150 bbls b. 4-1/2” Tubing – 8,918’ X .0152 bpf = 136 bbls c. 3-1/2” Liner – 69’ X 0.0087 bpf = 1 bbls d. 3-1/4” Liner – 1,300’ X .0079 bpf = 11 bbls e. 2-7/8” Liner – 263’ X .0058 bpf = 2 bbls 12. At surface, prepare for deployment of TCP guns. 13. 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. 14.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 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. 15.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2” Maxforce guns or similar Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 9,875’ – 9,950’ - Gun 9,950’ – 10,140’ – Blank 10,140’ – 10,375’ - Gun 310’ 500’ 2800 lbs (5.6 ppf) 16. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. f. Note any tubing pressure change in WSR. 17. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary, before pulling to surface. 18. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 19. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 20. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 21. RDMO CTU. 22. Turn well over to Operations POP. Attachments: Wellbore Schematic, Proposed Schematic, Tie-In Log, BOPE diagram, Standing Orders, Equipment Layout, Sundry Change Form Plug and Ext Perf B-20A PTD:212-026 Current Wellbore Schematic Plug and Ext Perf B-20A PTD:212-026 Proposed Wellbore Schematic Plug and Ext Perf B-20A PTD:212-026 Tie-in Log Plug and Ext Perf B-20A PTD:212-026 Perf Interval – 9,875’ – 9,950’ Perf Interval – 10,140’ – 10,375’ Plug – 10,500’ Plug and Ext Perf B-20A PTD:212-026 BOP Schematic Plug and Ext Perf B-20A PTD:212-026 Plug and Ext Perf B-20A PTD:212-026 Plug and Ext Perf B-20A PTD:212-026 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 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 thes 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 B-20A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-026 50-029-20842-01-00 341J ADL 0028310 11708 Conductor Surface Intermediate Liner Liner 9042 80 2639 9156 735 2785 11668 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 9042 35 - 115 39 - 2678 34 - 9190 8933 - 9668 8923 - 11708 2450 35 - 115 39 - 2677 34 - 8440 8206 - 8889 8197 - 9042 None 2670 4760 5410 10530 None 5380 6870 7240 10160 10550 - 11650 4-1/2" 12.6# 13Cr80 34 - 90449043 - 9041 Structural Date: Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com (907) 903-5990 PRUDHOE BAY 11/15/2023 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 By Grace Christianson at 2:00 pm, Oct 20, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.10.20 13:44:26 -08'00' Torin Roschinger (4662) 323-577 Perforate SFD 10/23/2023 DSR-10/24/23 10-404 2450 MGR30OCCT23*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.30 16:10:48 -08'00'10/30/23 RBDMS JSB 110223 Plug & Ext Perf B-20A Well Name:B-20A API Number:50-029-20842-01 Current Status:Operable – cycle well Rig:CTU Estimated Start Date:11/15/23 Estimated Duration:2day Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:212-026 First Call Engineer:Michael Hibbert (907) 903-5990 (C) Second Call Engineer:Kirsty Schultz (907) 350-4310 (C) Current Bottom Hole Pressure:3250 psi @ 8,800’ TVD (Based on Average Ivishak BHP) Maximum Expected BHP:3250 psi @ 8,800’ TVD (Based on Average Ivishak BHP) Max. Anticipated Surface Pressure:2450psi (Last SI WHP > calc’d gradient) Last SI WHP:2200 psi (Taken on 2/3/23) Min ID:2.377” 3-3/16” x 2-7/8” XO Max Angle:95 Deg @ 10,202 MD Reference Log:SLB Memory Compensated Neutron Log dated June 10, 2012 Brief Well Summary: CTD sidetrack completed in 2012 as a zone 2A well. Well has been a solid producer with majority on time until the end of 2021. Gas rates jumped and well started to cycle in 2022. The LTP was suspect. SL/EL pulled the LTP and calipered deployment sleeve on 2/23/23. Ran a modified LTP with D&D tubing stop to be able to set 4-1/2” packer in good tubing closer to the deployment sleeve. Well on time has improved since setting the LTP, but well has still been near MGOR. Objective:This program will isolate the lower liner with a CIBP, test for liner/LTP integrity and then perforate up-hole to improve on time of well with lower GOR. Procedure: 1. MU GR/CCL with ~2.25” JSN drift (NS Bridge plug 278-210 is 2.1” OD). RIH to ~10,500’. Flag pipe and pull tie-in log. a. Flag pipe for plug set (10,430’) and perforating depth (10,140’-10,350’). 2. POOH. Correlate with SLB Memory CNL 6/10/12(see attached log – Jewelry Log Pass). Correct flag and send to Jeff Nelson or OE. 3. MU NS 278-210 Bridge Plug or similar. RIH. 4. Prior to entering liner fluid pack well down CTBS. See bullhead volumes below in step 10. 5. Set CIBP at 10,430’. 6. Perform liner integrity test to 2000 psi. 7. If liner integrity test does not pass solid call to discuss path forward with OE. 8. POOH. Coil – Extended Perforating – If liner integrity test passed then proceed with extended perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Plug & Ext Perf B-20A 9. 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. 10. Bullhead 1.2X wellbore volume - 180 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 150 bbls b. 4-1/2” Tubing – 8,919’ X .0152 bpf = 136 bbls c. 3-1/2” Liner – 69’ X 0.0087 bpf = 1 bbls d. 3-1/4” Liner – 1,300’ X .0079 bpf = 11 bbls e. 2-7/8” Liner – 1147’ X .0058 bpf = 2 bbls 11. Use flag from CIBP drift if possible. If needed MU and RIH with GR/CCL in carrier with 2.25” JSN. f. Flag pipe as appropriate per WSS for adperf g. POOH and freeze protect tubing as needed. h. Confirm good log data. 12. At surface, prepare for deployment of TCP guns. 13. 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. 14.*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. i.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. 15.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2” Maxforce guns or similar Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 10,140’-10,350’210’210’1176 lbs (5.6 ppf) 16. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. j. Note any tubing pressure change in WSR. 17. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 18. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 19. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 20. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 21. RDMO CTU. 22. Turn well over to Operations POP. Make up PCE. - mgr Plug & Ext Perf B-20A Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE Schematic x Standing Orders x Equipment Layout x Sundry Change Form Plug & Ext Perf B-20A Current Wellbore Schematic Plug & Ext Perf B-20A Proposed Wellbore Schematic CIBP – 10,430’ C C C C C C C C Add perforations from 10,140’-10,350’ By Samantha Carlisle at 7:39 am, Sep 06, 2022 Plug & Ext Perf B-20A Tie-In Log Plug & Ext Perf B-20A Set CIBP at 10,430’ Perforate from 10,140’-10,350’ Plug & Ext Perf B-20A BOP Schematic Plug & Ext Perf B-20A Plug & Ext Perf B-20A Plug & Ext Perf B-20A Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU B-20A Install LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-026 50-029-20842-01-00 11708 Conductor Surface Intermediate Liner Liner 9042 80 2639 9156 735 2785 11668 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 9042 35 - 115 39 - 2678 34 - 9190 8933 - 9668 8923 - 11708 35 - 115 39 - 2677 34 - 8440 8206 - 8889 8197 - 9042 None 2670 4760 5410 10530 None 5380 6870 7240 10160 10550 - 11650 4-1/2" 12.6# 13Cr80 34 - 9044 9043 - 9041 Structural 4-1/2" Baker S3 Packer 8830, 8113 8830 8113 Torin Roschinger Area 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 0028310 34 - 8307 N/A N/A 295 475 26501 29064 388 348 400 1150 807 960 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:21 am, Jun 29, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.28 17:11:13 -08'00' Torin Roschinger (4662) RBDMS JSB 063023 DSR-6/29/23WCB 1-31-2024 ACTIVITY DATE SUMMARY 11/5/2022 ***WELL S/I ON ARRIVAL***(fish ltp) R/U HES 759 BRAIDEDLINE UNIT ***CONT WSR ON 11/6/22*** 11/6/2022 ***CONT WSR FROM 11/5/22*** (fishing) SET 3.70" UNIQUE SPEAR IN LTP @ 8,746' BLM JARRED ON UNIQUE SPEAR FOR 2.5 HRS, SPEAR RELEASED.(fishneck in grapples/metal shavings inside) PLANTED 3.70" SLICK CATCH SPEAR (2.60" to 2.73" grapple) IN LTP @ 8746' BLM (jar 2.5hrs, 6hrs tatal on B/L) ***CONT WSR ON 11/7/22*** 11/7/2022 ***CONT WSR FROM 11/6/22*** (fishing) JARRED ON SPEAR/45KB LTP FOR 8hrs (14hrs total) @ 8,742' BLM ***CONT WSR ON 11/8/22*** 11/8/2022 ***CONT WSR FROM 11/7/22*** (fishing) JARRED ON SPEAR/45KB LTP FOR 2hrs (16hrs total) @ 8,742' BLM ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** ******4 1/2" SLICK CATCH SPEAR PLANTED IN 45KB LTP @ 8,742' BLM****** Needs releasing prong on 4 1/2 GR to recover, use 3 1/2" GS to Jar on 2/2/2023 ***WELL FLOWING ON ARRIVAL***(ltp) RIG UP HES SLICKLINE UNIT #759 ***CONT'D ON 2/3/23 WSR*** 2/3/2023 ***CONT'D FROM 2/2/23 WSR***(ltd) DRIFTED TBG W/ 11' x 3.16" DUMMY GUN & 33' x 3.66" DUMMY GUNS TO LTP ASSY @ 8803' SLM.(no issues) PULLED 3.70" SLICK CATCH SPEAR FROM LTP ASSY @ 8804' SLM. ***NOTE*** Fish left in hole - (missing core from grapple) 25.75" OAL, max 2" OD w/ 1.0" fishing top (threads for first 2.0") pic in well file. ***CONT'D ON 2/4/23 WSR*** 2/3/2023 T/I/O= 2200/300/0 Temp= SI Pumped 38 bbls Crude down TBG Pumped 9 bbls 60/40 followed by 44 bbls crude down FL for west side recipe Hang tags Pad Op notified of well status upon departure 2/4/2023 ***CONT'D FROM 2/3/23 WSR***(ltp) DRIFTED INSIDE LTP ASSY W/ 3.70" CENT, 5' x 1-1/2" WB & 2.25" CENT W/ BULLNOSE, S/D @ 8814' SLM. PLANTED 3.70" SLICK CATCH SPEAR IN STUCK LTP ASSY @ 8808' SLM.(jarred 17mins) *****USE 4-1/2" GR W/ RELEASING PRONG TO RETRIEVE***** ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 2/8/2023 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD ELINE FOR WELLTEC STROKER FISHING JOB. RIG DOWN EQUIPMENT DUE TO 3RD PARTY CRANE ISSUES. ***WELL LEFT S/I, ON DEPARTURE Daily Report of Well Operations PBU B-20A Daily Report of Well Operations PBU B-20A 2/10/2023 ***WELL S/I ON ARRIVAL*** RIG UP ALASKA E-LINE WITH WORLEY CRANE SUPPORT FOR WELLTEC STROKER JOB. PT PCE 250LP-3000HP PULL LINER TOP PACKER FROM 8796' MD WITH WELLTEC 312 WELL STROKER AND WELLGRAB. WORKED UP TO 87K ON THIRD CYCLE TO FREE FISH FROM XN NIPPLE AT 9799' MD. PIECES OF ELEMENT AND SEAL ASSEMBLY LEFT IN HOLE. ***WELL LEFT S/I, PAD OP NOTIFIED*** 2/22/2023 *** WELL S/I ON ARRIVAL *** STANDBY FOR WINDS. WINDS DROPPED BELOW 30 MPH, MIRU. DRIFTED W/BLB & 3.79" GAUGE RING TO TOP OF FISH @ 8,799' SLM RAN BAITED WFD RELEASABLE SPEAR AND RECOVERED 13" & 34" SECTION OF FISH TO INCLUDE SEAL ASSEMBLY & MULE SHOE @ 8,908' SLM RAN 2.50" MAGNET TO 8,910' SLM, NO RECOVERY. DRIFTED W/2-1/2" SAMPLE BAILER TO 8,910' SLM / 8,923' MD, NO SAMPLE. RAN 2.50" MAGNET TO DEVIATION @ 9898'SLM/9913'MD, NO RECOVERY. LRS LOADED TBG W/150 BBLS OF HOT CRUDE, BRUSHED DEPLOYMENT SLEEVE @ 8,908' SLM / 8,923' MD. BRUSHED LINER DOWN TO 8,960' SLM. *** CONTINUE ON 2/23/2023 *** 2/22/2023 Assist Slickline(PATCH TUBING/LINER) Pumped 150 bbls 180* Crude down TBG to assist w/ brush n flush. ***Job continued to 02-23-2023*** 2/23/2023 *** CONTINUE FROM 2/22/2023 *** RAN READ CASED HOLE 1.69" - 24 ARM CALIPER LOG FROM 9900'SLM TO SURFACE (good data) *** WELL LEFT S/I ON DEPARTURE*** 2/23/2023 ***Continued job from 02-22-2023*** Assist Slickline (PATCH TUBING/LINER) SB for SL. SL in control of well per LRS deaprture. IA,OA=OTG 6/13/2023 ***WELL S/I ON ARRIVAL*** RAN 3-1/2" BRUSH w/ 2.5" GAUGE RING TO X-NIPPLE @ 8,954' MD WHIILE T- BIRD LOADED TBG w/ 176 bbls CRUDE SET 3-1/2" XX PLUG w/ 18" FILL EXTENSION IN X-NIPPLE @ 8,954' MD SET 4-1/2" D&D PACK OFF LTP IN DEP SLEEVE @ 8,923' MD T-BIRD PT TO 1,500 psi (pass) PULL 4-1/2" D&D PACK OFF LTP IN DEP SLEEVE @ 8,923' MD (40 minutes of heavy jarring, missing small pieces of element) RAN 3 1/2" GR W/ EQ. PRONG S/D @ 8,954' MD (no psi change, no ring on eq. prong) RAN 4 1/2" BLB, 3.75" GAUGE RING, BRUSH MANDRELS S/D @ 8,923' MD ***CONTINUE 6/14/23*** 6/13/2023 T/I/O= 500/350/0 TFS Unit#4 Assist Slick Line (Load and Test) Pumped 180 BBLS of Crude down the TBG to Assist Slick Line Pressure test Liner Top Packer. Slick Line in Control of well upon departure. FWHP=100/350/0 Daily Report of Well Operations PBU B-20A 6/14/2023 ***CONTINUE FROM 6/13/23*** RAN 2 1/4" BAILER (MSFB), S/D IN DEPLOYMENT SLEEVE @ 8,923' MD (no recovery) PULL 3 1/2" XX PLUG (w/fill extension) @ 8,954' (small pieces of element inside) SET D&D PACK-OFF w/ STANDARD QCLL (oal = 41", min id = 2.37") IN DEP SLEEVE @ 8,923' MD SET 4-1/2" TBG STOP ON TOP OF D&D PACKOFF (min id = 2.37") ***WELL S/I ON DEPARTURE*** The new LTP is correctly shown on the new WBS, below. -WCB ()@( SET D&D PACK-OFF w/ STANDARD QCLL (oal = 41", min id = 2.37") IN DEP SLEEVE @ 8,923' MD Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aIZ SJ alp Well History ile Identifier Organizing (done) wo-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: C or Items: ❑ Mas: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: // l BY: C Maria� Date: tb /9 /s/ J4f) 11 Project Proofing BY: OM Date: ci /ib/itt ,'s,' rif Scanning Preparation I x 30 = 3• + 2 (p =TOTAL PAGES 5-(61 ,1i (Count does not include cover sheet) BY: Maria Date: /1/ /s/ Production Scanning Stage 1 Page Count from Scanned File: (57 (Count does include cover heet) Page Count Matches Number in Scanni g Pr paration: YES qrne NO BY: WM Date: 16, At lsl Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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O Z CO N 7 N U N c O o i 2 z i Q U O CjI = ci N Y m F- 5 c ° 0= a 8 O o 0 i �w o It J a W w J V a. m 0 Z 16 Q .i _ " N N J °- a 1 O 0. c II 2oli O N p� EI V 0 v U o J a Q O ro N 0- I— m Z N 5� z p G N COa ) W m CO o LD 1 a a> Q C a C.1 z o EU m z 3 4, oI O) N m O N 3 N N d C4 o a I to cU t0 U H . c� `m QE I o QO a 2 c.° • STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COMMIS I JUN 2 6 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair WeICJ Plug Perforations ❑ Perforate OtheC Performed: Alter Casing❑ Pull TubinC Stimulate-Frac ❑ Waiver❑ Time ExtensioC Change Approved Program❑ Operat.Shutdowi❑ Stimulate-Other ❑ Re-enter Suspended Wet] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Development Exploratory 212-026-0 3.Address: P.O.Box 196612 StratigraphiG Service❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20842-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028310 PBU B-20A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): r 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 11708 feet Plugs measured None feet true vertical 9041.68 feet Junk measured None feet Effective Depth measured 11668 feet Packer measured See Attachment feet true vertical 9041.52 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 35-115 35-114.98 0 0 Surface 2639 13-3/8"72#L-80 39-2678 39-2677.46 4930 2670 Intermediate 9156 9-5/8"47#L-80 34-9190 34-8440.43 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10550-10580 feet 10640-10670 feet _ 10760-10790 feet 11066-11096 feet 11150-11180 feet 11270-11300 feet 11380-11470 feet 11525-11650 feet True Vertical depth 9042.71-9041.88 feet 9043.18-9044.25 feet 9043.04-9042.74 feet 9042.65-9042.95 feet 9043.22-9043.36 feet 9042.94-9042.53 feet 9041.7-9041.48 feet 9041.33-9041.43 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 34-9044 34-8306.99 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: 739 10619 67 0 220 Subsequent to operation: 419 10790 1694 0 235 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 El WAG ❑ GINJ❑ SUSP ❑ SPLUf 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 Garry Catron Email Garry.Catron@BP.Com Printed Name Garry Catron Title PDC PE Signature U a at1 Phone 564-4424 Date 6/25/2014 f RBCMS JUN 26 ZU VLF 7-/ dt Form 10-404 Revised 10/2012 I Z( / Submit Original Only • Packers and SSV's Attachment ADL0028310 SW Name Type MD TVD Depscription B-20A PACKER 8842 8123.89 4-1/2" Baker S-3 Perm Packer _ B-20A PACKER 8915 8189.94 45 Flo-Guard WL Top Packer d 0) R � � � M -co C NrCO LO , N ti U 7 MoNNOOoMC) ,t M OO , ti00 � NrCO O M M M O) CO (O O) O NrN i-- N (O O) O 115 66 O (D f� (D NI- NOOO (DM CO 00 00 O O N O i I I I I l 1 OD 01 CD N N M CCI 0 Q up 0 M M O 000 (00 CD OrsCOcraO � � (A (D " DOD00 OD O O CO OC) , N O) ✓ 0 O z i i . i M Nr 03 EnN MMa000000C) M C O 12 = Q O O 0 0000`0 • OM *k * —1 *k * A * 'N N Xn (r) (O [tti � -O 'Cr O (O (D OD _ pO (V OD NU5e- r-.—r. V O M M N v- 4 t coo M M - O N M C00 , 02M4 (OO J O) N O) W Q c O 0 W To U w w Q U0WWWWWzwwwww W _ QIzzzz » U J J J J coH 2 k / / - / / \ / ? A \ 2 (N II p .g (N 2 0) ( t \ oS � ® E I a- 0 co / s R 2 -® .R / 7 �» -0 tu) CD a) c E 2 C c � \ / / � k � � - / w7 � % E Ili w o$ E E :° < / - \_ k �� / \ / / O / » � ® ± , $ / \ § \ / 2 = 2 \ o » a_ % ƒ � e 0 k cc \ is m @ k\ ® pS k 2 5 / « S + ƒ t O / T\ / E / '' / / / / ci W R % — f S / / 7 5 - I - >, / ° o \ / / 02 \ .c (N co .0- 2 9 \ ) co I I \ r 13 / / cE E § / ) 2O § \ I ± E 4- - 3 _ ? 2 L) 0 • / 'C $ o • o c = \ CO 60 \ ƒ /cn 1E \ J- \ E & •g . \ o E % S $ = = E¥ � ocl = _ ® 0) Ebf \ ? C / o «w e e = N- as 2 R O o / 2 \ O ± R R .- I * UCC o_.- : w # # / / a 6 / / TREE= 4-1/16"Clw B�2 0A W� MK: WELD-EA = EVOY SA NOTES: WELL ANGEL>70°9890' ACTUATOR= BAKER C ""4-1/2"CHROME TUBING"' = 80.03' BF. BF.ELei EY== 44.53' KOP= 3100' [20"CONDUCTOR - ? , 2022' --(4-1/2"FES X NP,D=3.813" Max Angle= 95°@ 10202' - Datum M3= 9658' Datum TVD= 8800'SS 1- 2610' (-98"DV COLLAR 1 S 13-3/8'CSG,7211, L 8o BUTT,ID=12.34r -{ 2678' , GAS LFT MANDF� ST MD ND DEV TY FE VLV LATCH PORT DATE 4 3220 3216 11 MAG DOME RK 16 06/18/12 3 5853 5604 31 MMG SO RK 20 06/18/12 2 7556 7019 34 MG DAY RK 0 12/25/11 1 8718 8013 27 MAG DM' RK 0 12/25/11 8799' H4-1/2"HES X NP,D=3.813" Minimum ID = 2.36" @ 8915' 45 FLU-GUARD WL LTP 8830-7-1-0 5/8"x 4-1/2"BKR S-3 PKR,ID=3.875" 8865' H4-1/T H6 X NP,D=3.813" 8915' -145 FLO-GUARD WL LTP,D=2.36'(12/27/12) 8923' H 3.70'BKR DEPLOY SLV,ID=3.00' TOP OF 7'LNR H 8933' r 8933' -{9 5/8"X 7"LNR TOP HGR,D= k i! 8954' -3-112'HES X NIP,D=2.813' U I 8980' -4-1/2'HES XN NP,MLLED TO 3.80"(4/16/12) G I If I 3-1/2'LNR,9.2#,L-80 SIL, .0087 bpf,ID=2.992 H 8987' I ` 8987' --13-1/2"X 3-3/16')5),D=2.786' I 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 9033' ►�� 9033' H4-1/2"WLEG=3.958'- 0152 bpf,D=3.958" II "40 � 40`f� 9-5/8"CSG,47#,L-80 BUTT,ID=8.681" -I 9190' - %` 40 , (44 ► -- 9581'--r MARKER JONT r4 1/2"X 7'WHIPSTOCK(TAGGED 06/02/12) -j 9668• It dr, Vilb r LNR,26#,L-80 BUTT, .0383 bpf,ID=6.276" H -9668 3-1/4"LNR,6.6#,L-80 TC11,.0079 bpf,D=2.850 10287' fi MMLLOUT WINDOW(B-20A) 9668'-9675' PERFORATION SUMMARY — -T REF LOG:SLB CCL/GR/MCPL ON 06/10/12 ANGLE AT TOP PERF: 92°@ 10550' Note:Refer to Roduction DB for historical perf data 10287' -3-3/16'X2-7/8"XJ,ID=2.377' SIZE SPF NTBNAL Opn/Sqz SHOT SOZ 2" 6 10550- 10580 0 12/08/12 2" 6 10640- 10670 0 12/08/12 ' r 6 10760- 10790 0 12/08/12 2" 6 11066- 11096 0 05/26/14 2" 6 11150- 11180 0 05/26/14 ' 2" 6 11270- 11300 0 05/26/14 2" 6 11380-11470 0 06/10/12 2" 6 11525- 11650 0 06/10/12 ' /• PBTD -{ 11668' 2-718"LNR,6.4#, L-80 SIL, .0058 bpf, ID=2.441 11708' DATE REV BY OGPJv NTS DATE REV BY COMMENTS PRIMJHOE BAY UNIT 11/26/82 AUDI#2 INTIAL COMPLETION 03/12/14 LEC/JMO ADDED LTP D WELL: B-20A 10/01/08 D16 RWO 05/29/14 JTC/JMD ADPERFS(05/26/14) FERMI No: 2120260 06/12/12 NORDIC 2 CTD SIDETRACK(B-20A) AR No: 50-029-20842-01 12/14/12 RRW/JPA)ADPERFS(12/08/12) SEC 31,T11N,R14E,564'FNL&1895'FB_ 01/15/13 AMJM? FLO GUARD LTP(12/27/12) 04/20/13 PJC FERF CORRECTIONS BP Exploration(Alaska) REcEivaD BAKER PRINT DISTRIBUTION LISTN 10 Z 3 HUGHES AOGCC COMPANY BP Exploration(Alaska)Inc. INTERMEDIATE FINAL Yes (mandatory) Zk 2-- 92 c WELL NAME —2_CD - RUN NUMBER \ (mandatory) Z_Z \ 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: 6/5/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSONATTENTION #OF PRINTS #Ur nNrlinl i S #OF COPIES #OF COPIES t� BP Exploration(Alaska)Inc. I 3 1 I Petrotechnical Data Center LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 1 I Attn Ricky Elgarico PO Box 100360 Anchorage,Alaska 99510 3 ExxonMobil,Alaska I 1 I 1 I I I Attn Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 4 State of Alaska-AOGCC I 1 I 1 I I Christine Shartzer 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas I I 1 I I Attn:Sean Clifton 550 W.7th Ave,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 HUGHES a( ,- 0' 0)4, www.bakerhughes.com PRINT DISTRIBUTION LIST -4=6- tx.).. COMPANY BP EXPLORATION(ALASKA), INC COUNTY NORTH SLOPE BOROUGH WELL NAME B-20A STATE ALASKA FIELD PRUDHOE BAY UNIT DA I E 11/2/2012 THIS DISTRIBUTION LIST AUTHORIZED BY: Alfredo Martinez SO#4692796 CopiesLog Log Data CD Client/ Partners Copies Data CD Client/ Partners Company BP EXPLORATION(ALASKA), INC Company Person PETROTECHNICAL DATA CENTER Person 2 1 Address LR2-1 Address 900 E BENSON BLVD ANCHORAGE,AK 99508 Company EXXON MOBIL PRODUCTION CO Company 1 1 Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082 A HOUSTON,TX 77002 Company STATE OF ALASKA-AOGCC Company 1 1 Person CHRISTINE MAHNKEN Person Address 333 W.7TH AVE. Address SUITE 100 ANCHORAGE,AK 99501 Company DNR-DIVISION OF OIL&GAS Company Person CORAZON MANAOIS Person 1 Address 550 WEST 7TH AVE. Address SUITE 800 ANCHORAGE,AK 99501 Company ConocoPhillips Alaska Inc. Company Person Ricky Elganicio Person 1 Address PO Box 10036 Address Anchorage,AK 99510 Company Company Person Person Address Address Page 1 of 1 bp Date 10-04-2012 Transmittal Number:93260 ( 2\ 0 ‘&I RECEIVED BPXA WELL DATA TRANSMITTAL OCT 04 Enclosed are the materials listed below. AOGCC (BPXA FIELD LOG DATA) ,a C (If you have anyquestions,please contact DougDortch at the PDC at 564-4973 C/'SCJ�� Delivery Contents 1 CD-ROM Containing Field Log Data& Electronic Log Prints for the following wells: 07-22A '/Z 4-'r` 07-35A -- 13-15A • 13-15APB1 Z.a--IZ.( �vt/% �= , <z /� � cv4(014 13-15APB2 _4;4161W7-1 U5 - Zl2-c)-7Z) B-20A ',2/2— C-01B Z/?C-01B • 2_12- S-3 C-Q1 BPB1 C-27C 2- F-08B 2/2_--c)VC.) C'.O-,zoite /0c-_aI f( -DCl' 2i(- /2,6 U,-l7- l3 Please Signand Return one copyof 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 lb. Well Class: 20AAC 25.105 20AAC 25.110 ®Development 0 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. 6/30/2012 212-026 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 6/4/2012 50-029-20842-01-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 6/8/2012 PBU B-20A 564' FNL, 1895' FEL, Sec.31,T11N, R14E, UM 8. KB(ft above MSL): 80 15.Field/Pool(s): Top of Productive Horizon: 891'FSL,974' FWL, Sec.29,T11N, R14E, UM GL(ft above MSL): 43.03' Prudhoe Bay/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): 1239'FSL,2221'FWL, Sec.29,T11N, R14E, UM 11663' 9042' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 663734 y- 5950080 Zone- ASP4 11708' 9042' ADL 028310 TPI: x- 666566 y- 5951597 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 667804 Y- 5951973 Zone- ASP4 None 18. Directional Survey: ®Yes 0 No 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 9668' 8889' 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 20"x 30" Insulated .Conductor Surface 110' Surface 110' 36" 9 cu yds Concrete 13-3/8" 72# L-80 Surface 2678' Surface 2677' 17-1/2" 3720 cu ft Permafrost II 9-5/8" 47# L-80 Surface 9189' Surface 8440' 12-1/4" 1242 cu ft Class'G' 7" 26# L-80 8933' 9668' 8206' 8889' 8-1/2" 381 cu ft Class'G' 3-1/2"x 3-1/4" 9.3#/6.6# L-80 8923' 11708' 8197' 9042' 4-1/4" 131 sx Class'G' x 2-7/8" 6.4# 24. Open to production or injection? 0 Yes 0 No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 2"Gun Diameter,6 spf 4-1/2", 12.6#, 13Cr80 9033' 8830'/8113' MD TVD MD TVD 11380'-11470' 9042'-9041' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 11525'-11650' 9041'-9041' RECEIVEDDEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED } 2500' Freeze Protect w/40 Bbls of Diesel i JUL 2 5 2012 I ,Ma AOGCC - 27. . PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): July 2, 2012Flowing Date of Test: Hours Tested: Production For •OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 7/24/2012 4 Test Period 4 84 821 397 95 9830 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 200 1640 24-Hour Rate ♦ 501 4926 2383 N/A 28. CORE DATA Conventional Core(s)Acquired? 0 Yes 0 No Sidewall Core(s)Acquired? 0 Yes 0 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 R8DMS JUL 2 7 Form 10-407 Revised 12/2009 ri,,er g//9/L3 CONTINUED ON REVERSE gi› Submit Original OnIYC Z9. GEOLOGIC MARKERS(List all formations an -kers encountered): 30. FORMATION TESTS NAME TVD Well Tested? LJ 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. Zone 2A 9960' 9062' None 22P 11708' 9042' Formation at Total Depth(Name): Zone 2A/22P 11708' 31.List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32. I hereby certify that th • :•oing i tr - - • • rect to the best of my knowledge. I Signed: Joe Lastufka - I Title: Drilling Technologist Date: / /J PBU B-20A 212-026 Prepared By Name/Number: Joe Lastufka, 564-4091 Well Number Permit No./Approval No. Drilling Engineer: Zach Sayers, 564-5790 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 TREE 4-MC 20A WELLHEAD= MCEVOY OY, B-20A r NOTES: WELL ANGEL>70"9890'*''* ACTUATOR= BAKER C h 4-112" CHROME TUBING*** KB. ELEV= 8003' PJC DRAFT BF. ELEV= 44.53'. 1 KO KOP= 3100= Max Angle= 95°@ 10202', 20"CONDUCTOR 1- ? ' 2022' I-4-1/2"HES X NIP, ID=3.813" Datum MD= 9658, Datum TVD= 8800'SS 2610' I-9-5/8" DV COLLAR GAS LIFT MANDRELS 13-3/8"CSG, 72#, L-80 BUTT,ID= 12,347" 1--I 2678' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3220 3216 11 MMG DOME RK 16 06/18/12 3 5853 5604 31 MMG SO RK 20 06/18/12 2 7556 7019 34 MMG DMY RK 0 12/25/11 1 8718 8013 27 MMG DMY RK 0 12/25/11 8799' -14-1/2"HES X NIP, ID=3.813" Minimum ID = 2.36" @ 8910' 4-1/2" BKR KB LTP 8830' H9 5/8"x 4-1/2"BKR S-3 PKR, ID=3.875" ' 8865' -4-1/2"HES X NIP, ID=3.813" 8910' H4-1/2"BKR KB LTP, ID=2.36"(06/30/12) 8923' 3.70" BKR DEPLOY SLV,ID=3.00' TOP OF 7"LNR -1 8933' }- Re � 8933' -19 5/8"X 7'LNR TOP HGR,ID=? k ( � 8954' --�3-1/2" LIES X NIP, ID=2.813" N 8980' -4.1/2" HES XN NIP, MILLED TO 3.80"(4/16/12) ( 3-1/2"LNR,9 2#, L-80 STL, .0087 bpf,ID=2.992 8987' kl 8987' -13-1/2"X3-3/16"XO, ID=2.786" w 4-112"TBG,12.6#, 13CR-80 VAM TOP, -I 9033' U. -� 9033' 1-4-1/2"WLEG=3.958" 0152 bpf,ID=3.958" et kilt! 9-518"CSG,47#,L-80 BUTT, ID=8.681" H 9190' 4 A4 e I4-1/2"X 7"WHIPSTOCK(TAGGED 06/02/12) -1 9668' 95$1' -7"MARKER JOINT 4 7" LNR, 26#, L-80 BUTT, .0383 bpf.ID=6.276', 9668 419 MILLOUT WINDOW (B-20A) 9668'-9675" 3-1/4" LNR,6.6#, L•50 TG11. .0079 hpf, ID=2.850 H 10287'• 10287' H3-3/16"X2-7/8"XO,ID=2.377" PERFORATION SUMMARY REF LOG: MEM CCL/GR/TNF/TNN ON 06/20/12?? ANGLE AT TOP PERF: 91°@ 11380' Note. Refer to Production DB for historical pert data SIZE SPF INTERVAL I Opn/Sqz DATE 2" 6 11380-11470 0 06/10/12 2" 6 11525-11650 0 06/10/12 PBTD - 11668' 2-7/8"LNR,6.4#, L-80 STL, .0058 bpf,ID=2.441 - 11708' 411 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11126/82 AUDI'#2 INITIAL COMPLETION , 07/18/12 JMD LTP DEPTH CORRECTION WELL: B-20A 10101108 D16 RWO PERMIT No:'2120260 06/12/12 NORDIC 2 CTD SIDETRACK(B-20A) AR No: 50-029-20842-01 06/16/12 PJC DRLG DRAFT CORRECTIONS ' SEC 31,T11 N, R14E,564'FNL&1895'FEL 06/20/12 THH/JMD GLV C/O(06/18/12) 07/02/12 MSS/JMD SET BKR KB LTP(06/30/12) BP Exploration (Alaska) North America -ALASKA- BP Page 1 of 6 Operation Summary Report f. Common Well Name: B-20 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 6/2/2012 End Date: 6/8/2012 X3-011 WC-C: (2,012,775.00) i - Project:Prudhoe Bay Site:PB B Pad Rig Name/No.: NORDIC 2 Spud Date/Time:9/23/2008 12:00:00AM Rig Release: 6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (ft) 6/2/2012 00:00 - 02:00 2.00 MOB P PRE BEGIN RON EVENT WITH NORDIC 2 CTD RIG 'AT 00:00 ON 06/02/2012 CLEAR J-27 LOCATION AND SIGN OFF WWT PERMIT WITH PAD OPERATOR 02:00 - 02:30 0.50 MOB P PRE RIG MOVE PJSM, REVIEW PROCEDURE, COMMUNICATION 02:30 - 06:00 3.50 MOB P PRE MOVE RIG OFF OF J PAD AND DOWN SPINE TOWARD B PAD 06:00 - 06:30 0.50 MOB P PRE STOP ON B PAD ACCESS RD ABOUT 1 MILE FROM B-20 FOR SHIFT CHANGE. CONDUCT SHIFT CHANGE AND RIG WALK AROUNDS. 06:30 - 09:30 3.00 MOB P PRE .CONTINUE ON TO B PAD. STAGE RIG ON THE SIDE OF THE PAD AND PUT HERCULITE AND RIG MATS DOWN AROUND B-20 WELL. 09:30 - 10:00 0.50 MOB P PRE PJSM FOR MOVING OVER WELL WITH RIG CREW, NORDIC SUPT.NORDIC TOOLPUSHER AND WSL DISCUSS SPOTTER LOCATIONS AND DUTIES. DISCUSS USE OF THE E-STOP SYSTEM. 10:00 - 10:30 0.50 MOB P PRE 'MOVE RIG OVER WELL AND SET RIG DOWN. -ACCEPT RIG AT 10:00. 10:30 - 12:00 1.50 MOB P PRE RIG UP. PREP TO REMOVE TREE CAP. 12:00 - 16:00 4.00 MOB P PRE TEST SWAB VALVE PRIOR TO REMOVING TREE CAP. DIFFICULT TO GET A GOOD HIGH PT. TRY CYCLING BOTH SWAB AND SSV, NO LUCK. GREASE CREW COMES OUT TO GREASE THE SWAB AND SSV. TEST IS GOOD. 16:00 - 20:00 4.00 BOPSUR P PRE REMOVE SWAB CAP AND RIG UP BOPS AND TEST SHELL 20:00 - 00:00 4.00 BOPSUR P PRE PJSM AND TEST BOPE TO 250#/3500#-TEST HIGH PRESSURE SCREENS IN THE REEL HOUSE TO 350#/3800#-FUNCTION TEST BOP CONTROLS FROM BOTH REMOTE PANELS-ALL TESTS PASSED 6/3/2012 00:00 - 01:00 1.00 BOPSUR P PRE CONTINUE BOP TEST. TEST INNER REEL VALVE AND CT STRIPPER. 01:00 - 01:30 0.50 BOPSUR P PRE RIG EVAC DRILL. 01:30 - 03:15 1.75 BOPSUR P PRE PJSM THEN PUMP SLACK BACKWARDS AND CUT 280'CT OFF TO FIND IT. 03:15 - 05:00 1.75 BOPSUR P PRE INSTALL CT CONNECTOR. PULL TEST TO 30K.GET ON WELL AND PUMP WIRE FORWARD. 05:00 - 06:00 1.00 BOPSUR P PRE MAKE UP UQC, PRESSURE TEST CT CONNECTOR AND UQC. 06:00 - 07:00 1.00 BOPSUR P PRE INSTALL CHECK VALVES IN UPPER QUICK CONNECT. M/U CT RISER TO WELL TO TEST CHECK VALVES. PRESSURE TEST CHECK VALVES 300/3900 PSI,GOOD. Printed 7/16/2012 2:41:05PM • Page 2 of 6 North America -ALASKA- BP4111 • ��. 9 Operation Summary Report Common Well Name: B-20 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:6/2/2012 End Date:6/8/2012 X3-011 WC-C: (2,012,775.00) Project:Prudhoe Bay Site: PB B Pad Rig Name/No.: NORDIC 2 Spud Date/Time:9/23/2008 12:00:OOAM Rig Release:6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 08:00 1.00 RIGU P PRE PJSM FOR PULLING TWC. LOAD BPV LUBRICATOR TO RIG FLOOR, MAKE UP STEM EXTENSIONS. VERIFY MEASUREMENTS TO SWAB VALVE. WILL USE SWAB AND MASTER VALVE AS BARRIERS. INSTALL LUBRICATOR. PRESSURE TEST 280 -/3750 PSI AGAINST CLOSED SWAB AND MASTER VALVE. GOOD TEST. 08:00 - 09:30 1.50 RIGU P PRE PULL TWC UP ABOVE SWAB VALVE. 250 PSI ON WELL. CLOSE MASTER VALVE AND BLEED OFF PRESSURE. CLOSE SWAB TO RE-ESTABLISH 2 BARRIERS. CONDUCT AAR AND DOCUMENT LESSONS LEARNED. 09:30 - 09:40 0.17 RIGU P PRE OFFLOAD BPV LUBRICATOR AND PULLING ROD EXTENSIONS. 09:40 - 10:00 0.33 RIGU P PRE RIG EVACUATION EXERCISE. EVERYONE ON RIG CREW MUSTERS ALONG WITH TRUCK DRIVER AND NEARBY CAMERON CREW. ACCURATE HEADCOUNT,ALL PERSONS ACCOUNTED FOR IN 3 MIN. CONDUCT AAR. 10:00 - 10:40 0.67 RIGU P PRE INSTALL NIGHT CAP AND PT TO 300/3500 PSI,GOOD. 10:40 - 11:20 0.67 RIGU P PRE PJSM FOR BULLHEADING THE WELL. LINE UP TO BULLHEAD AS PER WELL PROGRAM. PUT 360 PSI WHP AND OPEN UP MASTER AND SWAB VALVE. 11:20 - 12:20 1.00 RIGU P PRE INITIAL WHP IS 280 PSI. PUMP 5 BBLS MEOH. PUMP 92 BBLS 1%KCL AT 4.5 BPM USING BOTH PUMPS. INITIAL WHP IS 280 PSI RISING SLOWLY PAST 700 PSI AFTER 20 BBLS AWAY. 50 BBLS AWAY,WHP FAIRLY STABLE AT 1350 PSI,4.5 BPM. 92 BBLS AWAY,SWAP TO MUD. MAINTAIN 4.5 BPM,WHP 1465 PSI STARTING TO DECREASE SLOWLY. 90 BBLS MUD AWAY,WHP IS STEADY AT 1240 PSI,4.6 BPM. 12:20 - 12:35 0.25 RIGU P PRE 170 BBLS MUD AWAY. SHUT DOWN PUMPS. FINAL WHP WHILE PUMPING IS 1250 PSI. PRESSURE RISING SLOWLY AT THE END, MUD AT THE PERFS. BLEED OFF PRESSURE,1.8 BBLS OF FLUID. 12:35 - 13:05 0.50 RIGU P PRE PRESSURE BLED OFF,START FLOW CHECK. 13:05 - 13:35 0.50 RIGU P PRE NO FLOW AFTER 30 MIN. FILL WELL WITH 4 BBLS ACROSS TOP. PJSM FOR M/U BHA#1. 13:35 - 15:00 1.42 STWHIP P WEXIT FILL WELL WITH 2.7 BBLS THEN M/U BHA#1 - WINDOW MILL. MILL IS 3.80 GO,3-79 NO-GO. NORDIC CREW CHANGE WHILE M/U BHA. M/U CT RISER. PRESSURE TEST QTS CONNECTION, GOOD. Printed 7/16/2012 2.41:05PM ` North America -ALASKA- BP Page 3 of 6 Operation Summary Report Common Well Name:B-20 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:6/2/2012 End Date.6/8/2012 X3-011 WC-C: (2,012,775.00) Project:Prudhoe Bay ' Site:PB B Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/23/2008 12.00:OOAM Rig Release:6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum: Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 17:00 2.00 STWHIP P WEXIT RIH,BHA#1. STOP AT 250 FT AND LOAD PITS WITH 50 MORE BBLS. WELL IS TAKING 6-10 BBL/HR. 17:00 - 18:30 1.50 STWHIP P WEXIT TIE-IN DEPTH FROM 9290 FT.-CORR=+2.5- UP WT CHECK=42K,RIH WT=23K-RIH TO 9665'OBTAIN SLOW PUMP RATES AT 9550' PUMP 1: 2.6 BPM=2290#, 1.0 BPM= 1183#, 0.5 BPM=850# PUMP 2: 2.6 BPM=2278#, 1.0 BPM= 1176#, 0.5 BPM=835# 18:30 - 21:50 3.33 STWHIP N DPRB 9,665.00 WEXIT GAS MONITOR AT SHAKER ALARMED AND REGISTERING 16 PPM-MM OUT RATE VERY ERRATIC FROM 1.3 TO 5.5 BPM-CLOSE BAKER CHOKE AND REGISTERED 20 PSI- FLUSH MM AND NOTIFY NS SUPT-RU AND CIRCULATE GAS CUT MUD THROUGH MUD GAS SEPARATOR AT 1 BPM X 1240 PSI HOLDING 100 BACK PRESSURE ON WELL- CIRCULATE BU -FLOW CHECK WELL-WELL DEAD 21:50 - 22:40 0.83 STWHIP N DPRB 9,665.00 WEXIT FLUSH MGS WITH FRESH WATER 22:40 - 22:50 0.17 STWHIP P WEXIT .RIH FROM 9665'-TAG WHIPSTOCK AT 9673.2' 22:50 - 00:00 1.17 STWHIP P WEXIT START MILLING WINDOW IN 7'CASING W/ 3.79"MILL PER BTT AND WELL PLAN -INITIAL PARAMETERS: FS=2340, PSI,80# DHWOB,450 PSI MW DRILLING PARAMETER DATA SHEET IS ATTACHED 6/4/2012 00:00 - 06:00 6.00 STWHIP P WEXIT MILL WINDOW PER BTT AND WELL PLAN- CURRENTLY NO FLUID LOSSES, 2.61 IN=2.61 OUT,FS=2500 PSI,2100#WOB, 160 PSI MW DRILLING PARAMETER DATA SHEET ATTACHED 06:00 - 09:00 3.00 STWHIP P WEXIT CONTINUE MILLING WINDOW PAST 9680' 09:00 - 10:00 1.00 STWHIP P WEXIT CONDUCT KICK WHILE DRILLING DRILL HOLD AAR. 10:00 - 11:00 1.00 STWHIP P WEXIT CONTINUE MILLING RAT HOLE AT 9688' SAMPLE IS 80%FORMATION. 11:00 - 12:00 1.00 STWHIP P WEXIT BACK REAM WINDOW. TRACE OF GAS IN RTNS. FLOW CHECK SHOWS NO FLOW. LINE UP TO GAS BUSTER. CONTINUE TO BACK REAM. 12:00 - 12:30 0.50 STWHIP P WEXIT DRY DRIFT WINDOW. SMOOTH. 12:30 - 14:30 2.00 STWHIP P WEXIT CIRC OOH THRU MGS. HOLE FILL NORMAL. 14:30 - 15:30 1.00 STWHIP P WEXIT PJSM FOR BHA LD. LS MOTOR AND MILLS. 15:30 - 17:00 1.50 STWHIP P WEXIT CHANGE OUT SLB RISERS TO CHANGE FLOOR HEIGHT ACCESS. 17:00 - 18:00 1.00 DRILL P PROD1 MU BUILD BHA WITH 2.6 DEG XTREME AND HYCALOG BI-CENT WITH CONTROL BUTTONS. STAB COIL. GET ON WELL. TEST QTS. PASSED. Printed 7/16/2012 2:41:05PM • • North America -ALASKA- BP • Page 4 of 6 Operation Summary Report Common Well Name: B-20 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/2/2012 End Date: 6/8/2012 X3-011 WC-C: (2,012,775.00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.: NORDIC 2 Spud Date/Time:9/23/2008 12:00:00AM Rig Release:6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 20:00 2.00 DRILL ' P PROD1 RUN IN HOLE. LOG TIE IN. ADD 2.5' CORRECTION. 20:00 - 23:00 3.00 DRILL P PROD1 SHAKER GAS DETECTOR SHOWS TRACE GAS.THEN 4%LEL. DISCUSS WITH TOWN. DECIDE TO WEIGHT UP MUD TO 9.0 PPG 23:00 - 00:00 1.00 DRILL P PROD1 DRILL AHEAD WHILE WEIGHTING UP MUD. 6/5/2012 00:00 - 03:00 3.00 DRILL P PROD1 CONTINUE DRILLING AHEAD WHILE WEIGHTING UP. DRILL TO 9850 FT. 03:00 - 06:45 3.75 DRILL P PROD1 LOG LONG TIE-IN FROM 9000 FT. 06:45 - 10:00 3.25 DRILL P PROD1 CONTINUE DRILLING FROM 9850 FT. 10:00 - 10:40 0.67 DRILL P - PROD1 DRILL TO TD OF BUILD SECTION AT 9960 FT. PICK UP 5 FT AND PERFORM 5 MIN FLOW CHECK. FLOW CHECK IS GOOD,NO FLOW. CONTINUE WIPER TRIP BACK TO WINDOW. PULL THROUGH WINDOW CLEAN AT 0.5 BPM /30R. PERFORM A JOG ABOVE THE WHIPSTOCK THEN STOP AND OPEN EDC,FLOW CHECK WELL. FLOW CHECK IS GOOD,NO FLOW. 10:40 - 12:15 1.58 DRILL P PROD1 POOH. PUMP 3.1 BPM WHILE POOH. 12:15 - 13:00 0.75 DRILL PROD1 STOP AT 50'. FLOW CHECK. HOLD PJSM. GET OFF WELL. UNSTAB COIL. LD BHA TOOLS. 13:00 - 13:45 0.75 DRILL P PROD1 MU LATERAL BHA(#3) 1.2 DEG AKO WITH XL MOTOR AD HYCALOG BICENTER BIT. INCLUDE RESISTIVITY TOOLS. STAB COIL. TEST TOOLS. GET ON WELL. PT QTS. PASSED. 13:45 - 15:45 2.00 DRILL P PROD1 RUN IN HOLE. PVT:493 BBLS. 15:45 - 16:30 0.75 DRILL P PROD1 LOG GR TIE IN FROM 9270'. ADD 3' CORRECTION. RUN IN HOLE. 16:30 - 17:30 1.00 DRILL P PROD1 SLIGHT GAS IN RTNS. ROUTE RTNS THROUGH MGS. LOG MAD RESISTIVITY LOG WHILE CIRCULATING. LOG TO 9700' 17:30 - 17:45 0.25 DRILL P PROD1 RUN IN HOLE TO BTMS AT 9960'. RECORD SLOW PUMP RATES ON BOTH MUD PUMPS. 17:45 - 20:00 2.25 DRILL P PROD1 DRILL AHEAD FROM 9960'. 2550 PSI FS AT 2.80 BPM IN/OUT. 200 PSI MTR WORK. DHWOB: 1.62K#. PVT:545 BBLS. PVT=541, IA=6,OA=-2,WHP=51 20:00 - 21:00 1.00 DRILL P PROD1 WIPER TO WINDOW FROM 10150' 21:00 - 22:30 1.50 DRILL P PROD1 DRILL AHEAD FROM 10150' 2440 PSI FS AT 2.5 BPM IN/OUT 22:30 - 23:20 0.83 DRILL P PROD1 WIPER TO WINDOW FROM 10300' 23:20 - 00:00 0.67 DRILL P PROD1 DRILL AHEAD FROM 10300' 2430 PSI FS AT 2.5 BPM IN/OUT PVT=533,WHP=44,IA=7,OA=-2 6/6/2012 00:00 - 01:30 1.50 DRILL P PROD1 DRILL AHEAD FROM 10344 Printed 7/16/2012 2:41:05PM ` North America -ALASKA- BP Page 5 of 6 ... Operation Summary Report r Common Well Name:B-20 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:6/2/2012 End Date:6/8/2012 X3-011 WC-C: (2,012,775 00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/23/2008 12:00:00AM Rig Release:6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code ' NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 02:30 1.00 DRILL P PROD1 WIPER FROM 10344 TO TT @ 9000' 02:30 - 03:00 0.50 DRILL P PROD1 LOG TIE IN=+3.5'CORRECTION 03:00 - 05:00 2.00 DRILL P PROD1 ON BOTTOM DRILLING,2430 PSI FS @ 2.5 BPM,WH=44#, IA=9,OA=1,PVT=524 BBLS 05:00 - 06:00 1.00 DRILL P PROD1 WIPER TO WINDOW FROM 10600' 06:00 - 07:20 1.33 DRILL P PROD1 DRILL TO 10690' 07:20 - 08:35 1.25 DRILL N DPRB 10,690.00 PROD1 UNABLE TO MOVE AT 10690' RETURNS IN=OUT PUMP BU AND SD PUMPS FOR 30 MIN TO RELAX WELL 08:35 - 08:45 0.17 DRILL N DPRB 10,690.00 PROD1 PULL 90K AND COIL CAME FREE 08:45 - 11:15 2.50 DRILL N DPRB 10,690.00 PROD1 POOH FOR MOTOR-OPEN EDC ABOVE WINDOW AFTER JOG-FLOW CHECK WELL= NO FLOW 11:15 - 11.30 0.25 DRILL N DPRB 10,690.00 'PROD1 STOP 50'FROM SURFACE AND CLOSE EDC- FLOW CHECK WELL=NO FLOW 11:30 - 12.00 0.50 DRILL N DPRB 10,690.00 PROD1 TAG UP AT SURFACE-POP OFF WELL TO CHANGE BHA 12:00 - 12:45 0.75 DRILL N DPRB 10,690.00 PRODI LD 3.125"ULTRA XL MTR AND PU 2.875"ULS 'MTR FOR IMPROVED DIRECTIONAL CONTROL HYC BI-CENTER BIT WAS RUNG OUT ON NOSE,GRADED 4-1 12:45 - 14:15 1.50 DRILL N DPRB 10 690.00 PROD1 RIH W/OPEN EDC,PVT=440 BBLS 14:15 - 14:45 0.50 DRILL N DPRB 10,690.00 PROD1 LOG TIE IN FROM 9260=+3.0' 14:45 - 15:30 0.75 DRILL N DPRB 10,690.00 PROD1 RIH TO BOTTOM AT 10690' 15:30 - 22:10 6.67 DRILL P 10,690.00 PROD1 DRILLL AHEAD FROM 10690' FS 2650 PSI @ 2.82 BPM IN/OUT WOB= 1.98K# PVT=497 BBLS 22:10 - 23:50 1.67 DRILL P 10,850.00 PROD1 WIPER FROM 10850', PVT=491 BBLS- STARTED MUD SWAP WITH NEW 9.0# POWER-VIS 23:50 - 00:00 0.17 DRILL P 10,857.00 PROD1 ON BOTTOM DRILLING TO 10857' 6/7/2012 00:00 - 03:00 3.00 DRILL P PROD1 DRILLING AHEAD FROM 10857' NEW MUD COMPLETLY AROUND AND PITS ARE CLEAN 03:00 - 05:00 2.00 DRILL P PROD1 WIPER TRIP FROM 11000' 05:00 - 08:30 3.50 DRILL P PROD1 ON BOTTOM DRILLING FS=2850 PSI @ 2.75 BPM IN/OUT 08:30 - 09:45 1.25 DRILL P PROD1 WIPER TRIP FROM 11150' FS=2750 PSI @ 2.7 BPM IN/OUT 09:45 - 10:15 0.50 DRILL P PROD1 OPEN EDC TO CLEAN OUT 7" 2867 PSI @ 3.39 BPM 10:15 - 11:30 1.25 DRILL P PROD1 LOG TIE IN=+9.0' 11:30 - 15:30 4.00 DRILL P PROD1 ON BOTTOM DRILLING FS=2800 PSI @ 2.73 BPM IN/OUT 15:30 - 17:30 2.00 DRILL P PROD1 WIPER FROM 11300' FS=2770 PSI @ 2.72 BPM,PVT=372 BBLS 17:30 - 20:30 3.00 DRILL P PROD1 ON BOTTOM DRILLING FS=2820 PSI @ 2.7 BPM WH=51,IA=18,OA=1,PVT=380 BBLS 20:30 - 22:50 2.33 DRILL P PROD1 WIPER FROM 11450'-PVT=360 BBLS Printed 7/16/2012 2.41:05PM North America -ALASKA- BP Page 6 of 6 Operation Summary Report Common Well Name:B-20 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 6/2/2012 End Date: 6/8/2012 X3-011 WC-C: (2,012,775.00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/23/2008 12 0000A Rig Release: 6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:Kelly Bushing/Rotary Table @80.00ft(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 ON BOTTOM DRILLING TO 11505' FS=2850 PSI @ 2.75 BPM 6/8/2012 00:00 - 01:30 1.50 DRILL P PROD1 ON BOTTOM DRILLING FROM 11505'TO 11600' 01:30 - 03:00 1.50 DRILL P PROD1 WIPER FROM 11600' 03:00 - 03:40 0.67 DRILL P PROD1 OPEN EDC TO CLEAN 7" 03:40 - 05:00 1.33 DRILL P PROD1 TIE IN @ 9700'- CORRECTION=+5' RIH TO BOTTOM 05:00 - 06:30 1.50 DRILL P PROD1 RUN IN HOLE BACK TO BTM. HOLE SMOOTH. 06:30 - 07:30 1.00 DRILL P PROD1 DRILL AHEAD FROM 11,680'. 2900 PSI FS AT 2.67 BPM IN/OUT. 150-300 PSI MTR WORK. 2.OK#DHWOB IA/OA/PVT:23 PSI/4 PI/362 BBLS. WHP/ECDITVD:37 PSI/10.21 PPG/8961'. _ 07:30 - 09:00 1.50 DRILL P PROD1 MAKE WIPER TRIP TO WINDOW. CALL TD AT 11,711'. 09:00 - 09:30 0.50 DRILL P PROD1 LOG GR TIE IN FROM 8300'TO 9500'FOR LINER TOP PLACEMENT DETERMINATION. 09:30 - 10:00 0.50 DRILL P _ PROD1 LOG FINAL GR TIE IN CORRECTION. -SUBTRACT 3'. 10:00 - 11:30 1.50 DRILL P PROD1 WIPER TRIP BACK TO BOTTOM. TAG AND CONFIRM CORRECTED TD AT 11,708'. 11:30 - 13:30 2.00 DRILL___ P PROD1 DISPLACE LINER WIPER PILL TO BHA. MAKE FINAL WIPER TRIP AT 28 FPM. LAY IN NEW MUD PILL. 13:30 - 15:15 1.75 DRILL P PROD1 OPEN EDC. FLOW CHECK. CIRCULATE OUT OF HOLE AT.3 BPM. HOLD PJSM AT 500'. FLOW CHECK. 15:15 - 16:00 0.75 DRILL P PROD1 GET OFF WELL. UNSTAB COIL. LD BHA AND TOOLS. CLEAR FLOOR. 16:00 - 17:00 1.00 CASING P RUNPRD PUMP SLACK FORWARD FROM REEL. RECOVER 222'OF WIRE. ESTIMED 280', THUS+/-60'SLACK E-LINE REMAINING IN REEL. 17:00 - 17:40 0.67 CASING P RUNPRD PUMP 3/4"BALL AROUND AS DRIFT. END RON EVENT AT 17:40 ON 6/8/12. BEGIN CON EVENT. Printed 7/16/2012 2:41.05PM North America -ALASKA- BP5 . Operation Summary Repo Common Well Name:B-20 AFE No Event Type: COM-ONSHORE(CON) Start Date:6/8/2012 End Date:6/12/2012 X3-011WC-C: (1,449,151 00) Project:Prudhoe Bay Site: PB B Pad Rig Name/No.: NORDIC 2 Spud Date/Time:9/23/2008 12:00:00AM Rig Release.6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/8/2012 17:40 - 18:40 1.00 CASING P RUNPRD POP OFF WELL-BALL RECOVERED-CUT OFF CONNECTOR AND PREP FOR CTC 18:40 - 19:30 0.83 CASING P RUNPRD INSTALL E-LINE BOOT ON BOT CTC AND PULL TEST TO 30K-PT TO 4000 PSI-GOOD 19:30 - 20:00 0.50 CASING P RUNPRD STAND INJECTOR BACK ON STANDS AND FILL HOLE-1 BBL 20:00 - 20:45 0.75 CASING P RUNPRD..,PJSM FOR PU LINER W/GOOD DISCUSSION ON WELL CONTROL AND POSSIBLE PROBLEMS W/EQUIPMENT TAKE CREW TO KOOMEY UNIT AND CONDUCT REVIEW ON PROPER OPERATION OF EQUIPMENT AND SHOW LOCATION OF CRITICAL VALVES AND PRESSURE SOURCES MOTORMAN GAVE INSTRUCTION ON PROPER LINE UP FOR DEFAULT CLOSING USING THE N2 BACKUP 20:45 - 00:00 3.25 CASING P RUNPRD START TO PU AND RIH W/2 7/8"6.4#STL LINER 6/9/2012 00:00 - 03:30 3.50 CASING P RUNPRD PU AND RIH W/LINER 03:30 - 06:30 3.00 CASING , P RUNPRD ALL LINER PICKED UP-PU INJECTOR AND STAB COIL-RIH W/LINER ON COIL 06:30 - 07:15 0.75 _ CASING P RUNPRD CONTINUE TO RIHWITH LINER. CIRC AT 03 BPM @ 1865 PSI TAG tTDAT 11705' CORRECT TO 11 708' 48K#UP INT. 07:15 - 08:45 1.50 CASING P RUNPRD PUMP 5 BBLS KCL. DROP 5/8"BALL CIRCULATE ON TO SELRT TOOL.2.0 BPM©2571 PSI. ON SEAT AT 42 BBLS. PRESSURE TO 4100 PSI SHEAR OFF SELRT. PU 3'TO GET NEW UP WEIGHT:40K#. LINER IS RELEASED. 08:45 - 10:45 2.00 CASING P RUNPRD DISPLACE WELL TO 9.0 KCL WITH 1% SAFELUBE. 1593 PSI AT 2.1 BPM. 1:1 RTNS. 10:45 - 12:30 1.75 CEMT P RUNPRD RU SLB CEMENTERS. CLEAN PITS AND LOAD WITH 9.0 PPG KCL. MIX 100 BBLS 2.0#BIOZAN. 12:30 - 14:00 1.50 CEMT P RUNPRD PJSM WITH CEMENTING AND RIG CREW. DISCUSS RISKS AND PROCEDURES. Printed 7/16/2012 2 41-43PM 1 • North America -ALASKA- BPPage 2 of 5 Operation Summary Report Common Well Name:B-20 AFE No Event Type: COM-ONSHORE(CON) Start Date:6/8/2012 End Date: 6/12/2012 X3-011WC-C:(1,449,151.00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 9/23/2008 12:00:00AM Rig Release: 6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 16:00 2.00 CEMT P RUNPRD PUMP 5 BBLS KCL. PT CEMENT LINE TO 250 AND 4000 PSI FOR MIN EACH. PASSED. BATCH MIX 27 BBLS 15.8 PPG CLASS G GASBLOK CEMENT AS PER WELLPLAN SPECS.AT WEIGHT AT 14:00 HRS. PUMP 5 BBLS KCL. 27 BBLS CEMENT 1980 -PSI @.0 BPM. DISP CMT WITH 9.0 2#BIO. 2250 PSI @ 2.0 BPM. 1:1 RTNS. REDUCE RATE AT 55 BBLS AWAY TO CLEAR SELRT. RESUME FULL RATE: 1710 PSI AT 1.98 BPM. STOP DISP AT 82 BBLS. PU AND SIDE EXHAUST 2 BBLS CMT AND 3 BBLS BIOZAN. OPEN BAKER CHOKE. SET DOWN 10K#. PRESS COIL AND SHEAR DART AT 3740 PSI. DISP.CMT AT 2300 PSI AT 1.06 BPM. 1:1 RTNS. BUMP PLUG AT 106 BBLS DISP, SAME AS CALCULATED VOL. HOLD 3150 PSI ON COIL. CIP AT 15:35 HRS. - OPEN CHOKE AND CHECK FLOATS. HOLDING. .PRESS COIL TO 900 PSI. PU FROM LINER -TOP. CIRC 5 BBLS BIOZAN AT 1.0 BPM AT 1.0 BPM AT LINER TOP. 16:00 - 18:00 2.00 CEMT P RUNPRD CIRCULATE OUT OF HOLE. 1.4 BPM AT 494 PSI. 0.8 BPM ABOVE DISPLACEMENT. MONITOR HOLE FILL. FLOW CHECK AT SURFACE=NO FLOW 18:00 - 20:00 2.00 CEMT P RUNPRD TAG UP AND STAND BACK INJECTOR-LAY DOWN BHA-CUT OFF 12'OF E-LINE 20:00 - 21:30 1.50 BOPSUR P RUNPRD PJSM-RU SWIZZLE STICK AND FLUSH BOP STACK 21:30 - 00:00 2.50 EVAL P OTHCMP PJSM-MU MEMORY LOGGING/CLEAN OUT BHA-RIH W/BHA ON 1 1/4"CHS WORKSTRING 6/10/2012 00:00 - 03:15 3.25 EVAL P OTHCMP RIH W/MEMORY LOGGING/CLEAN OUT BHA ON 1 1/4"CSH WORKSTRING 03:15 - 03:45 0.50 EVAL P OTHCMP MU CTC AND STAB ON INJECTOR-PSI TEST THE OTS TO 4000#=OK 03:45 - 07:00 3.25 EVAL P OTHCMP RIH W/MEMORY LOGGING/CLEAN OUT BHA ON COIL-SET DEPTH AT SURFACE=3139 5' BHA LENGTH-DOUBLE CHECK DEPTH CONTROL W/LOGGER AT 4139'=ON DEPTH. TAG PBTD AT 11642'. LOG UP PASS PAST LINER TOP. 07:00 - 09:00 2.00 EVAL P OTHCMP PULL OUT OF HOLE WITH LOGGNG TOOLS. 09:00 - 11:30 2.50 EVAL P OTHCMP AT SURFACE. PJSM AND FLOW CHECK.. GET OFF WELL. UNSTAB COIL. LD PH6 PIPE. PUMP 1/2"BALL AND OPEN CIRC SUB. STAND BACK CSH IN DERRICK. 47 STANDS. LD TWO JTS. 11:30 - 12:30 1.00 BOPSUR P OTHCMP PERFORM WEEKLY BOP FUNCTION TEST. TEST ALL COMPONENTS EXCEPT BLIND/SHEARS. ACTIVATION FROM DRILL FLOOR REMOTE PANEL. Printed 7/16/2012 2:41:43PM North America -ALASKA- BP `, Page 3 of 5# Operation Summary Report Common Wet Name: B-20 AFE No Event Type:COM-ONSHORE(CON) Start Date:6/8/2012 End Date:6/12/2012 X3-011 WC-C: (1,449,151.00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/23/2008 12:00:OOAM Rig Release:6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum: Kelly Bushing/Rotary Table©80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 14:30 2.00 ZONISO P OTHCMP PRESSURE TEST LINER LAP AS PER AK CRT-10-45 MIN WHP 0:0 2432 PSI 5:00 2391 10:00 2362 15:00 2347 -20:00 2322 25:00 2303 30:00 2289 35:00 2278 DOES NOT MEET 2ND 15 MIN LOSS<=1/2 FIRST 15 MIN LOSS. TEST FAILED-CONTACT WTL AND GET OK TO PROCEED EVALUATE MEMORY LOG DATA. PBTD CORRECTED TO 11663'. TOP OF LINER AT 8924'. 14:30 - 15:30 1.00 PERFOB P OTHCMP HOLD PJSM. LOAD 20 PERF GUNS IN TO PIPE SHED LOAD FIRING HEAD. 15:30 - 18:45 3.25 PERFOB P OTHCMP HOLD PJSM. MU 20 PERF GUNS AND E-FIRE HEAD. RUN 47 STANDS 1-1/4"CSH FROM DERRICK. 18:45 - 20:30 1.75 PERFOB P OTHCMP PJSM-PU 2 3/8"PH6 PU INJECTOR AND STAB ON WELL TEST QTS 20:30 - 22:30 2.00 PERFOB P OTHCMP RIH W/PERF GUNS ON COIL TBG 22:30 - 22:55 0.42 PERFOB P OTHCMP STOP @ FLAG AND CORRECT DEPTH TO 11663.5 FROM 11637.4' TAG BOTTOM TO VERIFY DEPTH-OK PULL UP TO 11650.7' SET PUMP TRIPS AND CHECK RATE/PSI FOR FIRING SEQUENCE 22:55 - 23:10 0.25 PERFOB P OTHCMP CYCLE PUMPS TO INITIATE FIRING SEQUENCE START MOVING UPHOLE SLOWLY WITH 15 SECONDS LEFT IN LAST SEQUENCE -GUNS FIRED ON DEPTH @ 11650.7' -GOOD INDICATION OF FIRING AT SURFACE -INITIAL FLUID LOSS RATE OF 0.15 BPM 2.00"6SPF 2006PJ GUNS. INTERVALS: 11,380'TO 11,470' 11,525'TO 11,650' 23:10 - 00:00 0.83 PERFOB P OTHCMP START POOH W/FIRED GUNS HOLDING 150 PSI ON WELLHEAD -LOSS RATE INCREASED TO 0.2 BPM WHEN BACK PRESSURE APPLIED 6/11/2012 00:00 - 02:30 2.50 PERFOB P OTHCMP POOH W/FIRED PERF GUNS ON CT -1.3 BPM IN/1.1 BPM OUT -SD AND FLOW CHECK ABOVE TOL @ 8800' =NO FLOW -SD AND FLOW CHECK AT SURFACE=NO FLOW -TAG UP AT SURFACE -PJSM-POP OFF WELL AND STAND BACK INJECTOR Printed 7/16/2012 2:41:43PM North America -ALASKA- BP 1111, Page 4 of 5 Operation Summary Report Common Well Name: B-20 'AFE No Event Type:COM-ONSHORE(CON) Start Date:6/8/2012 End Date:6/12/2012 X3-011 WC-C: (1,449,151.00) Project:Prudhoe Bay Site: PB B Pad Rig Name/No.: NORDIC 2 Spud Date/Time:9/23/2008 12:00:00AM Rig Release:6/12/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 03:15 0.75 PERFOB P OTHCMP LAY DOWN 4 JTS OF 2 3/8"WORK STRING RU AND FLUSH 1 V4"CSH W/FRESH WATER 03:15 - 08:00 4.75 PERFOB P OTHCMP POOH AND LAY DOWN 1 1/4"CSH WORK STRING REMOVE PIPE FROM RIG. 08:00 - 10:30 2.50 PERFOB P OTHCMP HOLD PJSM W/SLB PERF CREW. LD 13 GUNS. ALL SHOTS FIRED. RD FLOOR AFTER PERF AND CSH RUN. 10:30 - 13:00 2.50 CONDHL P OTHCMP HOLD PJSM TO MU NOZZLE BHA FOR FP WELL. RU AND TEST LRS PUMPERS. RIH WITH NOZZLE BHA. POOH AND DISPLACE FROM 2500'WITH DIESEL. AT SURFACE. GET OFF WELL. LD BHA. REMOVE LO/TO FROM WELLS B-27 AND B-05 WITH DSO. 13:00 - 13:45 0.75 BOPSUR P OTHCMP HOLD PJSM WITH DSM VALVE CREW. SET BPV ON DRY ROD. 13:45 - 15:00 1.25 BOPSUR -P OTHCMP PT SWAB AND MASTER VALVE. RECORD. PASSED. 15:00 - 18:30 3.50 RIGD P POST PJSM-RU SLB N2 PUMPERS. PUMP 5 BBLS FRESH WAER, SLB INHIBITOR. 5 BBLS MEOH. BLOW DOWN WITH NITROGEN TO TIGER TANK. 18:30 - 22:00 3.50 RIGD • P POST PJSM-UNSTAB COIL AND CUT OFF CTC-LD SPACERS-INSTALL GRAPPLE AND PULL TEST-PULL COIL BACK TO THE REEL AND SECURE 22:00 - 23:00 1.00 RIGD P POST REMOVE PACK-OFF AND SET INJECTOR BACK ON STANDS 23:00 - 00:00 1.00 RIGD P POST CLEAN PITS AND PREPARE 2 3/8"REEL TO BE REMOVED 6/12/2012 00:00 - 03:30 3.50 BOPSUR P POST PJSM-OPEN DOORS ON BOPE AND CLEAN/ INSPECT PER HIGH GOR SOP-CHANGE OUT RAMS FOR NEXT WELL-WILL HAVE FROM TOP DOWN ANNULAR. BLIND SHEARS 2" COMBI'S 2 3/8"COMBI'S 2"COMBI'S PJSM-LOWER 2 3/8"REEL OUT OF BOMBAY DOORS AND SECURE ON TRUCK-LIFT REEL OF 2"COIL INTO REEL HOUSE AND SECURE 03:30 - 05:30 2.00 BOPSUR P POST FINISH WORK ON BOP STACK-CLEAN AND RE-DRESS CT PACK-OFF FOR 2"COIL- INSPECT RIG TIRES IN PREPARATION FOR MOVE 05:30 - 06:00 0.50 BOPSUR P POST HOLD PJSM FOR ND BOPS. 06:00 - 07:00 1.00 BOPSUR P POST ND BOPS IN CELLAR. SECURE BOPS FOR MOVE. Printed 7/16/2012 2:41:43PM • North America ALASKA BP • Page 5 of 5 Operation Summary Report Common Well Name:B-20 AFE No Event Type: COM-ONSHORE(CON) Start Date:6/8/2012 End Date:6/12/2012 X3-011 WC-C: (1,449,151.00) Project:Prudhoe Bay Site: PB B Pad Rig Name/No.: NORDIC 2 Spud Date/Time:9/23/2008 12:00:00AM Rig Release:6/12/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing/Rotary Table @80.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 12:00 5.00 WHSUR P POST NU TREE CAP. PT SAME AS PER AK-10-45 TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH. RECORD TEST. PASSED(SEE ATTACHED CHART). CONTINUE TO PREP COIL SIZE CHANGE. FINISH INSTALLING 2"REEL IN REEL HOUSE. PU HERCULITE NOT UNDER RIG. REMOVE ALL PORTABLE EQUIPMENT FROM AROUND RIG,SPOT DOWN PAD. WELLWORK TRANSFER PERMIT CLOSED OUT WITH PAD OPERATOR. ALL TREE AND WELLHEAD VALVES CLOSED TO GAUGES. TREE AND CELLAR CLEANED. END CON EVENT AND RELEASE NORDIC 2 RIG FROM B-20A AT 12:00 NOON. NEXT WELL =B-05C. Printed 7/16/2012 2:41:43PM B-20A, Well History (Post Rig Sidetrack) Date Summary 06/15/12 T/I/O=Vac/0/0. Conduct PJSM.Valves cycled open to check pressure.Torqued tree to API. specs(see log for details). PT'd tree cap to 500 psi. (passed), prior to removal of tree cap. Rigged up lubricator with 1-1' ext. and CIW pulling tool. PT'd lubricator to 250 psi. low for 5 min. (passed)and 3500 psi. high for 5 min. (passed) using Swab and SSV as barriers. Pulled 4"CIW BPV#710 tagging at 118". Rigged up lubricator with 1-1'ext. and CIW TWC#287. PT'd lubricator(same barriers and procedure, passed). Set TWC tagging at 114". Came to surface, closed SSV and SV, and rigged up lubricator with CIW pulling tool. PT'd lubricator(same barriers and procedure, passed). Stopped lubricator(approx.6"above TWC) and PT'd tree to 250 psi. low for 5 min. (passed)and 5000 psi. high for 5 min. (passed) . Charted and documented. Pulled TWC tagging at 118". Rigged down lubricator and PT'd tree cap to 500 psi. (passed). 06/17/12 SET 4-1/2 SLIP STOP CATCHER @ 5907'SLM. 06/18/12 PULL RK-DGLV& SET RK-LGLV IN ST#3 @ 5853' MD. PULL RK-DGLV&SET RK-OGLV IN ST#4 @ 3220'MD. PULL SLIP STOP CATCHER FROM 5907' SLM. 06/30/12 DRIFT TO LINER TOP WITH 10'OF 3.70" DUMMY WHIPSTOCK AND 3.5" LIB (IMPRESSION OF DEPLOYMENT SLV). SET BAKER KB LINER TOP PACKER IN DEPLOYMENT SLEEVE @ 8,896'SLM (13.3' OAL MIN I.D 2.36). SET 4 1/2"x 3 1/2"KB LTTP IN LTP @ 8,878' SLM. LRS PREFORMED MIT-T TO 2400 PSI, PASSED. PULLED 4 1/2"x 3 1/2" KB LTTP FROM LTP @ 8,878'SLM. 06/30/12 T/I/0=x 0/331/0 Temp= S/I (Assist S-Line/Load and Kill) Pumped 5 bbls 60/40 Methanol down TBG. Pumped 1.10 bbls 70*crude down TBG to achieve 2400 psi MIT-T test pressure. TBG lost 100 psi in the 1st 15 minutes and 39 psi in the 2nd 15 minutes for a total loss of 139 psi over the 30 minute test. Bled —1 bbl to truck. FWHP=503/331/vac. S/W/SSV/M = SSL. IA/OA= OTG. Page 1 of 1 • BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB B Pad B-20 - Slot 20 B-20A Survey: MWD Survey Report - Geographic 17 July, 2012 BAKER 0 bp HUGHES Survey Report- Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well B-20-Slot 20 Project: Prudhoe Bay TVD Reference: Kelly Bushing/Rotary Table @ 80.00ft(DOYON ' Site: PB B Pad MD Reference: Kelly Bushing/Rotary Table @ 80.00ft(DOYON ' Well: B-20 North Reference: True Wellbore: B-20A Survey Calculation Method: Minimum Curvature Design: B-20A 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 B Pad,TR-11-14 Site Position: Northing: 5,946,440.22 ft Latitude: 70° 15'36.475 N From: Map Easting: 662,094.05ft Longitude: 148°41'22.843 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.23 ° Well B-20 API No Well Position +N/-S 0.00 ft Northing: 5,950,080.00 ft Latitude: 70° 16'11.917 N +EI-W 0.00 ft Easting: 663,734.00 ft Longitude: 148°40'32.830 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 38.00 ft Wellbore B-20A API No 500292084201 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 5/1/2011 21.59 80.97 57.664 Design B-20A Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,600.00 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (°) 42.00 0.00 0.00 66.31 Survey Program Date: 7/17/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 9,600.00 1 :Sperry-Sun BOSS gyro multi(B-20) BOSS-GYRO Sperry-Sun BOSS gyro multishot 9,667.50 11,708.00 MWD(B-20A) MWD MWD-Standard 7/17/2012 3:47:53PM Page 2 COMPASS 2003.16 Build 73 BAKERbp HUGHES Survey Report- Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well B-20-Slot 20 Project: Prudhoe Bay TVD Reference: Kelly Bushing/Rotary Table @ 80.00ft(DOYON ' Site: PB B Pad MD Reference: Kelly Bushing/Rotary Table @ 80.00ft(DOYON Well: B-20 North Reference: True Wellbore: B-20A Survey Calculation Method: Minimum Curvature Design: B-20A 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 9,600.00 18.07 66.00 8,824.41 1,414.22 2,640.09 5,951,551.22 666,342.52 70° 16'25.822 N 148°39'15.961 W TIP 9,667.50 17.64 65.07 8,888.66 1,422.79 2,658.93 5,951,560.19 666,361.16 70° 16'25.906 N 148°39'15.413 W KOP 9,700.23 22.07 74.98 8,919.45 1,426.48 2,669.37 5,951,564.11 666,371.52 70° 16'25.942 N 148°39'15.109 W 9,730.37 27.75 81.96 8,946.78 1,428.93 2,681.80 5,951,566.83 666,383.90 70° 16'25.966 N 148°39'14.747 W 9,760.96 34.81 81.74 8,972.90 1,431.18 2,697.51 5,951,569.42 666,399.56 70° 16'25.988 N 148°39'14.289 W 9,791.28 43.06 81.60 8,996.47 1,433.94 2,716.35 5,951,572.59 666,418.33 70° 16'26.015 N 148°39'13.741 W 9,821.74 51.57 79.52 9,017.10 1,437.64 2,738.41 5,951,576.77 666,440.30 70° 16'26.051 N 148°39'13.099 W 9,856.16 60.95 78.84 9,036.20 1,443.01 2,766.49 5,951,582.75 666,468.25 70°16'26.104 N 148°39'12.281 W 9,885.05 69.07 81.00 9,048.39 1,447.58 2,792.25 5,951,587.87 666,493.91 70°16'26.149 N 148°39'11.531 W 9,914.94 77.17 82.45 9,057.07 1,451.68 2,820.53 5,951,592.59 666,522.09 70° 16'26.189 N 148°39'10.707 W 9,935.69 83.08 84.65 9,060.62 1,453.97 2,840.84 5,951,595.33 666,542.34 70° 16'26.212 N 148°39'10.116 W 9,964.05 89.79 88.22 9,062.39 1,455.73 2,869.07 5,951,597.69 666,570.52 70° 16'26.229 N 148°39'9.294 W 10,000.05 90.83 92.83 9,062.19 1,455.40 2,905.05 5,951,598.15 666,606.50 70° 16'26.226 N 148°39'8.246 W 10,041.76 91.60 97.69 9,061.31 1,451.58 2,946.57 5,951,595.23 666,648.09 70° 16'26.188 N 148°39'7.038 W 10,067.79 93.50 101.51 9,060.15 1,447.24 2,972.20 5,951,591.45 666,673.81 70° 16'26.145 N 148°39'6.291 W 10,100.07 92.79 105.78 9,058.38 1,439.64 3,003.52 5,951,584.54 666,705.28 70° 16'26.070 N 148°39'5.380 W 10,134.06 93.43 110.50 9,056.53 1,429.08 3,035.76 5,951,574.68 666,737.74 70° 16'25.966 N 148°39'4.441 W 10,168.07 94.17 115.10 9,054.28 1,415.93 3,067.03 5,951,562.21 666,769.29 70° 16'25.837 N 148°39'3.531 W 10,201.95 94.61 117.30 9,051.68 1,401.02 3,097.34 5,951,547.97 666,799.92 70° 16'25.690 N 148°39'2.648 W 10,231.41 93.99 114.25 9,049.47 1,388.25 3,123.79 5,951,535.77 666,826.64 70° 16'25.564 N 148°39'1.878 W 10,260.29 93.32 110.35 9,047.63 1,377.31 3,150.45 5,951,525.42 666,853.53 70° 16'25.457 N 148°39'1.102 W 10,292.82 92.09 110.96 9,046.10 1,365.85 3,180.86 5,951,514.62 666,884.17 70° 16'25.344 N 148°39'0.217 W 10,330.50 91.94 116.14 9,044.77 1,350.81 3,215.37 5,951,500.34 666,919.00 70° 16'25.196 N 148°38'59.213 W 10,364.69 91.78 120.74 9,043.66 1,334.54 3,245.41 5,951,484.73 666,949.38 70° 16'25.036 N 148°38'58.338 W 10,395.83 87.17 122.11 9,043.95 1,318.31 3,271.97 5,951,469.08 666,976.29 70° 16'24.876 N 148°38'57.565 W 10,425.99 86.72 126.12 9,045.55 1,301.42 3,296.90 5,951,452.74 667,001.58 70°16'24.710 N 148°38'56.839 W 10,461.97 91.10 129.57 9,046.24 1,279.36 3,325.30 5,951,431.30 667,030.45 70° 16'24.493 N 148°38'56.013 W 10,493.75 92.27 125.49 9,045.30 1,260.01 3,350.48 5,951,412.51 667,056.04 70°16'24.302 N 148°38'55.280 W 10,525.71 93.01 122.12 9,043.83 1,242.25 3,377.01 5,951,395.33 667,082.95 70°16'24.127 N 148°38'54.508 W 10,555.47 91.93 119.03 9,042.55 1,227.13 3,402.60 5,951,380.77 667,108.86 70°16'23.978 N 148°38'53.763 W 10,582.90 90.92 116.94 9,041.87 1,214.26 3,426.81 5,951,368.44 667,133.35 70°16'23.852 N 148°38'53.058 W 10,610.18 88.68 114.14 9,041.96 1,202.50 3,451.42 5,951,357.21 667,158.21 70°16'23.736 N 148°38'52.342 W 10,639.49 86.53 110.45 9,043.19 1,191.40 3,478.51 5,951,346.70 667,185.53 70° 16'23.627 N 148°38'51.553 W 10,670.57 89.42 107.77 9,044.28 1,181.23 3,507.86 5,951,337.17 667,215.09 70° 16'23.527 N 148°38'50.699 W 10,700.25 90.46 103.96 9,044.32 1,173.12 3,536.40 5,951,329.69 667,243.80 70° 16'23.447 N 148°38'49.868 W 10,730.84 91.54 98.83 9,043.78 1,167.08 3,566.37 5,951,324.30 667,273.89 70° 16'23.387 N 148°38'48.995 W 10,760.97 91.23 94.20 9,043.05 1,163.66 3,596.29 5,951,321.53 667,303.87 70° 16'23.353 N 148°38'48.124 W 10,790.91 89.85 90.05 9,042.77 1,162.55 3,626.20 5,951,321.08 667,333.80 70° 16'23.342 N 148°38'47.254 W 10,820.51 90.77 85.80 9,042.61 1,163.62 3,655.77 5,951,322.79 667,363.34 70° 16'23.353 N 148°38'46.393 W 10,850.59 90.25 81.32 9,042.34 1,167.00 3,685.66 5,951,326.81 667,393.14 70° 16'23.386 N 148°38'45.523 W 10,880.25 89.88 76.50 9,042.31 1,172.70 3,714.75 5,951,333.15 667,422.10 70° 16'23.442 N 148°38'44.675 W 10,910.69 89.69 71.46 9,042.42 1,181.10 3,744.00 5,951,342.18 667,451.16 70° 16'23.524 N 148°38'43.824 W 10,942.16 89.94 66.27 9,042.52 1,192.44 3,773.34 5,951,354.16 667,480.25 70°16'23.636 N 148°38'42.969 W 10,970.43 89.88 61.29 9,042.57 1,204.93 3,798.70 5,951,367.19 667,505.32 70°16'23.758 N 148°38'42.231 W 11,000.32 90.15 58.23 9,042.56 1,219.98 3,824.52 5,951,382.80 667,530.81 70° 16'23.906 N 148°38'41.479 W 11,032.51 90.09 62.49 9,042.49 1,235.89 3,852.49 5,951,399.32 667,558.42 70° 16'24.063 N 148°38'40.664 W 11,063.71 89.32 67.46 9,042.65 1,249.09 3,880.75 5,951,413.12 667,586.39 70° 16'24.192 N 148°38'39.841 W 11,102.21 89.57 59.22 9,043.03 1,266.35 3,915.13 5,951,431.12 667,620.38 70° 16'24.362 N 148°38'38.840 W 11,120.85 89.82 56.80 9,043.13 1,276.22 3,930.93 5,951,441.34 667,635.97 70° 16'24.459 N 148°38'38.380 W 11,150.87 89.69 51.33 9,043.26 1,293.83 3,955.23 5,951,459.47 667,659.87 70°16'24.632 N 148°38'37.672 W 11,180.88 89.78 47.68 9,043.39 1,313.32 3,978.05 5,951,479.45 667,682.26 70°16'24.823 N 148°38'37.007 W 11,210.15 89.29 43.27 9,043.63 1,333.83 3,998.91 5,951,500.41 667,702.67 70° 16'25.025 N 148°38'36.400 W 11,240.04 91.26 37.99 9,043.49 1,356.51 4,018.37 5,951,523.51 667,721.63 70° 16'25.248 N 148°38'35.833 W 7/17/2012 3:47:53PM Page 3 COMPASS 2003.16 Build 73 NMI BAKER 0 bP HUGHES Survey Report- Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well B-20-Slot 20 Project: Prudhoe Bay TVD Reference: Kelly Bushing/Rotary Table @ 80.00ft(DOYON ' Site: PB B Pad MD Reference: Kelly Bushing/Rotary Table @ 80.00ft(DOYON ' Well: B-20 North Reference: True Wellbore: B-20A Survey Calculation Method: Minimum Curvature Design: B-20A Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 11,270.83 90.70 32.68 9,042.96 1,381.62 4,036.16 5,951,548.99 667,738.87 70° 16'25.495 N 148°38'35.314 W 11,300.63 90.86 26.97 9,042.56 1,407.45 4,050.98 5,951,575.14 667,753.12 70° 16'25.749 N 148°38'34.882 W 11,330.81 90.18 21.19 9,042.28 1,435.00 4,063.29 5,951,602.94 667,764.82 70° 16'26.020 N 148°38'34.524 W 11,362.95 90.89 14.68 9,041.98 1,465.56 4,073.18 5,951,633.71 667,774.05 70° 16'26.320 N 148°38'34.235 W 11,390.91 90.71 9.16 9,041.59 1,492.90 4,078.95 5,951,661.17 667,779.22 70° 16'26.589 N 148°38'34.067 W 11,420.67 90.40 3.24 9,041.30 1,522.47 4,082.16 5,951,690.80 667,781.79 70° 16'26.880 N 148°38'33.973 W 11,450.68 89.39 357.51 9,041.36 1,552.47 4,082.36 5,951,720.79 667,781.34 70° 16'27.175 N 148°38'33.966 W 11,480.71 89.82 351.13 9,041.56 1,582.33 4,079.39 5,951,750.59 667,777.72 70° 16'27.469 N 148°38'34.052 W'. 11,511.53 90.52 354.02 9,041.47 1,612.89 4,075.40 5,951,781.05 667,773.07 70° 16'27.769 N 148°38'34.168 W 11,540.74 90.28 0.34 9,041.27 1,642.05 4,073.97 5,951,810.17 667,771.00 70° 16'28.056 N 148°38'34.209 W 11,570.43 90.95 4.80 9,040.95 1,671.70 4,075.30 5,951,839.84 667,771.69 70° 16'28.348 N 148°38'34.170 W 11,600.19 89.48 10.51 9,040.84 1,701.18 4,079.26 5,951,869.40 667,775.01 70° 16'28.637 N 148°38'34.054 W 11,628.85 89.08 14.72 9,041.20 1,729.14 4,085.52 5,951,897.48 667,780.65 70° 16'28.912 N 148°38'33.872 W 11,662.69 89.78 20.28 9,041.53 1,761.40 4,095.69 5,951,929.96 667,790.12 70° 16'29.230 N 148°38'33.575 W 11,708.00 89.78 20.28 9,041.71 1,803.90 4,111.40 5,951,972.78 667,804.90 70° 16'29.648 N 148°38'33.117 W TD-2 7/8" 7/17/2012 3:47:53PM Page 4 COMPASS 2003.16 Build 73 Letter of Transmittal BAKER Date: July 17, 2012 HUGHES t� To: From: State of Alaska AOGCC Baker Hughes INTEQ G �� 333 W. 7th Ave., Suite 1000:41:colp795 East 94`h Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Bill Michaelson Please find enclosed the directional survey data for the following well(s): C-12CPB1 C-12C ala ' 0 7•5"- C-27C oZ ( • 0 ►-t 2, C-01BPB1 C-01B B-20A 2 L ' 46' B-05C , ( -- 07-35A a‘ 1 o' ( 7 Enclosed for each well(s): 2 hardcopy prints of directional survey reports 1 compact disk containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: . d ` , State of Alaska AOGCC DATE. RECEIVED STATE OF ALASKA t, .iKA OIL AND GAS CONSERVATION COMMISSION JAN 18 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate [.J Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ A 212-026-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: ,, Anchorage,AK 99519-6612 50-029-20842-01-00 - 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028310 PBU B-20A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 11708 feet Plugs measured None feet true vertical 9041.68 feet Junk measured None feet Effective Depth measured 11663 feet Packer measured See Attachment feet true vertical 9041.5 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 75 20"x 30" 35-110 35-109.98 0 0 Surface 2644 13-3/8"72#L-80 34-2678 34-2677.46 4930 2670 Intermediate None None None None None None Production 9156 9-5/8"47#L-80 33-9189 33-8439.51 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10550-10580 feet 10640-10670 feet 10760-10790 feet 11380-11470 feet 11525-11650 feet True Vertical depth 9042.71 -9041.88 feet 9043.18-9044.25 feet 9043.04-9042.74 feet 9041.7-9041.48 feet 9041.33-9041.43 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 32-9033 32-8296.99 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: 196 6166 2362 0 199 Subsequent to operation: 511 5191 1457 0 190 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q "" Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ,,❑✓ Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhaysabp.com Printed Name Nita Summer ays Title Petrotechnical Data Technician / / Y +'�,, Phone 564-4035 Date 1/18/2013 //////Lh/%moi'/l.�u�-f�� RBDMS JAN 2 8 013 'l�F. -/)'/3/, / i3 Form 10-404 Revised 10/2012 Submit Original Only -0 -2.- 2 _1 a) TD o N �o mo > CMD a) 0 0 CO w L0 C2-LO > '0 o a`n o = a ~ oZ a) o E cJ o p 02 w > p c to a a) wN `n _ 0 > o W 0 0 a - CO (n m O W C J N __I a0 46 °-"13 CD o u a w W I= 4- 3 -- 0 - a) a, m 2w 0 � � a `t 0 < � °a " b CD - - Z b0 2 N ° I 0- a) ai ,- . - m 2 W a) l-- m ou_ O 1 O , = coma�0ti m >_ p6'0 0 Q P:hi m W CD a V M w cr a ism iiu coo _ Z w �� m l- m� m E� a� �comx ? Q` > O _ a) -o }Ic. 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(0 Mit — (0O J r r co N co W MND D < V CUOCLCCCCWOLLZ V Z W W W W O m O Z Z Z Z D D U J J J J d (/) Packers and SSV's Attachment ADL0028310 SW Name Type MD ND Depscription B-20A PACKER 8830 8033.07 4-1/2" Baker S-3 Perm Packer B-20A PACKER 8915 8109.94 45 Flo-Guard WL Top Packer TREE= 4CNV WELLHEAD ELLHEAD= MCMC EVOY - SAFETY NOTES: WELL ANGEL>70"9890'** ACTUATOR= BAKER C ***4-1/2"CHROME TUBING' KB.ELEV= 80.03' BF.ELEV= 44.53' 2 I KOP 3100' Max Angle= 95'@ TV 10202' 20"CONDUCTOR — ? 2022' HD4-1RDEV'HES - X NP,DLV=3.813' Datum MD= 9658' U Ua= DatTVD= 8800'SS I 2610' 95/8'DV COLLAR 13-3/8'CSG,720, L-80 BUTT,ID=12.347' — 2678' GAS LFT MANDRELS ST MD TYFE VLATCH PORT DATE A 4 3220 3216 11 IJA3 DONE Fn( 16 06/18/12 3 5853 5604 31 MNG SO FEI( 20 06/18/12 2 7556 7019 34 MNG DMS' FE 0 12/25/11 1 8718 8013 27 MM3 DMS' FE 0 12/25/11 ' 8788' H4-1/2"IES X NP,ID=3.813' Minimum ID =2.377" @ 10287' 3-3/16" X 2-7/8" XO 8830' —19 5/8"x 4-1/2"BKR S-3 PKR,D=3.875' 8865' H4-1/2"FES X NP,ID=3.813' 8915' H45 FLO-GUARDWL LTP(12/27/12) 8923' —{3.70'BKRDEPLOY SLV,D=3.00' TOP OF 7'LNR H 8933' , . 8933' 95/8'X7"LNRTOP HGR,D=? i i 8964' —3-1/2'HES XNIP,D=2.813• i i ! 8880' —4-1/2'HES)Q4 NP,MLLED TO 3.80'(4/16/12) 3-1/7 LNR,9.2#,L-80 Sit., 0087 bpf,ID=2.992 —{ 8987 8987 -13 1/2'X 33116• ),D=2.786' 4-1/2"TBG,12.6#,13CRt-80 VAM TOP, —I 9033' .j 4. 8033' H41/2'WLEG=3.958"r .0152 bpi,D=3.958' �I•• �••I 95/8'CSG,47#,1-80 BUTT,ID=8.681" 9190' I`I ,I`I, L I`I `I,I 4-1/2'X 7'WHIPSTOCK(TAGGED 06/02/12) — �8' ISI 161‘ 8881'9681• HT MARKERJOM I%I II, 7'LNR,26#,L-80 Burr..0383 bpf,ID=6.276' -{ .=9$$$ ,I`I ,I`I, I II 4 �I+I �,41 I�, %►jI MLLOUT WINDOW(B-20A) 9668'-9675' 3-1/4'LNR,6.6#,L-80 TC11,.0079 bpi,ID=2.850 —{ 10287 PERFORATION SUMMARY REF LOG:SLB COJGR/NCPL ON 06/10/12 ANGLE AT TOP PERF: 92°@ 10550' 10287' —{33/16•x 2-7/8'X0,ID=2.377' Pbte:Refer b Production DB for historical perf data E TERVAL ,Opn/Sgz ,,.ATE ,./ SW N 2" 6 10550-10580 0 12/08/12 2" 6 10640-10670 0 12/08/12 6 11077660-10790 0 12/08/12 I 2" - 6 —17"380=1"1470 0 1 2' 6 11525-11650 0 06/10/12 I PBTD — 11668' 1.11 2-7/8'LNR,6.4#,1-80 STL, .0058 bpf,ID=2.441 —1 11708' •' DATE REV BY COMvBIIS DATE REV BY COMMENTS PRUDHOE BAY MIT 11/26/82 AUDI/2 IMTIAL COMPLETION 07/18/12 JM) LTP DEPTH CORRECTION WELL B-20A 10/01/08 D16 RVVO 09/16/12 AK/PJC FINAL DRLG CORRECTIONS PERMT No:"2120260 06/12/12 NORDIC 2 CTD SDERRACK(B-20A) 11/14/12 JRRIUMJ PILLED LTP(11/07/12) AH Pb: 50-029-20842-01 06/16/12 PJC CMG DRAFT CORRECTIONS 12/14/12 RRVWJMJ ADPERFS(12/08/12) SEC 31,TI1N,R14E,564'FN.&1895'FEL 06/20/12 IMAM GLV CIO(06/18/12) 01/15/13 AMJND SET FLO GUARD LTP(12/27/12) 07/02/12 MSS/JM3 SET BKR KB LTP(06/30/12) BP Exploration(Alaska) 7N ql 7E n a SEAN PARNELL, GOVERNOR ij ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION 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 B-20A BP Exploration (Alaska), Inc. Permit No: 212-026 Surface Location: 564' FNL, 1895' FEL, SEC. 31, T11N, R14E, UM Bottomhole Location: 1452' FSL, 2315' FWL, SEC. 29, Ti 1N, R14E, 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, /) f, 4 Cathy Foerster Chair DATED this 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) STATE OF ALASKA ALASK, .JIL AND GAS CONSERVATION COMMIS..,) RECEIVEDA41 PERMIT TO DRILL 36-i? 20 AAC 25.005 MAR 0i 2012 1 a.Type of work: 1 b.Proposed Well Class: ®Development Oil 0 Service-Winj 0 Single Zo e 1 c. Specify if we is proposed for: ❑ Drill IN Redrill 0 Stratigraphic Test 0 Development Gas ❑Service-Supply 0 Multiple Z ne 0 Coalbed Gas 0 Gas Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG ❑Service-Disp Alaska Oil&Gas ConElGoomfsgsion 2. Operator Name: 5.Bond: ® Blanket 0 Single W II 11. Well I & Number: BP Exploration(Alaska) Inc. Bond No. 6194193 PBU B-20A 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 11933' TVD 8970'ss Prudhoe Bay/Prudhoe Bay 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: ADL 028310 564'FNL, 1895'FEL, Sec.31,T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 815'FSL,671'FWL, Sec.29,T11 N, R14E, UM April 25,2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1452'FSL,2315'FWL,Sec.29,T11 N, R14E, UM 2560 24600' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 80.03' feet 15.Distance to Nearest Well Open Surface: x- 663734 y-5950080 Zone- ASP4 GL Elevation above MSL: 43.03' feet to Same Pool: 600' 16.Deviated Wells: Kickoff Depth: 9675' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 94 degrees Downhole: 3256 Surface: 2376 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade .Coupling Length MD ND MD ND (including stage data) 4-1/8" 3-1/2"x 3-1/4" 9.3#/6.6# L-80 STL/TC-II 3008' 8925' -8119'ss 11933' 8970'ss 145 sx Class'G' • x 2-7/8" /6.5# 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 10047' 9252' None 9920' 9130' 9886' Casing Length Size Cement Volume MD TVD Conductor/Structural 110' 20" 9 cu vds Concrete 110' 110' Surface 2678' 13-3/8" 3720 cu ft Permafrost II 2678' 2677' Intermediate 9189' 9-5/8" 1242 cu ft Class'G'. 133 cu ft Permafrost C 9189' 8440' Production Liner 1107' 7" 381 cu ft Class'G' 8933'-10040' 8206'-9246' Perforation Depth MD(ft): 9800'-9838' Perforation Depth ND(ft): 9015'-9052' 20.Attachments: 0 Property Plat ® BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ® Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the > e.oing/is rue •d rect. Contact Matt Ross,564-5782 Printed Name JamA'• - j Title Engineering Team Leader Prepared By Name/Number /A__ . Signa d re ' Phone 564-4711 Date - Joe Lastufka,564-4091 Commission Use Only Permit.ue r//.? , API Number: Perriyi lE1p`r)\\(. I Seercover letter for Number: D 6 50-029-20842-01-00 �/J\ °j)� �� other requirements Conditions of Approval: If box is checked,well may not be IvJetbe used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: Other: 44 3Soo /9,3 BO/ /esSamples Req'd: Yes No Mud Log Req'd: �❑,fYes eNo H2S Measures: Yes 0 No Directional Survey Req'd: L►I Yes 0 No Date 3-l3 -/z- / APPROVED BY THE,COMMISSIONERCOMMISSION Form 10-401 Revised 07/2009 Th r it is valid for 24 months oiri Nr aljr20 AAC 25.005(0Ji€ Submit In Duplicate To: Alaska Oil & Gas Conservation Commission From: Matthew Ross bD CTD Engineer Date: March 2, 2012 Re: B-20A Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well B-20A. CTD Drill and Complete B-20A program: Rig Start Date: April 25th, 2012 Pre-Rig Work: (scheduled to begin April 2nd, 2012) 1. F MIT- IA to 3,000 psi, MIT-OA to 2,000 psi). Passed 12/25/11 2. W Cycle LDS; PPPOT- T to 5,000 psi. Passed 12/27/11 3. S Drift tubing down to TD with 3.625" centralizer. Done 12/20/11 4. E Mill XN profile at 8980' MD to 3.80". '/ 'safe- • 5. E Set 4-W x 7" whipstock at 9,675' MD. 6. V PT MV, SV, WV. Bleed wellhead pressures down to zero. 7. 0 Bleed production flow and GL lines down to zero and blind flange. 8. 0 Remove wellhouse, level pad. 9. V Set TWC (4-1/16" 'H' profile) 24 hrs prior to rig arrival. PsA Rig Work: (scheduled to begin April 25th, 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" window at 9,675' and 10' of rathole in Zn2C, swap the well to Geo-Vis. 3. Drill Build: 4.125" OH, 325' (28°/100 planned). 4. Drill Lateral: 4.125" OH, 1,933' (12°/100 planned) with resistivity. 5. Run 3-1/2" by 3-1/4" by 2-7/8" L-80 liner leaving TOL at 8,925' MD. ' -.kis 6. Pump primary cement leaving TOC at 9,500' MD, 30 bbls of 15.8 ppg liner cmt planned. 7. Cleanout liner and run MCNL/GR/CCL log. pti) 8. Test liner lap to 2,400 psi. 9. Perforate liner per asset instructions (-200'). 10. If needed, set 4-'h" liner top packer, and test to 2,400 psi. 11. Freeze protect well, set BPV, RDMO. Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Generic GLV's. Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Geo-VIS for milling window and drilling (-679 psi overbalance). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.125" Casing Program: • 3-1/2", L-80, 9.3 lb/ft STL liner 8,925' MD —8,955' MD. • 3-1/4", L-80, 6.6 lb/ft TC-II liner 8,955' MD — 10,300' MD. • 2-7/8", L-80, 6.5 lb/ft STL liner 10,300' MD— 11,933' MD. • A minimum of 30 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 9,500' 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 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 93.6°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—24,600'. • Distance to nearest well within pool —600'. Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL/MCNL logs will be run. Perforating: • SWS 2", 6 spf, perf guns, 1-1/4" CSH work string and 2-3/8" PH6 • 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. Xf" Anti-Collision Failures: • B-05B 505.7' (ctr— ctr distance) Status: Producer, will be shut in. • B-27 802' (ctr—ctr distance) Status: Motherbore, plugged and abandoned. • B-27A 565.5' (ctr— ctr distance) Status: Producer, will be shut in. Hazards • The maximum recorded H2S level on B pad was 110 ppm on well B-21 on 6/30/2011. • Lost circulation risk is considered low due to uncertainty in B-20. Reservoir Pressure • The reservoir pressure on B-20A is expected to be 3,256 psi at 8,800' TVDSS. (7.1 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,376 psi. • An EMW of 8.4 ppg for this well will provide 587 psi over-balance to the reservoir. Matthew Ross CC: Well File CTD Engineer Sondra StewmanlTerrie Hubble TREE= CMI WELLHEAD= MCEVOY B-2 O SAFE. . .IOTES: """4-1/2" CHROME TUBING*** ACTUATOR= BAKER C KB.ELEV= 80.03' BF.ELEV= 44.53' KOP= 3100' Max Angle= 35°@ 6400' Datum MD= 9658' ' 2022' —4-1/2"HES X NIP, ID=3.813" Datum TVD= 8800'SS 2610' 9-5/8"DV PKR 13-3/8"CSG,72#,L-80,ID=12.347" —1 2678' , GAS LIFT MANDRELS ST MD TVD DEV TYPE_VLV LATCH PORT DATE 4 3220 3216 11 MMG DOME RK 16 11/29/08 3 5853 5604 31 MMG DOME RK 16 11/29/08 Minimum ID = 3.725" @ 8980' 2 7556 7019 34 MMG DOME RK 16 11/29/08 4-1/2" XN NIPPLE 1 8718 8013 27 MMG SO RK 20 11/29/08 1 8799' 1—4-1/2"HES X NIP, ID=3.813" X 8830' —19 5/8"x 4-1/2"BKR S-3 PKR,ID=3.875" I 8865' —4-1/2"HES X NIP,ID=3.813" TOP OF 7"LNR —1 8933' 8933' —19 5/8"X 7"LNR TOP HGR,ID=? 4-1/2"TBG,12.6#, 13CR-S0 VAM TOP, 9033' 8980' —I4-1/2"HES XN NIP,ID=3.725" .0152 bpf, ID=3.958" 9-5/8"CSG,47#,L-80, ID=8.681" — 9190' 9033' 4-1/2"WLEG=3.958" 9581' H7"MARKER JOINT PERFORATION SUMMARY REF LOG:DA-BHCA, 11/21/82 ANGLE AT TOP PERF: 17° @ 9800' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9696-9748 S 08/15/98 3-3/8" 4 9748-9758 S 08/15/98 3-3/8" 6 9752-9758 S 12/13/99 2-7/8" 4 9770-9790 S 08/15/98 2-7/8" 4 9800-9818 0 08/15/98 3-3/8" 4 9825-9838 0 12/13/99 I PBTD —I 9865' I ••,$&.4.$*I4 ..4 !A, 9886' -J FISH-CAM SPINNER SHIELD IN HOLE,06/04/92 X11...A'I4 .4 7"LNR,26#,L-80,.0383 bpf,ID=6.276" -1 10040' i�••••••• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/26/82 ORIGINAL COMPLETION WELL: B-20 10/01/08 D16 RWO PERMIT No:'1821680 10/12/08 JLJ/PJC GLV C/O(10/04/08) API No: 50-029-20842-00 11/21/08 MD/JMD DRLG DRAFT CORRECTIONS SEC 31,T11N,R14E,564'FNL&1895'FEL 12/12/08 MBM/SV GLV C/O(11/29/08) BP Exploration (Alaska) TREE= CW WELLHEAD= MCEVOY B-20A SAFE. . .JOTES: ***4-1/2"CHROME TUBING*** ACTUATOR= BAKER C proposed CTD sidetrack KB.ELEV- 80.03' BF.ELEV= 44.53' KOP= 3100' Max Angle= 35"@ 6400' 2022' H4-1/2"HES X NIP,ID=3.813" Datum MD= 9658' Datum TVD= 8800'SS 2610' 9-5/8"DV PKR r _ 13-3/8"CSG,72#,L-80,ID=12.347" — 2678' 11 GAS LIFT MANDRELS ST MD TV DEV TYPE VLV LATCH PORT DATE 4 3220 3216 11 WAG DMY RK 0 12/25/11 3 5853 5604 31 MMG DMY RK 0 12/25/11 Minimum ID = 2.377" 10300' 2 7556 7019 34 MMG DMY RK 0 12/25/11 3-3/16" x 2-7/8" XO 1 8718 8013 27 MG DMY RK 0 12/25/11 ' ' 8799' H4-1/2"HES X NIP,ID=3.813" TSGR=9,226' MD X 8830' -19 5/8"x 4-112"BKR S-3 PKR,ID=3.875" ' ' 8865' H4-1/Z'HES X NP, ID=3.813" /Top of 3-1/2"liner @-8,925' TOP OF 7"LNR — 8933' 8933' Hs 5/8"X 7"LNR TOP HGR,ID=? 0 ' , H-4-1/2"HES XN NIP,ID=3.800" I milled out 4-1/2"TBG,12.6#, 13CR-80 VAMTOP, 9033' .0152 bpf, ID=3.958" 3-1/2"X Nipple 9-5/8"CSG,47#,L-80, ID=8.681" I— 9190' 9033' H4-1/2"WLEG=3.958" 9581' -7"MARKER JOINT I 3-1/2"x 3-3/16"XO —Top of cement at-9,501 PERFORATION SUMMARY 1 \\� 8 -I ==h) REF LOG: DA-BHCA,11/21/82 _ 5 ANGLE AT TOP PERF: 17°@ 9800' TD @ 11,933' Note: Refer to Production DB for historical perf data 3-3/16"x 2-7/8"XO @-10,300' SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9696-9748 S 08/15/98 3-3/8" 4 9748-9758 S 08/15/98 3-3/8" 6 9752-9758 S 12/13/99 2-7/8" 4 9770-9790 S 08/15/98 2-7/8" 4 9800-9818 0 08/15/98 3-3/8" 4 9825-9838 O 12/13/99 '4 1/2"-x 7"TT w stock ,),675' I PBTD - 9865' 1111;x.41111114 1. #44 9886' -FISH-CAM SPINNER SHIELD IN HOLE,06/04/92 I 7"LNR,26#, L-80, .0383 bpf, ID=6.276" 10040' 11111.,1'1'l 1I1 11i1i1•1i1i••A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/26/82 ORIGINAL COMPLETION 02/02/12 WJH proposed coil sidetrack WELL: B-20A 10/01/08 D16 RWO PERMIT No:1821680 10/12/08 JLJ/PJC GLV C/O(10/04/08) API No: 50-029-20842-00 11/21/08 MD/JMD DRLG DRA FT CORRECTIONS SEC 31,T11 N, R14E,564'FNL&1895'FEL 12/12/08 MBM/SV GLV C/O(11/29/08) 01/07/12 RCT/PJC GLV C/O(12/25/1) BP Exploration(Alaska) Meg' 0 m 'li z m v Z O v co m _ °° O ai Ca el N s- M C,�j 0 Z a N 43 O N — • , V Co v °O ''i U) oo O OD r-- V Q a. o t` 7 @ � a O O N a FO- a0 t 0 y -8 8 Np N _ ct 7 a N () i > � m �' u n of ZZ > w g J c < J NNN• S' E co j > d m Jm • 2 Y F- 2- W o m N c 7 a) O 2 D 7 mr. 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O 3 Co) 3 _ co xE Q H m N U N re c rrwq 111 1111 U Q Ill PIM t I I ll 11 " ca E c n1 m 1.11111111 ,_V O. a X x Land Administration System Page 1 of 1 Alaska DNR Case Summary File Type:ADL File Number. 28310 See Township,Range,Section and Acreage? 0 Yes No I New Search File: ADL 28310 "^at' Search for Status Plat Updates As of 03/06/2012 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 08/19/1965 Total Acres: 2491.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date:12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: o11N Range: 014E Section: 29 Section Acres:640 Search Plats Meridian: U Township: o11N Range: 014E Section: 3o Section Acres:604 Meridian: U Township: oiN Range: 014E Section: 31 Section Acres:607 Meridian: U Township: olN Range: o14E Section: 32 Section Acres:640 Legal Description 05-28-1965***SALE NOTICE LEGAL DESCRIPTION*** C14-131 uN 14E UM 29,30,31,32 2491.00 U-3-7 End of Case Summary Department of Natural Resources 550 W.7th Ave,Suite 1260,Anthorage,AK 99501-3557 Phone:907-269-8400 fax:907-269-8901 TTY:907-269-8411 State of Alaska I I©2010 I Webmaster http://dnr.alaska.gov/prof ects/las/Case_Summary.cfm?FileType=ADL&FileNumber=28310... 3/6/2012 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME 72 " PTD# o?lo?Oa2 L Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: P,e4/L4,DE' / POOL: e/".4,4710‘.__T,4')'comic . Check Box for Appropriate Letter I 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. Rev:9/09/2011 > > m O > 7 > D 1: -1:1 D Q o r co , 0n 3 0 •m O N 7 fn - k o w w 5 w w o- p (/3 p Ca N pj O O N v N co D) N D) 7 0 .i 7 C) O (D O (DO ... CDN N N CO w w w CO CO CO CO CO CO N) N N.) N.) N N.) N N N.) N - - (0 CO �1 O C)) .P CO N — 'i tiCO co v C) al A w N - O (0 CO -.l 0) 01 A CO N - O (0 CO C7) 01 A w N - 0 v to Cn p C C ( * = CO W O o. . 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