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214-197
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 09-31D Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-197 50-029-21396-05-00 15855 Conductor Surface Intermediate Liner Liner 8875 80 2499 3460 7886 4720 13800 20" 13-3/8" 9-5/8" 7" 4-1/2" 8872 48 - 128 47 - 2545 45 - 3505 3347 - 11233 11134 - 15853 48 - 128 47 - 2545 45 - 3505 3347 - 8597 8522 - 8875 13997, 15480, 15627 470 2230 / 2670 4760 5410 7500 13800, 14389 1490 3700 / 4930 6870 7240 8430 13450 - 15650 4-1/2" 12.6# 13Cr85 43 - 11136 8872 - 8878 Structural 4-1/2" HES TNT 1993, 1993 11009 8427 Bo York Operations Manager David Bjork david.bjork@hilcorp.com 907.564.4672 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028328 & 0028327 43 - 8523 N/A N/A 19266 16005 8 0 2679 2074 325-102 13b. Pools active after work:Prudhoe Oil 4-1/2" MCX I-SSV 11009, 8427 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 1:59 pm, Apr 25, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.04.24 17:59:59 - 08'00' Bo York (1248) DSR-4/29/25JJL 5/8/25 RBDMS JSB 050225 ACTIVITYDATE SUMMARY 3/27/2025 ***WELL S/I ON ARRIVAL*** EQUALIZE & PULL RED SPYDER ISSSV (ser# RS-26) FROM SVLN @ 1,993' MD DRIFT w/ 3.67" CENT, STEM, 3.48" CENT, SAMPLE BAILER TO DEVIATION @ 11,712' SLM ***WELL S/I ON DEPARTURE*** 3/29/2025 CTU#1 1.5" CT. Job Scope: Depth Log / Set CIBP / Ext Adperf MIRU CTU. Function Test BOP's. Make up Northern CTC/MHA. Tagged Stripper. PT PCE 350psi Low / 4100psi High. SITP= 1730psi. RIH w/ Read 2-3/8" Logging Carrier & 3.60" DJN. Bullhead wellbore w/ 284 bbls 1% KCL w/ Safelube. Continue to keep hole full to prevent gas migration. Tagged in Liner at 14072' down / 14067' up. (~ bottom of existing open perf interval). Notifiy OE, no need to work nozzle deeper as we are below the new plug set depth. Logged from compression up to 10900'. Flagged Pipe at 13839'. Pooh keeping hole full. Pop off & break down the Read log BHA.Scaffolder erected. MU NS 4.5" CIBP.Confirm good Tie in data. (+1') Correction. Send to OE for review & approval. RIH with 4.5" CIBP. ***In Progress*** 3/30/2025 CTU#1 1.5" CT. Job Scope: Depth Log / Set CIBP / Ext Adperf Continue RIH w/ Northern 4-1/2" CIBP. Correct depth to Top of Plug at Flag. Attempt to set top of CIBP at 13900'. CIBP moving downhole after setting. Pick up to 13880' attempted to pressure test but failed at 660psi. RBIH & Push CIBP down to 13997'. Pooh keeping the hole full. Recover 1/2" ball. Setting Tool looks good. Swap out Setting Tools. Make up & RIH w/ 2nd Northern 4-1/2" Alpha CIBP. Correct depth at flag. Set Top of CIBP at 13800'. Stack ~ 3k down surface weight. PT Plug to 1000psi - good set. Pooh keeping hole full. At surface, perform 10 min No Flow Test. Establish circulation across the top. Unstab lubricator. Break down setting tool bha. Recover 1/2" steel ball. Make up 2-1/8" Swivel below MHA. PT MHA 3500psi - Good Test. Hold PJSM & Perform Kick Drill w/ Coil Crew, HES TCP & Crane Operator on days. Verify Safety Joint makes up to Perf Guns. Deploy 2-7/8" Perf Guns. Trolly out injector & make up swivel above Firing Head. Stab on well & PT QTS to 4200psi. Correct counter depths. RIH w/ HES 2-7/8" x 100' Perf Gun BHA taking displacement to Trip Tank. Correct to bottom shot depth at the Coil flag. RIH past shot depth, PU to Bottom shot depth. For perf interval (13,450'-13,550'). PJSM for launching ball. Pump 5/8" ball down. On seat 27.4 bbls, Fired at ~3700 psi. PUH while pumping. Well on a Vac swap to KCL, cont POOH with continuous hole fill at 1 bpm. ***In Progress*** Daily Report of Well Operations PBU 09-31D Daily Report of Well Operations PBU 09-31D 3/31/2025 CTU#1 1.5" CT. Job Scope: Depth Log / Set CIBP / Ext Adperf Well on a Vac, Continue POOH with continuous hole fill at 1 bpm. Catch WHP Cont POOH keeping hole full. ~13-15 bph loss rate. At surface. Perform good 10 min no flow test. Establish circulation across the top. PJSM for gun Un-deployment. Weather hold for wind > 30 mph. Unstab from well, Break firing head off. Ball recovered. Undeploy (5) 2-7/8" guns. All shots fired. 40 bbls (2600') 60/40 FP in the well. Night Crerw WC Drill for Gun Un-Deploy ***Job Complete / Return well back for Injection*** 4/3/2025 *** WELL S/I ON ARRIVAL *** BRUSHED 4-1/2" HES X-NIP @ 1993' MD SET 3.81" X-LOCK w/ RED SPIDER INJECTION VALVE (ser# RS-26, 8 x 1/8" ports, steel sec lockdown, 48" oal) IN HES X-NIP @ 1993' MD RAN 4-1/2" CHECKSET (sheared), UNABLE TO DO DRAW DOWN HAVE 0 psi ON TUBING ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 09-31D Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-197 50-029-21396-05-00 ADL 0028328 & 0028327 15855 Conductor Surface Intermediate Production Liner 8875 80 2499 3460 7886 4720 14389 20" 13-3/8" 9-5/8" 7" 4-1/2" 8873 48 - 128 47 - 2545 45 - 3505 3347 - 11233 11134 - 15853 2260 48 - 128 47 - 2545 45 - 3505 3347 - 8597 8522 - 8875 15480, 15627 470 2230 / 2670 4760 5410 7500 14389 1490 3700 / 4930 6870 7240 8430 13950 - 15650 4-1/2" 12.6# 13Cr85 43 - 111368872 - 8878 Structural 4-1/2" HES TNT 4-1/2" MCX I-SSV 11009 / 8427 1993 / 1993 Date: Bo York Operations Manager Brodie Wages David.Wages@hilcorp.com (713) 380-9836 PRUDHOE BAY March 10, 2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-102 By Gavin Gluyas at 12:35 pm, Feb 24, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.02.24 12:11:00 - 09'00' Bo York (1248) SFD 2/27/2025 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 Perforate DSR-2/24/25 10-404 JJL 2/25/25 *&: 3/7/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.07 10:51:17 -09'00' RBDMS JSB 031125 MIST Plug and Addperfs 09-31D PTD:214197 Well Name:09-31D API Number:50-029-21396-05 Current Status:Online Injector Rig:Slickline / Coil Estimated Start Date:March 10, 2025 Estimated Duration:3days Regulatory Contact:Carrie Janowski Permit to Drill Number:214197 First Call Engineer:David Wages 713.380.9836 Second Call Engineer:Jerry Lau 907-360-6233 AFE Number: Current Bottom Hole Pressure:3268 psi @ 8,600’ TVD 4/2017 SBHPS Max. Anticipated Surface Pressure:2260 psi with 0.2 psi/ft MI in wellbore Min ID:3.725” XN Nip @ 11,118’ MD Max Angle:95 Deg @ 11,946’ Tie In Log: 09-31D SLB Mem CBL - Log Dated 26-June-2015 Brief Well Summary: This well is a MIST injector that was completed in 2015. 4 bulbs have been utilized so far with the last one in 2021. The well is in good mechanical condition. History: 3/2015: Parker 273 sidetrack to 09-31D 3/2015: Eline run USIT, TOC found at 5700’. 6/15: Pull B&R, pull RHC. Coil ran cbl, perforated from 15,620’ – 15,590’, 15.560’ – 15,590’, 15,530’ – 15,560’, 15,500’ – 15,530’. Thin pipe found, RDMO. 7/15: SL set MCX 5/16: SL C/O MCX 4/17: SL pull MCX, run SBHPS 5/17: Coil tag at 11,650’, C/O to 11,738’, ran tie in log, set plug at 15,325’, perforated 15,064’ – 15,032’. 15,032’ – 15,000’, 14,940’ – 14,908’, 14,887’ – 14,908’. 14,876’ – 14,887’, slickline followed up and set MCX 7/18: coil milled CIBP and pushed to 15,627’, venturi run. Set CIBP @ 14,750’. Perforated from 14,474’ – 14,506’, 14,538’ – 14,506’, 14,442’ – 14,474’. Slickline set MCX. 8/21: SL pull MCX, coil mill CIBP, push to 15,480’, set CIBP @ 14,390’, PT plug good. Perf 13,950’ – 14,070’ (120’). 9/21: set red spider 5/24: MIT-IA pass to 2500 psi Objective: The objective of this program is to increase offset production by moving MI bulbs. Slickline 1. MIRU Slickline Unit and spot ancillary equipment. 2. Pull Red Spider valve set in X Nip at 1993’ MD. 3. Drift to deviation with a 3.5” cent and sample bailer to deviation and collect sample if possible. If sample is collected please note in AWGRS and notify OE. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs 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 MIST Plug and Addperfs 09-31D PTD:214197 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. CCoil –Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead 1.2x wellbore volume ~256 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 (13,950’)=213 bbls b. 4-1/2” Tubing – 11,133’ X .0152 bpf = 170 bbl c. 4-1/2” Liner to Top Perf– 2817’ X 0.0152 bpf = 43 bbls d. 4-1/2” Liner to CIBP– 3256’ X 0.0152 bpf = 50 bbls 3. Pull Tie in log with GR/CCL 4. Set CIBP per tie in below at 13,900’ 5. At surface, prepare for deployment of TCP guns. 6. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KKWF, 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. *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. 7.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. MIST Plug and Addperfs 09-31D PTD:214197 PPerf Schedule Use 2-7/8” Maxforce 175 charges 6 SPF Perf Interval Perf Length Gun Length Weight of Gun (lbs) 13,450’ –13,550’100 100 1240lbs (12.4ppf) 8. RIH with perf gun and lightly tag CIBP for depth control (as needed). Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 9. After perforating, PUH to top of liner or into tubing 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. 10. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 11. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 12. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 13. RDMO CTU. 14. Turn well over to Operations POP. OPS 1. Upon POI 09-31 MI, WAG well 03-10 to PWI Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Tie In Log 7. Change of Approved Sundry Form MIST Plug and Addperfs 09-31D PTD:214197 Current Wellbore Schematic MIST Plug and Addperfs 09-31D PTD:214197 Proposed Schematic MIST Plug and Addperfs 09-31D PTD:214197 Coiled Tubing BOPs MIST Plug and Addperfs 09-31D PTD:214197 Equipment Layout Diagram MIST Plug and Addperfs 09-31D PTD:214197 Standing Orders for Open Hole Well Control during Perf Gun Deployment MIST Plug and Addperfs 09-31D PTD:214197 Tie-In Log MIST Plug and Addperfs 09-31D PTD:214197 MIST Plug and Addperfs 09-31D PTD:214197 CIBP Set: Hopefully we can see the old perfs on the tie in log MIST Plug and Addperfs 09-31D PTD:214197 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-31D PRUDHOE BAY UNIT 09-31D Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/12/2024 09-31D 50-029-21396-05-00 214-197-0 G SPT 8427 2141970 2107 1997 2027 2029 2032 8 18 18 19 4YRTST P Kam StJohn 5/4/2024 4 Year AOGCC MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 09-31D Inspection Date: Tubing OA Packer Depth 0 2755 2714 2704IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240504180409 BBL Pumped:6.3 BBL Returned:5 Wednesday, June 12, 2024 Page 1 of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y Anne Prysunka at 4:15 pm, Oct 04, 2022 'LJLWDOO\VLJQHGE\'DYLG%MRUN '1 FQ 'DYLG%MRUN RX 8VHUV 5HDVRQ ,DPDSSURYLQJWKLV GRFXPHQW 'DWH 'DYLG%MRUN MGR19OCT2022 DSR-10/4/22 RBDMS JSB 100622 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/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU 09-31D Convert WAG to GI Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-197 50-029-21396-05-00 N/A ADL 0028328 & 0028327 15855 Conductor Surface Intermediate Production Liner 8875 80 2499 3460 7886 4720 14389 20" 13-3/8" 9-5/8" 7" 4-1/2" 8873 48 - 128 47 - 2545 45 - 3505 3347 - 11233 11134 - 15853 2470 48 - 128 47 - 2545 45 - 3505 3347 - 8597 8522 - 8875 15480, 15627 470 2230 / 2670 4760 5410 7500 14389 1490 3700 / 4930 6870 7240 8430 13950 - 14070 4-1/2"12.6# 13Cr85 43 - 111368872 - 8872 Structural HES TNT PKR 4-1/2" MCX I-SSV 11009, 1993 8427, 1993 Date: Bo York Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL 10/11/2021 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 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 1:20 pm, Sep 30, 2021 321-517 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.29 10:10:51 -08'00' Bo York DSR-9/30/21 10-404X DLB 09/30/2021 MGR11OCT21 dts 10/11/2021 JLC 10/11/2021 Jerem y Price Digitally signed by Jeremy Price Date: 2021.10.11 13:36:36 -08'00' RBDMS HEW 10/12/2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:214-197 6.50-029-21396-05-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 15855 15768 8876 11009 15480, 15627 14389 8427 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 48 - 128 48 - 128 1490 470 Surface 2499 13-3/8" 47 - 2545 47 - 2545 3700 / 4930 2230 / 2670 Intermediate 3460 9-5/8" 45 - 3505 45 - 3505 6870 4760 Liner 7886 7" 3347 - 11233 3347 - 8591 7240 5410 Perforation Depth: Measured depth: 13950 - 15650 feet True vertical depth:8872 - 8878 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr85 43 - 11136 43 - 8523 11009 8427Packers and SSSV (type, measured and true vertical depth) HES TNT Liner 4720 4-1/2" 11134 - 15853 8521 - 8875 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 0 0 3005 13142 0 0 9389 0 2907 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Torin Roschinger torin.roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-4594 Treatment descriptions including volumes used and final pressure: 13. Sr Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8875 Sundry Number or N/A if C.O. Exempt: 321-360 4-1/2" MCX I-SSV 1993 1993 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Mill/Set CIBP, EXT Perf Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028328, ADL 0028327 PBU 09-31D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 55 By Meredith Guhl at 8:17 am, Sep 14, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.13 10:58:37 -08'00' Bo York RBDMS HEW 9/15/2021 MGR14OCT2021 DSR-9/14/21 ACTIVITYDATE SUMMARY 8/2/2021 **WELL S/I ON ARRIVAL** DRIFTED TO & EQ'D MCX @ 1993'MD w/ 3.84" CENT & X EQ PRONG. RAN 4 1/2" GS 40" PRONG TO 28'SLM *sat down in unknown obstruction* DRIFTED FREELY w/ 3.84" GAUGE RING TO MCX @ 1993'MD PULLED 4-1/2 MCX (ser.M35B) FROM 1993' MD DRIFTED w/ 3.61" DOGLESS GS(OD Drift) & 2.5" SAMPLE BAILER TO STALL OUT DUE TO DEVIATION @ 11734'SLM(11754'MD) *80* DEVIATION* TAGGED XN FOR C/F @ 11098'SLM(11118'MD) w/ 3.79" GAUGE RING. **WELL S/I ON DEPARTURE** 8/15/2021 CTU#6 1.75" CT Job Objective: Mill CIBP/ Set CIBP / Ext. Addperf MIRU CTU. MU & RIH Baker 2-7/8" milling assembly with 3.70" 3-bld junk mill to 14725' ctm. Flag pipe. Start Milling CIBP. ***Continued on 08/16/21*** 8/16/2021 CTU#6 1.75" CT Job Objective: Mill CIBP/ Set CIBP / Ext. Addperf Mill CIBP. Push to 15480' ctm. Dry drift to flag. Pooh. FP & secure well due to Covid- 19 outbreak. Night crew able to work their tower. MU & RIH with NS CIBP. ***Continued on 08/17/21*** 8/17/2021 CTU#6 1.75" CT Job Objective: Mill CIBP/ Set CIBP / Ext. Addperf Continue RIH with NS 4-1/2" CIBP. Correct depth at flag Set CIBP. ME of plug at 14390' (Top of CIBP 14389.4'). Pressure test plug to 1521 psi. Good test. POOH maintaing hole fill. Ensure well kill and make up 120' of 2-7/8" MaxForce perf guns, 6 spf. RIH and tag CIBP for tie-in, pick up and perforate 13950-14070'. POOH maintaining hole fill. Lay down perf guns with all shots fired. Well not freeze protected, to be put on injection immediately. RDMO ***Job Complete*** Daily Report of Well Operations PBU 09-31D Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:214-197 6.API Number:50-029-21396-05-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028328 , ADL 0028327 Property Designation (Lease Number):10. 341H 8. PBU 09-31D 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations 5 Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 15855 Effective Depth MD: 13Cr85 11. 8-1-2021 Commission Representative: 15. Suspended Contact Name: Torin Roschinger Contact Email: Torin.Roschinger@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" MCX I-SSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8875 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 11009 / 8427 1993 , 1993 Date: Liner 4720' 4-1/2" 11134 - 15853 8521 - 8875 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 47 - 2545 47 -2545 14. Estimated Date for Commencing Operations: BOP Sketch 48 - 128 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT 14452 - 15650 8873 - 8878 4-1/2" 12.6#43 - 11136 Liner 14750 8873 14750 15627 48 - 128 470 13-3/8" 9-5/8" Contact Phone:(907) 564-4594 Date: 07/19/2021 4760 80'149020"Conductor 2230 / 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2499'3700 / 4930 Intermediate 3460'45 - 3505 45 - 3505 7886' 7" 3347 - 11233 3347 8591 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 8:11 am, Jul 21, 2021 321-360 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.07.20 15:46:03 -08'00' Bo York MGR21JUL21 DSR-7/21/21DLB 07/21/2021 X 10-404 dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 11:13:40 -08'00' RBDMS HEW 7/22/2021 MIST Plug and Addperfs 09-31D PTD: 214197 Well Name: 09-31D API Number: 50-029-21396-05 Current Status: Online Injector Rig: Slickline / Coil Estimated Start Date: August 2021 Estimated Duration: 3 days Regulatory Contact: Carrie Janowski Permit to Drill Number: 214197 First Call Engineer: Torin Roschinger (406) 570-9630 (c) Second Call Engineer: AFE Number: Current Bottom Hole Pressure: 3300 psi @ 8,800’ TVD 7.3 PPGE Maximum Expected BHP: 3350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP) Max. Anticipated Surface Pressure: 2470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 1650 psi Min ID: 3.725” XN Nip @ 11,118’ MD Max Angle: 95 Deg @ 11,946’ Reference Log: 09-31D SLB PSP CBL/VDL/GR/CCL - Log Dated 26-June-2015 Brief Well Summary: This well is a MIST injector that was completed in 2015. Currently, producers 03-27, 09-04, and 09-26 see a big MI buzz from this well. The recommended cumulative volume of MI in the current location has been reached and the offset producers are starting to see significant decline from the peak MI influence from this third bulb. It is time to move uphole for the fourth bulb. It’s expected that the same wells will benefit from this MIST location. No acid job was performed on this well after the previous three sets of perforations. This procedure will use a similar gun system for this add perf and are not planning on a stimulation at this time. Objective: The objective of this program is to increase offset production by moving MI bulbs. The existing CIBP set at 14750’ MD will be milled up and pushed to TD to allow future re-MIST of entire well. A CIBP will be set to isolate the existing perfs and 120’ off extended addperfs will be shot uphole. Slickline 1. MIRU Slickline Unit and spot ancillary equipment. 2. Pull MCX set in X Nip at 1993’ MD. 3. Drift to deviation with a 3.5” cent and sample bailer to deviation and collect sample if possible. If sample is collected please note in AWGRS and notify OE. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs 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. Coil Tubing * MIST Plug and Addperfs 09-31D PTD: 214197 1. Bullhead 265 bbls of KWF, 8.4 ppg 1% KCl down the tubing to the formation. (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 WSL.) a. Wellbore volume to bottom perf = 221 bbls b. 4-1/2” Tubing – 14,548’ X .0152bpf = 221 bbls 2. MU 2-7/8” milling BHA w/ 3.70” mill & RIH. Tag CIBP at 14,750’ MD and flag pipe. This will be used as the tie-in depth for the subsequent CIBP set later in this procedure. 3. Mill CIBP at 14,750’ MD and push down to where previous plug was milled and pushed down to on 07/10/2018, ~15,627’ MD. POOH and confirm flag is still painted on pipe. a. If for any reason it’s suspected that there is debris above where we are going to set the CIBP, the flag had been wiped clean on the pipe when milling or the original CIBP tag was suspiciously off depth, MU a venturi with a logging BHA and re-log the well for tie-in and clean up debris in lateral. Exact depth isn’t super critical as this MI bulb will service the same zone through all new 120 addperfs and be in homogeneous sand as seen in the mini-log below. b. If logging run is required, MU logging BHA in 2-7/8” carrier with a ~3.0” JSN. RIH and flag pipe for CIBP tie-in. POOH and confirm good data. 4. MU and RIH with 3.50” NS CIBP. Set CIBP at 14,390’ MD. POOH. 5. Freeze protect tubing as needed. 6. At surface, prepare for deployment of TCP guns. 7. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, 8.4 ppg 1% KCl as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 8. Pickup safety joint and 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. 9. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. 09-31D Perf Schedule *2.875” perf guns were used to calculate gun weights. Perf Interval Perf Length Gun Length Weight of Gun (lbs) 13950-14070’ 120 120 1488lbs (12.4ppf) 10. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 11. POOH. Stop at surface to reconfirm well dead and hole full. 12. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. RDMO CTU. 14. RTP or FP well. Attachments: Standing orders flow chart included with this sundry request. * See note above regarding kill methods if pressure observed at surface after perforating. MU lubricator MIST Plug and Addperfs 09-31D PTD: 214197 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Mini Log 7. Tie In Log Current Wellbore Schematic MIST Plug and Addperfs 09-31D PTD: 214197 Proposed Schematic MIST Plug and Addperfs 09-31D PTD: 214197 Coiled Tubing BOPs MIST Plug and Addperfs 09-31D PTD: 214197 Equipment Layout Diagram MIST Plug and Addperfs 09-31D PTD: 214197 Standing Orders for Open Hole Well Control during Perf Gun Deployment MIST Plug and Addperfs 09-31D PTD: 214197 Mini Log MIST Plug and Addperfs 09-31D PTD: 214197 Tie-In Log MIST Plug and Addperfs 09-31D PTD: 214197 MIST Plug and Addperfs 09-31D PTD: 214197 MIST Plug and Addperfs 09-31D PTD: 214197 MEMORANDUM State of Alaska Tubing, g, Jp Alaska Oil and Gas Conservation Commission To: Jim Rei$ � 66C II 6-w DATE: Thursday, May 28, 2020 P.1. Supervisor � SUBJECT: Mechanical Integrity Tests 1 BP Exploration (Alaska) Inc. ped: 09-31D FROM: Bob Noble PRUDHOE BAY UNIT 09-31D Petroleum Inspector 37 4YRTST P/F Sre: Inspector Reviewed By: P.I. Sup" J� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-31D API Well Number 50-029-21396-05-00 Inspector Name: Bob Noble IBSp Num: mitRCN200524141042 Permit Number: 214-197.0 Inspection Date: 524/2020 - Rel Insp Num: Packer 09-31D Type Inj (b ,TVD YP J Depth 8427 2107 Tubing, g, Jp Pretest 2127 - 10 Initial 2137 ' 3000 15 Min 2140 - 2955 39 - 30 Min 45 Min 60 Min 2138 . 2938 39 2141970 Type Test SPT Test psi ped: es BBL Returned: 3.5 OA 37 4YRTST P/F P ✓ Notes: Thursday, May 28, 2020 Page I of I OF T4 • y`�A;11,7y 6.1, THE Slit Alaska Oil and Gas ti� °'A 1�ic� Conservation Commission _ jJ S JL``1 1 f 1 : �� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501 3572 ALASMain: 907.279 1433 Fax: 907.276.7542 www.aogcc.alask .gov Bernhard Stechauner FS2 Lead PE SCS BP Exploration(Alaska), Inc. P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Oil Pool,PBU 09-31D Permit to Drill Number: 214-197 Sundry Number: 318-197 Dear Mr. Stechauner: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French 41— Chair DATED this day of May, 2018. RBDM ',\1 Al 16 2018 STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION C SSION APPLICATION FOR SUNDRY APP ALS U.).5' stop 20 AAC 25.280 MAY 14 2111g 1. Type of Request: Abandon 0 Plug Perforations 0 - Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate 0 - Other Stimulate 0 Pull Tubing 0 Chang ro g Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Set CIBP 10 - 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 214-197 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 0"6. API Number: 50-029-21396-05-00 7. If perforating. 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU 09-31D- 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028327&028328 PRUDHOE BAY.PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15855 • 8875 • 15325 8879 15325 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 48-128 48-128 1490 470 Surface 2499 13-3/8" 47-2545 47-2545 3700/4930 2230/2670 Intermediate 3460 9-5/8" 45-3505 45-3505 6870 4760 Liner 7886 7" 3347-11233 3347-8597 7240 5410 Liner 4720 4-1/2" 11134-15853 8521-8875 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14886-15650 8875-8878 4-1/2"12.6#13Cr85 13Cr85 43-11136 Packers and SSSV Type: 4-1/2"HES TNT Perm Packer Packers and SSSV MD(ft)and TVD(ft): 11009/8427 4-1/2"MCX I-SSV 1993/1993 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 101 • 14.Estimated Date for Commencing Operations: May 21,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Stechauner,Bernhard be deviated from without prior written approval. Contact Email: Bernhard.Stechaunerabp.com Authorized Name: Stechauner,Bernhard Contact Phone: +1 907 564 4594 Authorized Title: FS2 Le-d-PE 57011/1g Authorized Signature:' / Date: 57i t{/1 g COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31 _ ,Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ � � — Other: Post Initial Injection MIT Req'd? Yes 0 No [ I Spacing Exception Required? Yes 0 No W Subsequent Form Required: /0,4-04 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date:5 '1 5 't 5//5/18 RBDM ,MAY 16 2018 G.�5 ORIGINAL .574/ E Submit Form ani Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachm nts in Duplicat 10•Sundry Application for Well PBU 09-31ftTD#214-197) Expected Start Date: May 21, 2018 Current condition of well: WAG Injection Well, Operable, Injecting: Gas Injection Rate: 21959 Mscf/Day Injection Pressure: 3004 psi Shut-in Wellhead Pressure: 1650 psi Reservoir pressure: 3300 psi Well objective(s): This well is a MIST injector that was completed in 2015. Currenity 03-27, 09-04, and 09- 26 see a big MI buzz from this well. We have reached the recommended volume of MI in the current location and it is time to move uphole for the third bulb. We expect the same wells to benefit from this MIST location. Additionally, 09-29 could start to see benefits and the 09-38 injector flowback trial might see support from these perforations as well. No acid job was performed on this well after the previous two sets of perforations. We will use a similar gun system for this add perf and are not planning on a stimulation at this time. Proposed program: 1. Pull MCX, drift to deviation with dmy gun. 2. Mill out CIBP and push to TD, set CIBP at 14,750' MD, and add pelf 3. Set MCX sized for -20MMscf/d (current MCX is 1.14" bean). BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • WOPENDING PERFORATING PROCEDURE global wells organization Well: 09-31D API#:50-029-21396-05 Date: 5/11/2018 Prod Engr Bernhard Stechauner Office Ph: (907)564-4594 H2S Level: Home Ph: 0 ppm Cell/Pager. (907)360-7485 CC or AFE: APBINJEC WBL Entries IOR Type Work Description • 250 C Mill out CIBP,Set new CIBP,Add perfs { Well Objectives and Perforating Notes: See Procedure. Attachment: Tie-in log with proposed perfs annotated Reference Log Tie in Log Add 10 feet Log: PDCL MCBL to the tie-in log to be on Date: 3/24/2015 6/27/2015 depth with the reference log. Company: BP SLB Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone PERF TYPE 14,452' 14,548' 14,442' 14,538' 96 6 Rand ¢0° Z2 ADD PERF Requested Gun Size: 2-7/8" Charge: MaxForce Min Wellbore ID: 3.725 Max Swell in Liquid: 3.047 Max Swell in Gas: N, Is Drawdown Necessary/Desired/Unnecessary During Perforating Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Drift: 15,325 ft MD on 5/13/2017 Est Res.Pres.@ 8,800'TVDss MD is 3300 psi Perforation Summary Summary Dist Well: 09-31D Town: Date: API#: 50-029-21396-05 Prod Engr: Anch Prod Engr P.D.Center PBTD -- _-- General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0 • 0 MI Injector Minaog LA fecIllog ¢roteT 17 Well: 09-31D i 1:8010 sur,x 1.40 1 r.tar ix Osortaloti r{4bL4_IWRIXto4tokMST Gse.: p11xo� _. 'i.... ^ i,ri:'• .re 11.777E 474 .-, 's 9,1414711,HO s-g. ..,v, ,s.e Y:ithi. Sts'!. 001.04/ T i W5 MID e ( G IttiR DMA' 7,1,5 g i GR,t Et,�klie�l '.�.. 1 YI!'f_fN44 J PE Notes a.i 3 *.s'I -�--- - SWT PH 1.T as �n `' ',CIS. (!Er �, W€3_Of, 7A wpY `3 k m•, i t i arsn^Fndaa1teIyn i isnr, .""' RDCPm. ;.,- f4- - t , 6„ g” t 4 £ I "jt gg a if 0 , _ - 2018 Part i 1.7'1::* ' 14,442-14,538'MD I 3 [ MAW- Plug 14,754'MD H., 447th.. ....�,_ .. .. .......__ ...,._.... ,.. jyX t 1 1 {_ $ till _ $ s a { _3 N, ' j li 111111 't }j}jX , j01,,""" Mill out plug and .__... , . push to TD .1 sA,. MI i Y I s g r1 i \II\ - t , „ ,,,,:::t .":,,r1:7:, snot., muk n a r TREE= 4_1/16"CM/ 4 9 31 D WELLFEAD= McEVOY _ NOTES:N25 READINGS AV > GE 125 ppm ACTUATOR= BAKER C 411 ©N M """ WELL ANGLE>70'@ 11667'""CHROME ORB ELEV= 54' I [I TBG1998. LNR' "'MAX4-1/2'HES XNIPDOGL�:15,...3573.1811725.6''•" BF.ELEV 23.0' 9H1 KOP= 4400' — Max Angle 95°@ 11946' —"COND, — ? ' 1993 Datum MD= NIA —#, Datum TVD= 8800'SS D= 13-3/8"CSG,72#,L-80 BUTT,D=12.347" — 2533' (FIRST 2 JOINTS ARE K-55) TOP OF 7"LNR --1 3347' j- - 3347' —9-5/8'X 7'BKR HRD-E ZXPN LW 9-5/8"GEN I Wt-IPSTOCK(02/26/15)H 3505' u �� w!11"TIEBACK D=6.170" 9-5/8"CSG,47#,L-80 BTC,ID=8.681" H —3505 3362' H 9-5/8'X 7"BKR FLEX-LOCK HGR D=6.190' Minimum ID =3.725" tai 11118' 9-5/8'CSG MLLOUT WINDOW(09-31D) 3505'-3522" 4-112" HES XN NIPPLE TOP OF CEMENT TT(7"CSG) —I —5600' 10978' —4-1/2"I IES X NP,ID=3.813" r e.i 1 `r' X, 11009' —17'X 4-1/2"HES TNT PKR,D=1856' ' 11046' —14-1/2"HES X NP,D=3.813" 11118' —4-1/2"I-ES XN NP,D=3.725" P $ TOP OF 4-1/2"LNR H 11133' ►_, $ 11133' 7"X 5"BKR ZXP LW w/11"TEBACK,D=4.330' 4-1/2"TBG,12.6#,13CR-85 VAM TOP, H 11136' VI ‘ 4' *I 11136' —4-1/2'WLEG,D=3.958' .0152 bpi,D=3.958' l JI A 'a 1115T -17'X 5"BKR FLDC-LOCK DG HGR,D=4.310" TOP OF 4-1/2"LNR CMT H -11165' $ 4 I `r V H amo 11 LOGGED / / �� AN IV !; 1116T --I5"X 4-1/2"XO,D=3.900' 7"LNR,26#,L-80,VAM TOP HC, —I 11233' ► p N .0383 bpf,D=6.276" r N r 4 r c 13279' H RA TAG ON STOP RING r • r PERFORATION SUMti1ARY 14664' H RA TAG ON STOP RING re REF LOG:SLB/LWD VISION LOG FROM 02/27-03/17/15 i P ANGLE AT TOP PERF:89°@ 14886' r Note:Refer to Production DB for historical pert data r II SIZE SPF INTERVAL Opn/Sgz S1-10T SOZr 1 2-7/8" 6 14886-14950 0 05/13/17 : 15325' H4-1/2"WFD(3gP(OS/11/17) 2-7/8' 6 15010- 15074 0 05/13/17 r 2-7/8" 6 15500-15650 C 06/29/15 ► P r PBTD H 15768' r r,IIII,' 164, 101046.4 4-1/2"LNR, 12.6#,13-CR VAM TOP, — 15853' t reel. .0152 bpf,D=3.958' DATE REV BY COP UTTS DATE REV BY COMMENTS PRUDHOE BAY LILT 08/07/85 RWN 35 INTIALCOMPLETION 04/03/15 NWJMD ANAL ODE APPROVAL WELL: 09-31D 05/28/86 WW1 R COMPLETION '07/21/15 MSS/AC ADFERFS PERMT No:'2141970 04/21/93 N2ES SIDETRACK(09-31A) 02/15/17 BS/JMD UPDATED D FIRE NFO AR No: 50-029-21396-05 08/06/94 CTU CTD SIDETRACK(09-31B) 05/22/17 AC/JM) SET C38P&ADPERFS(05/11-13/17) SEC 2,T1ON,R15E,1587'FSL&998'FM 04/28/96 NES3 CTD SIDETRACK(09-31C) 03/22/15 PKR 273 SIDETRACK(09-31D) BP Exploration(Alaska) 411/ 21 41 97 "TELL LOG TRANSMITTAL#904029305 2 8 3 5 7 To: Alaska Oil and Gas Conservation Comm. July 3, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage,Alaska 99501 DATA LOGGED JUL 0 7 2017ABENDR K.BENDER RE: Coil Flag Log: 09-31D Run Date:5/10/2017 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 09-31D Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-21396-05 Coil Flag Log(Field Print) 1 Color Log 50-029-21396-05 SCANNED JUL 1 720i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:fi)/41241"*"Ldi') "✓.-E:�ti:� ' STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations I3 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 5 C I g 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 214-197 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-21396-05-00 7. Property Designation(Lease Number): ADL 0028328 8. Well Name and Number: PBU 09-31D 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 15855 feet Plugs 9 measured 15325 feet 1 true vertical 8875 feet Junk measured feet JUN![I'rt' 1 3 2017 Effective Depth: measured 15325 feet Packer measured 11009 feet true vertical 8879 feet Packer true vertical 8427.03 feet AOG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 48-128 48-128 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 3460 9-5/8"47#L-80 45-3505 45-3505 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 14886-14897 feet 14897-14918 feet 14918-14950 feet 15010-15042 feet 15042-15074 feet 15500-15530 feet 15530-15560 feet 15560-15590 feet 15590-15620 feet 15620-15650 feet True vertical depth: 8875-8875 feet feet 8875-8875 feet 8875-8875 feet 8876-8877 feet 8877-8877 feet 8879-8879 feet 8879-8879 feet 8879-8878 feet 8878-8878 feet 8878-8878 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 43-11136 43-8523 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSV 1993 1993 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCA/0* Treatment descriptions including volumes used and final pressure: NOV 0 8 2017, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -18276 30 2833 Subsequent to operation: -26202 198 2829 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG m GINJ 0 SUSP 0 SPLUG 0 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: 317-075 Authorized Name: Stechauner,Bernhard Contact Name: Stechauner,Bernhard Authorized Title: F Lead P ^� Contact Email: Bernhard.Stechauner@bp.com Authorized Signature: / Date: 6/12/17 Contact Phone: +1 907 564 4594 Form 10-404 Revised 04/2017 V/ z- i CO ?- i RBDI IS Vi JU l T .3 2017 4 (0/tr Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED JUN 1 3 2017 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary AOGCC June 12, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Adding of Perforations under Sundry# 317-075 for Well 09-31D, PTD # 214-197. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • w Q0000000 [-is ay 1, Mf-O ICrCOrOd N LO CC) N N co to N- O U I- 00) O M OCOY) N M CON- CX) 0)) IX) 1.0 N- UC) CO 9aO1:1' 0O) N-- Cs O U) U) CO O N CO CO O O O N- CO U) N CO Nt M a CO co O M CO M N r- O LC) OU) N CO CI .F11 Li Q aoN- OtovMM O H 09.1 LO a 0 to 0 Lo 0 �1 � � cooccocco .y N U") 1. N.ti 4 ((0 y 0) a '-cNi = N co co ch L co O CO 0 M CD CO CO CO N OO O M N N r W � Q a)0 C U W W W 0 0 u_ u_ rt a t Z Z irQ W W W m O D D ;- Z Z D 00) (i) -..= M =1 I— • • Packers and SSV's Attachment PBU 09-31D SW Name Type MD TVD Depscription 09-31D SSSV 1993 1992.91 4-1/2" MCX I-SSV 09-31 D PACKER 3357.79 3357.59 7" Baker ZXP Top Packer 09-31D TBG PACKER 11009.19 8427.03 4-1/2" HES TNT Perm Packer 09-31D PACKER 11144.94 8530.04 5" Baker ZXP Top Packer • • 0) 1 c c _z in ih a) Q- = m m to o X. o, _ 2 a To EQ r Q r,...;acO N o ° C i CO J 73 J 73 N to O Oa) Oa) d m -0 cu uai - N N N V N N U L rnos t a .c m J f0 J f0 '0 a) eL a) V O O O M O M O O0 m EL 0)O � o � o a H 5 c � O — 045 (0 O i T- % Ur Q .Q C CCNI O c') 0 2 0 2 HN 0 - O C ch Co O .. COO : —In 0 in 0 +. � � 0 >- ;: CL CO - d CO � .. A CV '47. Ce . tO . 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O m = LO ' c0 Q L •N 'a N •.O � ' 0 O a 0 .0 •N '0 N •_O a ' 0 -C " -5-c N 0 -C Ce .7'4- 0 j Ca-C ? 0) -1).,, •C4- 0 j - .c U j 0)'C E (n N •c • U 7 0)C O Q r U j 0)-0 •c *k _o c •c 3 a � it ..o c _5 ss *k o c c 3 � � 1 # n c .c •3 u) E _ c •c c o � -) c '4 =_ c 'co 't - - C ' gg c ', = E 'co 'C 99 cw = cUDg c `�- � ? 1— * O c O . a) * H * 0N * 1— * O c 0L a) * 1- * 0 c co * I- * O c U * U OE2U o Q* U * Ute * U * U 0E0 c) 0_* U * U OCch * U * U o2 * N- ti I N- r r r r r N N N N N N N N M M r r r r r 1713 I CO CO CO ` 0 • = S0o_ A- Li- A- 13 03Q I \ � m R c / / on ' % / 7 E \ - al06 •- cf % IC ' k % � 2 a) § o G — U a. en = \ % : go o m @ oI. � o a co 3 z - Q = E CO e 2 � : EQ 0_a. � f .0 2k $ 216,Th 09 2 �43 ® 0 � & .D & 0 0) 7 _ 0 a)Co 7 » _0) LI A 0 2 2 p x o L a � pg = O ° ca ® 2 -I & 2 co N— 2 " k a. _1 = A 2 — t = q = c EL ti ® - D • - x o �ZZ \ G ■ o o | - X 0 \ re0Om ii 5 ° � E < 1—LIJ ck k •Cli E & _ a m 0_ & a) CI w ° $ — 0 ƒ 3 2 Ill k ) Q ® » % O « D - 02 Cr) / k 0 / to | 0 E U ƒ 0 o » a02 \ 62 - 00 _ § 0 1k � f & f70o & 5 ¥ _ � O k o£ o a w » , \ d / k _cto - ._ '% u) E & e Ni- 4 co / / kc - k / / LCw ƒ / 0 •- O : 0 o 2 c : : 2 CO CC : to m s ¥ ¥ 0 0 CO q V M. = r — cn 2 c-- 03 n # $ a TREE= ., 4-1/16"CNV • -WELLHEAD= McEVOY 09-31 D SAFE OTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER C WHEN ON M"' WELL ANGLE>70.@ 11667'"""CHROME OKB ELEV= TBG&LNR m MAX DOGLEG:15,5•@ 11756'"" BE REV= 23.0' KOP= 4400' -"COND, .1` ? ' 1993' -4-1/2"FES X NP,D=3.812" Max Angle= 95°@ 11946' Datum MD= WA _#, Datum TVD= 8800'SS D= " 13-3/8"CSG,72#,L-80 BUTT,13=12.347" -i 2533' (FIRST 2 JOINTS ARE K-55) TOP OF 7"LNR - 3347' I-- , 3347' -9-5/8"X 7"BKR HRD-E ZXPN LW 14 1 CI W/11"TACK,D=6.170" 9-5/8"GEN 1 WHIPSTOCK(02/26/15)-I 3505' 9-5/8"CSG,47#,L-80 BTC,ID=8.681" --J -3505 1 3362' H 9-5/8"X 7"BKR FLEX-LOCK HGR,D=6.190" Minimum ID =3.725" @ 11118' 9-5/8"CSG MLLOUT WINDOW(09-31D) 3505'-3522" 4-1/2" HES XN NIPPLE TOP OF CEMENT(7"CSG) H -5600' ' 10978' -�4-1/2"FES X NP,D=3.813" _.,P A $- .L. 11009' -I 7"X 4-1/2"HES TNT PKR,13=3.856" ,Pe ►1Ij ' 'pi I�� 11046' H 4-1/2"FES X NP,ID=3.813" ft $ 11118' _H4-1/2"FES XN NP,D=3.725" j a TOP OF 4-1/2"LNR H 11133` Ph * * 11133' —7"X 5"BKR ZXP LTP ►ig w/11"TEBACK,D=4.330" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, -j 11136' ' ' j �►�;,' 11136' --I4-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" l .►,�''I 11157' -j 7"X 5"BKR FLEX-LOCK DG HGR,D=4.310" TOP OF 4-1/2"LNR CMT H -11155' _ `. '4 lill -I ELND TT LOGO /_/_ 1Igr t 1116T --j 5"X 4-1/2"XO,D=3.900" P Pe 1 7"LNR, r �26#,L-80,VAM TOP HC, - 11233' ' .0383 bpf,D=6.276" ► 4 r N 13279' H RA TAG ON STOP RING r r PERFORATION SUMMARY r 4 14664' -RA TAG ON STOP RING] REF LOG:SLB/LWD VISION LOG FROM 02127-03/17/15 ► le 111 ANGLE AT TOP PERE:89°@ 14886' r Note:Refer to Production DB for historical pert data r M SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2-718' 6 14886-14950 0 05/13/17 O ; 15325' H4-1/2"WFDCBP(05/11/17) 2-7/8" 6 15010-15074 0 05/13/17 2-7/8" 6 15500-15650 C 06/29/15 r PBTD —, 15768' r 15 IkleN4 ► %'%%; J ►'jj�j� R 4-1/2"LNR 12.6#,13-CR VAM TOP, - I 15853' .0152 bpf,D=3.958" DATE REV BY CONWENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/07/85 RWN 35 INITIAL COMPLETION 04/03/15 NWJMD FINIAL ODE APPROVAL WELL. 09-31D 05/28/86 WW1 RECOMPLET1ON 07/21/15 MSS/JMD ADPERFS PERM'T No:'"`L141970 04/21/93 N2ES SIDETRACK(09-31A) 02/15/17 BS/JMD UPDATED PERF NFO API No: 50-029-21396-05 08106/94 CTU CTD SIDETRACK(09-31B) 05/22/17 AC/JMD SET CBP&ADPERFS(05/11-13/17) SEC 2,T10N,R15E,1587'FSL&998'FW... 04/28/96 NE53 CTD SIDETRACK(09-31C) 03/22/15 PKR273 SIDETRACK(09-31D) BP Exploration(Alaska) • • V OF TfJ ��► THE STATE Alaska Oil and Gas Nom►_� , ofLASKA Conservation Commission # } =_ 333 West Seventh Avenue " 2 r C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFA S�� Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner Lead Petroleum Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 SCANNED MAR 1 7 2017, Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-31 D Permit to Drill Number: 214-197 Sundry Number: 317-075 Dear Mr. Stechauner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. d Commissioner DATED this O.'day of February, 2017. RBD MS V/ FEB 2 7 2017 RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 4 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A OG CC 1. Type of Request: Abandon 0 Plug Perforations m - Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate m • Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other D y o r,‘/r n-ract 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 214-197 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ Service H 6. API Number 50-029-21396-05-00 • 7, If perforating: C.c••'• 3((f ! 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? JO Yes 0 No I3 • PRUDHOE BAY UNIT 09-31 D • r i.e-7 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028328 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 15855 - 8875 • 15768 8876 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#I-1-40 48-128 48-128 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 3460 9-5/8"47#L-80 45-3505 45-3505 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr85 13Cr85 43-11136 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"MCX I-SSV 1993, 1993.05 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program EZI BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service ®- 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ® • GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Stechauner,Bernhard be deviated from without prior written approval. Email Bernhard.Stechauner@bp.corn Printed Name Stechauner,Bernhard Title FS2 Lead PE Signature �' _,..., Phone +1 907 564 4594 Date 27 1 t 7 i —/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: ''‘"-1 - 0**7 6 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 �Other: 1-c5 1k Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No B Subsequent Form Required: l 0 ---.'0 Zt Approved by: 62----, COMMISSIONER APPROVED BYTHECOMMISSION Date: Z 125/17 V TL- Z/27 / 14 ORIGINAL RBDMS u,v FEB 2 7 2017 .40 ;;/.37;; hr Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ® • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: 09-31 D Well Type: WAG Injection Well API Number: 50-029-21396-05 Well Activity Conventional 4 Classification: Activity Description: MIST stage plug/perf Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Add Perf+ Prof Mod Estimated Cost, $K: AWGRS Job Scope: PERFORATING Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes PrimarySecondary Required? Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907)360-7485 Well Intervention Engineer: Todd Sidoti Contact numbers: (907) 564-5113 (907)632-4113 Lead Engineer: Danielle Ohms Contact numbers: (907) 564-5759 (907)440-9082 Date Created: January 13, 2017 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate Inj Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (psi) Cut(%) (Mscf/Day) 1/10/2017 0 0 3,040 Current Status: Operable Shut In Inclination>70°at Depth(ft) 11,667' MD Maximum Deviation(Angle and Recent H2S (date,ppm) NA 0 ppmDepth) 11,946' MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 16° 11,755' MD Reservoir pressure(date, psig) NA 3350 estimate Minimum ID and Depth 3.725" 11,118' MD Reservoir Temp,F 190 estimate Shut-in Wellhead Pressure 2,310 psi Known mech. integrity None problems(specifics) Last downhole operation (date, 5/9/2016 Set MCX at 1,993' MD operation) Most recent TD tag(date,depth, toolstring OD) 6/29/2015 15,738' MD Perforate with 2-7/8"PJ Omega Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, This well is a MIST injector that was completed in 2015. Currenity 03-27, 09-04, and 09-26 see a big MI background information, buzz from this well. We have reached the recommended volume of MI in the current location and it is time etc: to move uphole for the second bulb. The well is currenity SI for reservoir management reasons since MI is - a rare comodity and this well has already received its share in the current location. We expect the same wells to benefit from this MIST location. No acid job was performed on this well after the initial perforations.We will use a similar gun system for - the add perf and are not planning on a stimulation at this time. • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Time for next MIST bulb Specific Intervention or Well Objectives: 1 Add perfs for next stage MIST bulb and set plug to isolate all deeper perforations • 2 3 Key risks,critical issues: Mitigation plan: 1 Last coil intervention noticed high pipe wear Use appropriate measures. 2 Job written assuming 30'guns available If we can't use 30'guns,make 4 runs with 25'guns Due to strategic MIST planning,please execute this job 3 Job timing as soon as possible but don't POP until 09-27 CTD is completed(mid Feb 2017) Summary Service Line Activity Step# 1 S Pull MCX, drift to deviation, SBHPS as per attached 2 C Set CIBP and add perf 3 S Set MCX Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 C Set CIBP at 15,330' MD 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: 20 BWPD: Expected Production Rates: FTP(psi): Choke setting: PI (bfpd/psi dp) Post job POP instructions: P01 well to MI once MCX is set at 20MM target injection rate. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • i 0 Injector LI Techlog Minilog ProFeci P80 EWF Well: 09-31D Author Laura.) Larson Scale 1 4000 C)a',e 414/2016 E+,.r(ce+5705 X 717114.11 S. OW C. UM E.wurc'Awes kg r 00I301041 C.0,,,x4rirs,Deo 3101$4421006000 F Ott Prudhoe fey ,tt.".<trt tSVFS ial7xr3s•1412430701 yak» <.t.,. ASr•h,. 4A077APT C xmrl►102470(53 i'S.' SP , 7ura a NEST GRA 1 A . 14.0I 4 Rate oJNnrrrottoa PE Notes BEST.RSHA TVOSS MO 0,2 02120M2 t*' g^ Btsv X0P5 (FEET) (FEET) N a Itkfitx.TVOSS BEST.RDEEP 0 0 F/NX soa :40 100 14000 r saw ft 8700 0.2 OHMM 200 075S 7 it. i7ss ... - Oras ' 020 11754 - MS , C' \- 8620 14000• ....... _. .. Oils 7 1 52250 , 7 cM IX 8610 12500 ._ __.,.__. , _ 3 ' 12750 s 11000+ _ .. 15250 _...._. t 1 i 11500 t 11710' MOO• -. 4 ) c14750 ,....__...__..._ _.___..__...__ ...__._._. .:.....__.._._._._._._.._.._.. _....__.._. '" 14500 'L ,r Add Perf: Mmi • 1500041k- 14,890-14950'MD INIIIM' 8610 ' 15,000-15,060'MD 1SIS0- SetCIBP: j 15,330'MD Mil 15500+ li I - 8610 .. 1 15750 I-' • • Schlumberger Company. BP Exploration (Alaska). Inc. Well. 09-31D Field Prudhoe Bay Borougn: North Slope Stwe. Alaska Memory Cement Bond Log -1 (..) T. f. PSP CBUVDUGR/CCL 27-Jun-2015 FINAL 0, a 5 1587 2T FSL 9984,1'FEL Elev.: K.8 67.05 ft &glace a y.2 s 6 GL. g p fi F c.; gPermanent Oatan MSL E'ev. 0 00 ft 2 CL C) CC -4 log Measured From RKB 67 05 ft wove Perm Datum g• Drilling Measured From: RKB gt t API Sena' No. Section Township Range Cl 50-029-21396-05 2 ION 15L Loggng Date 26-Jur-2015 Run Number 1 Depth Doer 15768 fl Schlumberger Depth ID Not Tagged Bottom Log Interval 15100 ft Top Log Interval 1075011 Casing Paid Type 1%KCI Sanity Density 8 4 Ibm?9al f, Fluid I evel 0 f. B I./CASING/TUBING STRING Bit Size horn To CasingfTubing See 4.530 in Weight 12 6 tint Grade 13-CR VAM TOP From 1116711 To 15853 ft Maximum Recorded Temixiretvres L., • On Bottom Time 26-Jurt-2015 16-43 Unit Nornber Location 59 Prudhoe Bay Recorded By Burd • • Witnessed By I Stevens /Spiier I • S MINI 1111111116111111111110111111111 MI MINI MN E -1100 IIINI ; 1 , p_—,„„,..,,,,,,,,,,.....,-....r...._tia Y OMB =1111•11111111111 NM=Lii 0.•am Mr-I NMW-IIMM.IeRIMIIIII mMNMmsMuBIBI ��11I .•mi...MI1III _mM1M1.1oN.1si1 — .!.1:iI- M 4 _M1.11Ma11.1B1111i ,1 iik;b!.'• i - c7 �1,4q14900 liii _ ' M _ .. � .... ■,.. .= II[1ii mii,..r...•1_ ni.. . " idinum E ENE , _ ,. ....„ .....r .7,.......... ......,OM 11111111•IIII IIIIIMUNINNIP 1111.111111111111 •MIMI OMB NMI =_111 11.111. .11111111111 t r _ MIN IMO ,880. 14,940"1M- ==F in_.-iii IIIN MICA I .....wit IIMM Or OMINIMINI MINI M.i Nom Mim Ms .il ._. 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Z 2 2 0 co co co co co Q :z } O = a r 0 0 0 0 0 O o, OMCOC) N a, co to co Loco 0 Ln Ln Ln Ln LC) TW RI N 0 CD O = U) J = 0 O a J a 1- Q O co cn co co U A. ate „ Cl- C .2 CC WCC ti' wwwww ;, aaaa. a 0. 0 t a) a a, 1- oLn Ln Ln Ln Ln 0 D 0 c 0 0 0 0 0 W J J Z O N N N N N Z �'. 1 1 < W 0) N- N LL O w O CO O -J !] 0 W a a) N N N N N Z a'. 0 W 0 0 W W a LU O CSO CCOO (9 Cfl CO 0 0 W -� J J 0 CC CL < < 21 a 9 co LL LL ILL co a cC a) E c° 00000 CO CO CO CO M a. a co 0 a N a a m rn rn 01) rn rn m a. a a 0 J 0 0 w a C7 O 0 C) 0 Q QCO m LL LL Cn CO a NY • • Packers and SSV's Attachment PRUDHOE BAY UNIT 09-31D SW Name Type MD TVD Depscription 09-31D SSSV _ 1993 1992.91 4-1/2" MCX I-SSV 09-31 D TBG PACKER 3357.79 3357.59 7" Baker ZXP Top Packer 09-31D TBG PACKER 11009.19 8427.03 4-1/2" HES TNT Perm Packer 09-31D TBG PACKER 11144.94 8530.04 5" Baker ZXP Top Packer • TREE= 4-1/16"CNV WELLtfAD= AtEVOY SA NOTES:H2S READINGS AVERAGE 125 ppm �1 .ACTt1ATOR= BAKER C 9_31 D WION M""" WELL ANGLE>70"@ 11667""CHROME OKB.ELEV_ t TBG&LNR"""MAX DOGLEG:15.5•@ 11756'"'" BE ELEV= 23.0' 2 KOP= 4400' Max Angle= 95°@ 11946' J—"GOND, ? ' 1993' —4-1/2"HES X MP,D=3.812" Datum MD= WA --#, Datum TVD= 8800'SS D= 13-3/8"CSG,72#,L-80 BUTT,D=12.347" H 2533' , (FIRST 2 JOINTS ARE K-55) TOP OF 7"LNR --I 3347' jl 3347' —9-5/8"X 7"BKR HRD-E ZXPN LW 9-5/8"GEJ I WHPSTOCK(02/26/15)-I 3505' T ® w/11"TIEBACK,D=6.170" 9-5/8"CSG,47#,L-80 BTC,ID=8.681" H —3505 3362' H9-5/8"X 7"BKR FLEX-LOCK HGR D=6.190" Minimum ID = 3.725" @ 11118' 4-1/2" HES XN NIPPLE <1 WINDOW9-5/$"CSG MLLOUT WINDOW(09-310) 3505'-3522" TOP OF CEMENT(7"CSG) —{ —6600' J t-, , ' II -J4-1/2"HES X NP,D=3.813" .t :~ ` 11009' H7"X 4-1/2"HES TNT PKR D=3.856" r .i, 11046' H4-112"HES X NP,ID=3.813" * 1111W H4-112"HES XN NP,D=3.725" %- I .a t i * TOP OF 4-1/2"LNR — 11133' c* 11133' —7"X 5"BKR ZXP LTP 4. writ"TEBACK,ID=4.330" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, H 11136' \I* 11136' �4-1/2"WLE�,D=3.958" 0152 bpf,D=3.958" +1 J �: — Q 4r 1115T —17"X 5"BKR FLEX-LOCK DG HGR,D=4.310" TOP OF 4-1/2"LNR CMT H —11155' . R `~ • L H ELMD TT LOGGED / / 11167' —{5"X 4-1/2"XO,D=3.900" 7"LNR,26#,L-80,VAM TOP HC, -L 11233'- .0383 bpf,ID=6.276" 13279' —RA TAG ON STOP RING FERFORATION SUMMARY REF LOG:SLB/LWD VISION LOG FROM 02/27-03/17/15 ANGLE AT TOP PERF:91°@ 15500' :._ 14564' --IRA TAG ON STOP RANG Note:Refer to Production DB for historical perf data III "Et3 P SIZE SPF 1'TTERVAL Opn/Sgz SHOT SOZ i {'-5'"t20 2-7/8" 6 15500- 15530 0 06/29/15 . 2-7/8" 6 15530-15560 0 06/28/15 2-7/8" 6 15560- 15590 0 06/28/15 . 2-7/8" 6 15590- 15620 0 06/27/15 .. i.2-7/8" 6 15620- 15650 0 06/27/15 II EY s FBTD -J 1576W .k7.-:74.-'.. 4-1/2"LNR, 12.6#,13-CR VAM TOP, H 15853' *.'.. .0152 bpf,D=3.958" — — DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY INT 08/07/85 RWN 35 IMTIAL COMPLETION 03/27/15 JMD DRLG HO CORRECTIONS _ WELL: 09-31D 05/28/86 WW1 `RECOMPLETION 04/03/15 NWJMJ MAL ODE AF- OVAL PERMT No: 2141970 04121/93 N2ES SIDETRACK(09-31A) 07/21/15 MSS/JMDlADPERFS API No. 50-029-21396-05 08/06/94 CTU CTD SIDETRACK(09-31B) 07/22/15' JO/JMD ADDED PERE REF LOG SEC 2,T1 ON,R15E, 1587'FSL&998'FWL 04/28/96 MEW CTD SIDETRACK(09-31C) 03/22/15 PKR 273 SIDETRACK(09-31D) BP Exploration(Alaska) • • Link, Liz M (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, May 25, 2016 10:02 AM To: AOGCC Reporting (DOA sponsored) Subject: PBU 09-31D / PTD # 214-197 Hello, Please reference the following well: SCAMS JUN 0 1 2016 Well Name: PBU 09-31D Permit#: 214-197 API #: 50-029-21396-05-00 This well began Injection on: May 6, 2016 Method of Operations on this date: Miscible Gas Injection 1 RBDMS MAY 2 5 2016 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,May 19,2016 TO: Jim Regg ]� c (I( Supervisor SUBJECT:Mechanical Integrity Tests P.I.P � � `/ BP EXPLORATION(ALASKA)INC. 09-31D FROM: Jeff Jones PRUDHOE BAY UNIT 09-31D Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JjC- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-31D API Well Number 50-029-21396-05-00 Inspector Name: Jeff Jones Permit Number: 214-197-0 Inspection Date: 5/12/2016 Insp Num: mitJJ160515081342 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 09-310 G ' 8422 2339 2322 , r 2326 2337 PTD T e Test Testpsi Tubing Well Type Inj TVD 2141970 Type SPT 2105.5 IA 476 3000 - 2964 2958- I Interval INITAL P/F P 'r OA 12 - 16 . I 17 17 - Notes: Initial MIT-IA. 1 well inspected,no exceptions noted. ' % WED SEP. 2 7 2016 Thursday,May 19,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 14, 2016 12:54 PM To: AK, D&C Well Integrity Coordinator;AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC IL; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Drotar, Mark; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; jim.regg@alaska.gov' Subject: OPERABLE:Injector 09-31D (PTD#2141970) Passed MIT-IA All, Injector 09-31 (PTD#2141970) passed an AOGCC-witnessed MIT-IA on 5/12/16.The well is reclassified as Operable. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) MAY 1 8 20i1. Office: (907)659-5102 ���� Email: AKDCWellIntegrityCoordinator(a�BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, May 05, 2016 11:49 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Drotar, Mark; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; 'jim.regg@alaska.gov'; AK, D&C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Injector 09-31D (PTD #21 70) Ready to be Placed on Injection All, Injector 09-31 (PTD#2141970)was sidetracked in March 2015 but was never pt,.on injection due to surface constraints. On March 22, 2015 the rig performed a MIT-T and MIT-IA, both passed to 4000 psi. The well is now ready to be placed on injection. The well is now classified as Under Evaluation and placed on the 28 day clock. Plan forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: AOGCC MIT-IA once well is online and thermally stable 3. Well Integrity Superintendent: Make Operable post passing AOGCC MIT-IA Please call with any questions or concerns. • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, May 05, 2016 11:49 AM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OIL; AK, OPS PCC EOC TL;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Drotar, Mark; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; 'jim.regg@alaska.gov'; AK, D&C DHD Well Integrity Engineer Subject: UNDER EVALUATION:Injector 09-31D (PTD #2141970) Ready to be Placed on Injection All, Injector 09-31 (PTD#2141970) was sidetracked in March 2015 but was never put on injection due to surface constraints. On March 22, 2015 the rig performed a MIT-T and MIT-IA, both passed to 4000 psi. The well is now ready to be placed on injection. The well is now classified as Under Evaluation and placed on the 28 day clock. Plan forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: AOGCC MIT-IA once well is online and thermally stable 3. Well Integrity Superintendent: Make Operable post passing AOGCC MIT-IA Please call with any questions or concerns. 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Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0• WDSPL 0 No.of Completions: One • '//// Service 0 Stratigraphic Test 0 2. Operator Name: 6. DaCComp.�usp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc '6/28/2015 214-197• 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 •2/27/2015 50-029-21396-05-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number •3/16/2015 PBU 09-31D " Surface: 1587'FSL,998'FEL,Sec.02,T1ON,R15E,UM • 17. Field/Pool(s): 9. KB(ft above MSL): 67.05' • Top of Productive Interval: 3305'FSL,726'FEL,Sec.03,T1 ON,R15E,UM GL(ft above MSL): 19.8' • PRUDHOE BAY,PRUDHOE OIL • Total Depth: 309'FNL,4027'FEL,Sec.11,T1ON,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: . 15768'/8876' • ADL 028327&028328 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 717376 •y- 5943027 • Zone - ASP 4 •15855'/8875' • TPI: x- 712320 y- 5944601 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: \ Total Depth:x- 714405 y- 5941045 Zone - ASP 4 1993'/1993' 1900'(Approx.) 5. Directional Survey: Yes 0 (attached) No 0 13. Water Depth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) ••3505'/3505' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD/GR/RES.MWD/GR/RES/NEU/DEN/USIT 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 47' 127' 47' 127' 30" 18004 Polyurethane 13-3/8" 72# K-55/L-80 46' 2545' 46' 2545' 17-1/2" 2500 sx CS III,400 sx CS II 9-5/8" 47# L-80 45' 3505' 45' 3505' 12-1/4" 500 sx Class'G',300 sc CS I 7" 26# L-80 3347' 11233' 3347' 8597' 8-1/2" 317 sx Class'G' 4-1/2" 12.6# 13Cr80 11133' 15853' 8521' 8875' 6-1/8" 531 sxClass'G' 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2", 12.6#,13Cr85 11136' 11009'/8427' 2-7/8"Gun Diameter,6 spf - CttBt , 15500'-15530' 8879'-8879' t �t. 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 15530'-15560' 8879'-8879' I P...1'" i 15560'-15590' 8879'-8878' Was hydraulic fracturing used during completion? Per 20 AAC 25.283(i)(2)attach electronic and printed • Yes 0 No RI 15590'-15620' 8878'-8878' v 15620'-15650' 8878'-8878' information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2200' Freeze Protect w/151 Bbls Diesel - 27. PRODUCTION TEST Date First Production: Not on Injection Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(Corr): Press 24 Hour Rate •w+ Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 f 'UG 8 20bmit ORIGINAL only 28. CORE DATA • Conventional Core(s) Yes 0 No RI • Sidewall Cores Yes 0 No WI 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 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No l Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Ugnu 5172' 4994' AAC 25.071. West Sak 7817' 6426' Coleville Mudstone 8734' 6927' HRZ 10941' 8375' Shublik/LCU 11229' 8594' Sadlerochit-Zone 4B 11286' 8638' Zone 4A 11401' 8720' CGL-Zone 3 11504' 8787' BASE OF CGL-ZONE 2C 11587' 8832' Formation at total depth: Zone 2C • 11587' 8832' 31. List of Attachments: Summary of Daily Drilling Reports,Summary of Post-Rig Work,LOT/FIT Summary,Well Schematic Diagram,Survey,Cement Reports Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nocas,Noel Email: Noel.Nocas©bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: ,Phone: +1 907 564 4091 Date: 1/2,7115 INSTRUCTIONS General:This form is designed fo bmitting 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations 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 15.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 TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records 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. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only IFdd`= 4-1/16'C3V11 F12S DINGS AV GE 125 ppm 1/V�tJ LEAD= MbEVOY • 09-31 D SA WHENFEl -•TESWELL ANGLE>70"ft 11667'"'CHROME ACTUATOR= BAKER C O B.ELEV= 54, ' TBG199&LNR"'MAX DOGLEG:15.5- 11756''^' B_ ._--__...._ BF.ELEV= 23.0 KOP= _ 4400 - 2 Max Angie=-95' 95'c 11946' —"COM), — ? ' 1893' —4 12"t$X PF,D=3.812' Datum MD= WA Datum TVD= 8800'SS D= • 13-3/8'CSG,72#,L-80 BUTT,D=12.347' -{ 2533' —A ' (FIRST 2 JOINTS ARE K-55) TOP OF 7"LNR.--{ 334T - I 334T —9-5/8'X r BKR t-RD-E ZXPN LIP 14 9-5/8"GEN I VN-IPSTOCK(0226/15)' 3505' w/11"T�/1C D=6.170' 9-58'CSG,47#,L-80 BTC,ID=8.68V -1 --3505 3367 —9-5/8"X r BKR FLEX-LOCK HGR,D=6.190' Minimum ID = 3.725" @ 11118' 9-5/8'CSG FLOUT WNDOW(09-31D) 3505'-3522' 4-1/2" HES XN NIPPLE • TOP OF CEMENT(7'CSG) -5600' • ieSP ' ' 10978' H4-1/2'FES X NP,D=3.813' Pr � 11009' H 7'X 4-12'FES TNT FKR,D=3.856' tl ' . 11046' H4-1/2"HES XNP,D=3.813' ' 1 11118' F-4-1/2'HES XN NP,D=3.725' TOP OF 4-1/2'LNR I- 11133' 11133' J--7"X 5'BKR ZXP LTP +C Pi w/11"TEBACK,D=4.330' 4-12'TBG,12.6#,13CR-85 VAM TOP, H 11136' 7E' \� 11136' H4-12"WL6G,D=3.958" - .0152 bpf, =3.958' 1115T --r x 5'BKR FLEX-LOCK DG HGR D=4.310' l TOP OF 4-12"LHR CMT -11156' t 1L ELM)TT LOGGED—/ /— l c rt 1116T 5'X4-1/2 X0,0=3.900' 7"LNR,26#,L-80,VAM TOP HC, — 11233' r r. .0383 bpf,D=6276' r N P 13279' —RA TAG ON STOP RING PERFORATION SUMMARY r P. REF LOG:SLB/LWD VISION LOG FROM 02/27-03/17/15 r ' ANGLE AT TOP PERF:91'@ 15500' 14664' —RA TAG ON STOP RING Note:Refer to Production DB for historical perf data r SIZE SPF NTERVAL CIpn/Sgz SHOT SO7 I r 2-7/8"' 6 15500-15530 0 06/29/15 r 2-7/8' 6 15530-15560 0 06/28/15 r 2-7/8' 6 15560-15590 0 06/28/15 r . 2-7/8' 6 15590-15620 0 06/27/15 r ur 2-7/8' 6 15620-15650 0 06/27/15 P P .r PBTD 'H 15768' % ii 412'Ltd 12.6#,13-CR VAM TOP, — 15853' - .0152 bpf,D=3.958" ()ME REV BY CX)MMBJTS DATE REV BY COMMENTS PRUJDHOE BAY UNIT 08/07/85 MN 35 IMTIAL COMPLETION 03/27/15 AU DRLG FID CORRECTIONS W13_. 09-310 0 05/28186 WW1 RECOMPLETION 04/03/15 NN'JM) FNAL OOEAFFROVAL PERMfT No: 2141970 04/21/93 N2E3 SIDETRACK(09-31A) 0721/15.M S/JAA ADFERFS AR Pb: 50-029-21396-05 08/08194 CTU CTD SIDETRACK(09-318) 07/22/15 JO1JM) ADDED PERF REF LOG SEC 2,T10N,R15E, 158T FSL&998'RM_ 04/28/96 NES3 :CTD SIDETRACK(09-31C) 03/22/15 PKR 273 SIDETRACK(09-310) BP Exploration(Alaska) • BP AMERICA >� c. LOT/ FIT Summary.� , � Well Name: 09-31D Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (PPM (psi) (BHP) (psi) (ppg} 03/12/15 FIT 11,233.00 8,597.00 8.60 872.00 4,712.75 10.55 Page 1 of 1 • • North America-ALASKA-BP Page 1 of 37 Operation Summary Report Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release 3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations(hr) (usft) 2/19/2015 18:00 20:00 2.00 ; RIGD P PRE RIG DOWN IN PREPARATION TO MOVE RIG -PIN FORUM CRANE -PREP RIG FOR MODULE SEPARATION -HOOK UP BRIDAL LINES PREP RIG FLOOR TO UD DERRICK SECURE PIPE SHED -DISCONNECT INTERCONNECTS BETWEEN MODULES BEGIN RON EVENT AT 18:00 ON 02/19/15 WITH PARKER 273 RIG. 20:00 - 22:00 2.00 RIGD P PRE PJSM SKID FLOOR -MOVE ROOFTOP WALKWAYS -RIG DOWN MANRIDERSAND PREPARE RIG FLOOR PREPARE PIPE BARN PERFORM DERRICK INSPECTION -SKID RIG FLOOR INTO RIG MOVE POSITION. 22:00 - 23:00 1.00 RIGD P PRE 1 PJSM TO LOWER DERRICK WALKTHROUGH LOWER DERRICK CHECKLISTS 1-LOWER DERRICK -FINAL SLACKOFF WEIGHT ABOVE DERRICK STAND=420 KLBS. 23.00 - 00:00 1.00 RIGD P PRE PREPARE TO SEPARATE MODULES -DISCONNECT FUEL,HYDRAULIC,ELECTRIC I LINES -PREP TIRES -SWITCH OVER POWER 2/20/2015 00:00 - 03:00 3.00 RIGD P PRE I PREPARE TO MOVE RIG FROM L-01ATO DS-09 PREP MODULES FOR SEPARATION -WARM UP TIRES -SEPARATE MUD MOD FROM DRILL MOD AND STAGE DOWN PAD j-SEPARATE DRILL MOD FROM UM AND 'STAGE DOWN PAD 03:00 - 06:00 3.00 RIGD P PRE MOVE UTILITY,DRILL,AND MUD MODULES (SIMULTANEOUSLY)FROM L PAD TO DS-09. STAGE DRILL MODULE BY L PAD EXTENTION -REMOVE WELL HOUSE FROM L-01A WITH CRANE -SEND WELLHOUSE TO DS 09-31 D 06:00 - 00:00 18.00 RIGD P PRE MOVE ALL MODULES FROM L PAD TO DS 09 -MOVE ALL THREE MODS SIMULTANEOUSLY -MOVE MODS ONTO SPINE ROAD AT 1100 HRS -STOP FOR TRAFFIC AND CREW CHANGE AT SANTA FE PAD AT 23:30 HRS 2/21/2015 00:00 - 06:00 6.00 RIGD P PRE MOVE ALL MODULES FROM L PAD TO DS 09 MOVE ALL THREE MODS SIMULTANEOUSLY -MOVE MODS ON K PAD ACCESS -TURN ON TO WEST DOCK ROAD AT 03:30 HRS Printed 7/14/2015 11:42:28AM 11111 North America-ALASKA-BP 4 Page 2 of 37 l is Operation Summary Report" Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date.3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 18:00 12.00 RIGID P PRE MOVE ALL MODULES FROM L PAD TO DS 09 -MOVE ALL THREE MODS SIMULTANEOUSLY -MOVE MODS DOWN WEST DOCK ROAD -MOVE THROUGH DEADHORSE AND ONTO ICE ROAD NOTIFY AOGCC OF UPCOMING BOP TEST AT 1100 HRS 18:00 - 21:30 3.50 RIGID P PRE MOVE ALL MODULES FROM L PAD TO DS 09 MOVE ALL THREE MODS SIMULTANEOUSLY -ARRIVE ON DS 17 AT 1900 HRS CONTINUE ONTO DS-09 21:30 - 00:00 2.50 RIGD P PRE MOVE ALL MODS TO DS-09 -STAGE MODULES ON DS-09 -MOVE ALL MODS ONTO BACK SIDE OF DS-09 BY 09-31 -TEST RIG MOVE ESD 1-PREPARE TO BACK DRILL MOD OVER 09-31 2/22/2015 00:00 - 01:00 1.00 RIGU P PRE RIG UP ONTO DS 09-31 -FLOW STATION 2 LOST SAFETY CRITICAL 'LINE OF SITE'COMMS WITH DRILL SITE FACILITY TROUBLESHOOTING ISSUE DISCUSS WITH PAD OPERATOR AND FLOW STATION 2 CONTROL ROOM -BACK DRILL MOD OVER DS 09-31 -MOVE UTILITY MODULE INTO PLACE -MOVE MUD MODULE INTO PLACE -RAISE DRIVING CABS. COMMS ISSUES STILL PRESENT BETWEEN DRILL SITE AND FACILITY 01:00 - 11:00 10.00 RIGU N WAIT 6.65 PRE DISCUSS OPTIONS WITH PAD OP,CONTROL ROOM,DRILLING SUPERINTENDANT FACILITY OTL REQUESTS THAT RIG STAND BY UNTIL TECHNICALADJUSTMENTS TO COMMUNICATIONS DISHES CAN BE ATTEMPTED 11:00 - 12:30 1.50 RIGU P 6.65 PRE APPROVAL FROM FACILITY LEADERSHIP TO BEGIN RIG-UP PROCESS PJSM RAISE DERRICK AND CONTINUE RIG UP -RAISE DERRICK,LIFT OFF HEADACHE AT 530K,MAX PULL 540K -SKID RIG FLOOR RAISE PIPE CAT -RIG UP INTERCONNECTS CONNECT STEAM,ELECTRICAL PLUG BOARD,ROOF AND FLOOR PANELS 12:30 - 14:00 1.50 RIGU j P 6.65 PRE ;RIG UP -RAISE PIPE CAT -RIG UP INTERCONNECTS -CONNECT STEAM,ELECTRICAL PLUG BOARD,ROOF AND FLOOR PANELS Printed 7/14/2015 11:42.28AM • North America ALASKA BP • 'f q : Operation Summary Report Common Well Name 09-31 AFE No Event Type RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14.00 - 21:30 7.50 RIGU P 6.65 PRE i BRIDLE DOWN,HANG&TIE BACK BRIDLE LINES INSTALL MOUSE HOLES -HANG RIG TONGS -INSTALL MUD LINES&CEMENT LINES TO RIG FLOOR -TAKE ON SEAWATER I-CALIBRATE TOTCO PIT LEVEL SENSORS PJSM INSTALL PIPE WIPER SYSTEM IN FLOW BOX -REVEIW L2RA WITH WELDER AND FIREWATCH 21:30 - 00:00 2.50 RIGU P 6.65 PRE INSTALL ROOFTOP WALKWAYS '-BUILD HANDRAILAND WALKWAY FROM DRILL MOD TO WELL HOUSE I-RIGUP SECONDARY KILL LINE TO IA RIG UP&PT HARDLINE TO OPEN TOP TANK -CHANGE UPPER RAMS FROM 2-7/8"X 5-1/2" VBRS TO 7"FIXED -OPEN RAM DOORS AND INSPECT ALL RAMS 2/23/2015 00:00 - 01:30 1.50 DHB P PRE **ACCEPT PARKER 273 ON DS 09-31D AT 00:01 HRS 02-23-2015** PJSM PRESSURE TEST DOWNHOLE PLUG -PT PLUG FROM BELOW 250 PSI LOW AND 500 PSI HIGH FOR 5 CHARTED MINS EACH -BLEED OFF PRESSURE 01:30 - 02:00 0.50 DHB P PRE HOLD RIG EVAC DRILL WITH LYLE BUCKLER CREW -AAR WITH RIG CREW 02:00 - 05:00 3.00 DHB P PRE PJSM WITH CAMERON TO BLEED CONTROL LINES CONFIRM 0 PSI ON TBG AND IA I-CAMERON BLEED OFF CONTROL LINES MONTIOR TBG,IA AND CONTROL LINES FOR 1 HR 05:00 - 06:30 1.50 DHB N SFAL PRE PJSM NIPPLE DOWN TREE -PREPARE TO N/D TREE TREE CAP GAUGE SHOWS PRESSURE DETERMINE MASTER VALVE TO BE PRESSURE LOCKED -CALL GREASE CREW TO VERIFY VALVES ARE FUNCTIONING PROPERLY GREASE CREW FUNCTION MASTER VALVE AND ENSURE IT IS OPEN 06:30 - 07:00 0.50 DHB P PRE RE-TEST DOWNHOLE PLUG -PT PLUG FROM BELOW 250 PSI LOW AND 500 PSI HIGH FOR 5 CHARTED MINS EACH -CONFIRM 0 PSI ON TUBING DURING TEST -BLEED OFF PRESSURE 07:00 - 10:00 3.00 RIGU P PRE ,PJSM NIPPLE DOWN 5-1/8"MCEVOY 5M TREE AND 11"X 5-1/8"ADAPTER -CAMERON REP AND WSL INSPECT HANGER THREADS THREADS DETERMINED TO BE IN POOR CONDITION i SPEAR WILL NEED TO BE USED TO PULL !HANGER ISA BLANKING PLUG WILL NOT THREAD INTO PROFILE Printed 7/14/2015 11:42:28AM North America-ALASKA BP ' Page 4 of 37 'f u Operation Summary Report ,` ,. ..+rte; y,,.,-.,.,,.,, -. - - _ _ _. _._ _.,��:_ "'✓" d°?� __ Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release 3/22/2015 Rig Contractor PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual©67.05usft(above Mean Sea Level) Date From-To Hrs rs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 18:30 8.50 BOPSUR P PRE PJSM NIPPLE UP 13-5/8"5 M BOP N/U HIGH PRESSURE RISER -N/U BOP I-INFLATE AIR BOOTS FOR BELL NIPPLE AND I FLOW LINE ENERGIZE ACCUMULATOR -BUILD 5"DONUT TEST JOINT -FLUID PACK BOP&CHOKE BLEED AIR FROM LINES 18:30 - 00:00 5.50 BOPSUR P PRE PJSM,TEST 13-5/8",4 PREVENTER BOP AND RELATED EQUIPMENT -UTILIZE PRESSURE CROSSCHECK LIST PRIOR TO TESTING -TEST BOP ACCORDING TO AOGCC,BP REGULATIONSAND PARKER PROCEDURES TEST AGAINST DOWNHOLE PLUG SET AT 500 FT -TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW.3500 PSI HIGH,5 MINS CHARTED 2/24/2015 00:00 - 04:30 4.50 BOPSUR ' P PRE FINALIZE TESTING OF BOP I-TEST UPPER FIXED RAMS WITH 7"TEST JOINT -TEST LOWER VBRS WITH 4"&5"TEST 'JOINT I-TEST BLIND RAMS -TEST HCR KILL AND CHOKE -PERFORM ACCUMULATOR DRAWDOWN TEST PRESSURE TEST BOP AND EQUIPMENT 250 PSI LOW TO 4000 PSI HIGH TEST FOR 5 CHARTED MINS EACH �_. PASSING TESTS 1 II IAAND OA:0 PSI THROUGHOUT TEST PERIOD BLOW DOWN LINES AND RIG DOWN TEST EQUIPMENT SEE ATTACHED DOCUMENTATION BOB NOBLE OF AOGCC WAS WITNESS TO 'BOP TEST 04:30 - 05:00 0.50 DHB C DECOMP PJSM,RIG UP DUTCH RISER I-RIG UP DUTCH RISER FOR SLICKLINE -PREPARE TO PULL DOWN HOLE PLUG AT 500 FT 05:00 - 11:00 6.00 DHB C DECOMP PJSM WITH SLB TO RIG UP SLICKLINE -BRING SLICKLINE TOOL AND PRERSSURE CONTROL EQUIPMENT TO RIG FLOOR -RIG UP SLICKLINE PRESSURE CONTROL EQUIPMENT I-MAKE UP TOOL PER SLB I-PRESSURE TEST DUTCH RISER,QUICK TEST SUB(QTS),SLICKLINE LUBRICATOR AND BOP BODY PT AGAINST DOWNHOLE PLUG AT 500 FT PT 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINS Printed 7/14/2015 11:42:28AM • North America ALASKA BP , Page 5 f Operation Summary Report '%; ".` Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM [Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. I UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 13:30 2.50 DHB C DECOMP SLICKLINE RETREIVE DOWN HOLE PLUG -RIH WITH GS SPEAR&EQUALIZE PLUG -POOH,BREAK OFF AT QTS,RE-PIN GS TOOL M/U TOOL AND TEST AT QTS 3500 PSI FOR 5 MINS RUN IN HOLE AND RETREIVE PLUG 13:30 - 15:30 2.00 DHB C ' DECOMP PJSM RIG DOWN SLICKLINE LAY DOWN TOOLS&PLUG • -RIG DOWN QTS,BOP,AND LUBRICATOR -SEND EQUIPMENT OFF RIG FLOOR 15:30 - 21:00 5.50 PULL P DECOMP PJSM CIRCULATE OUT DIESEL FREEZE PROTECT -VERIFY VALVE LINE UP -PRESSURE TEST LINE FROM IA TO FLOW 'BACK TANK 250 PSI LOW AND 3500 PSI HIGH, 5 MINS EACH -CLOSE BLIND RAMS -PUMP 50 BBL SEWATER,25 BBLS DEEPCLEAN PILL,325 BBL SEAWATER PUMP DOWN-TBG,RETURNS UP IA TO FLOW BACK TANK RATE:6 BPM,435 PSI BLOW DOWN/RIG DOWN SURFACE LINES -MONTIOR WELL, WELL IS STATIC **SIMOPS:RIG UP DAYON CASING TONGS& SLB SPOOLER** 21:00 - 23:30 2.50 PULL P DECOMP PJSM PULL 10"X 5-1/2"MCEVOY TUBING HANGER -MAKE UP SPEAR PER BOT REP DRAIN STACK -RUN IN HOLE AND ENGAGE SPEAR IN TUBING HANGER I-CAMERON BACK OUT LOCK DOWN SCREWS -PULL HANGER OFF SEAT AT 80K LBS (INCLUDING 35K TOP DRIVE) -PULL SPEAR&HANGER TO RIG FLOOR MONITOR WELL FOR 10 MINUTES AFTER PULLING HANGER TO RIG FLOOR,WELL STATIC -LAY DOWN HANGER AND SPEAR ASSEMBLY 23:30 - 00:00 0.50 PULL P DECOMP RIG SERVICE '-LUBRICATE RIG GREASE BLOCKS,TOP DRIVE,IDM 2/25/2015 00:00 - 02:00 2.00 PULL P DECOMP CIRCULATE BOTTOMS UP DIESEL STILL PRESENT IN TBG AND (ANNULUS PUMP SURFACE TO SURFACE CIRCULATE DOWN TBG,RETURNS UP IA TO FLOW BACK TANK RATE:6 BPM,335 PSI -MONITOR WELL FOR 10 MIN:STATIC CHANGE OUT 5"ELEVATORS TO 4 1/2"YC (ELEVATORS Printed 7/14/2015 11:42:28AM 0 North America-ALASKA-BP • e '� Pag6 of 37 Operation Summary Report .1 tuAtor'sigolos: rarvAvoem, ,e,� -,e it .rt' - - -. .f_�_..��,.�' ,e Common Well Name:09-31 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10.093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31D actual t67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth j Phase Description of Operations (hr) (usft) 02:00 - 06:00 1 4.00 PULL P DECOMP POOH WITH 4-1/2"12.6# 13CR TUBING ' -LAY DOWN 1 X 1 IN PIPE SHED -POOH FROM 3715'MD TO-2100'MD -P/U:52K AT 2100 FT I 1 SPOOL CONTROL LINE WITH SLB SPOOLER AT 2100 FT DISCONNECT CONTROL LINE 'FROM SSSV • LAY DOWN SSSV 1 RECOVER 51 STAINLESS STEEL BANDS REMOVE CONTROL LINE SPOOLER FROM RIG FLOOR UTILIZE AIR TOOL TO TAKE OFF CONTROL LINE BANDS -MONITOR TRIP VIA TRIP TANK-PROPER DISPLACEMENT 06 00 07:30 1.50 PULL P 1 DECOMP POOH WITH 4-1/2"12.6# 13CR TUBING -LAY DOWN 1 X 1 IN PIPE SHED -POOH FROM 2,100'MD TO SURFACE I- -MONITOR TRIP-VIA TRIP TANK-PROPER 1 'DISPLACEMENT 92 FULL JOINTS RECOVERED I-4 PUP JOINTS RECOVERED :-1 SSSV AND 2 FLOW COUPLINGS RECOVERED -1 GLM RECOVERED -CUT JOINT=4.09' -TUBING IN GOOD CONDITION , 07-30 - 09:00 1.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR -RIG DOWN CASING TONGS AND SEND OFF FLOOR -CHANGE OUT YC ELEVATORS FOR BX 1 ELEVATORS CLEAN AND CLEAR RIG FLOOR STAGE CLEAN OUT ASSEMBLY TO RIG FLOOR 09:00 - 12:00 3.00 CLEAN P DECOMP PJSM MAKE UP 9-5/8"CLEAN OUT ASSEMBLY i BHA#1 -MAKE UP ASSEMBLY PER BOT REP -RIH WITH BHA -8-1/2"MILL TOOTH BIT,BIT SUB WITH FLOAT ,(2)8-1/2"WATERMELON MILL,6-1/4" BUMPER SUB,(9)6-1/2"DRILL COLLARS,(15) 5"HWDP,X/O SUB PU:86K,SO:82K -OAL OF BHA =779.25" 12:00 - 16:30 4.50 CLEAN P 1 DECOMP 1 RUN IN HOLE WITH 9-5/8"CLEAN OUT ASSEMBLY 1-RIH ON ELEVATORS -RIH WITH 4"DP,1X 1 FROM PIPE SHED -BREAK CIRCULATION EVERY 15 STANDS PUMP 210 GPM(g 125 PSI TAG 4-1/2"STUB AT 3,733'MD _ 16 30 - 18:00 1.50 CLEAN P DECOMP CIRCULATE BOTTOMS UP CIRCULATE SWEEP SURFACE TO SURFACE 1 CLEAN RETURNS PUMP AT 650 GPM&1380 PSI I MONITOR WELL 10 MINS PRIOR TO POOH WELL IS STATIC Printed 7/14/2015 11:42:28AM , Page7ofV North America ALASKA. BP • , � i4VRViVitiZti6hPniFeti",q:- Operation Summary Report Common Well Name.09-31 AFE No Event Type RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 I End Date:3/18/2015 X3-013XD-C.(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:OOAM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual©67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase 1 Description of Operations (hr) (usft) 1 18:00 - 20:00 2.00 CLEAN P DECOMP PULL OUT OF HOLE WITH CLEAN OUT ASSEMBLY -POH ON ELEVATORS FROM 3,733 TO-780' MD I -STAND BACK 4"DP IN DERRICK -MUD WEIGHT IN&OUT=8.5 PPG MONITOR WELL 10 MINS PRIOR TO PULLING BHA THROUGH STACK 20:00 - 21:30 1.50 CLEAN P DECOMP PJSM WITH BOT,LAY DOWN CLEANOUT ,ASSEMBLY I I -BREAK OUT MILL I l-MAKE UP STARTER WINDOW MILL AND WATERMELON MILLS FOR NEXT RUN M/U TO LOWER WATERMELON MILLS FROM 'CLEAN OUT RUN -LAY DOWN IN PIPE SHED 8-1/2"MILLS IN GAUGE,NO SIGNS OF WEAR 21:30 - 22:00 0.50 CLEAN 1 P DECOMP RIG SERVICE CLEAN AND CLEAR RIG FLOOR GREASE ST-80,IDM.BLOCKS,AND TOP DRIVE 22:00 - 00:00 2.00 STWHIP P DECOMP PJSM RIG UP HES E-LINE&EZSV `-,RIG UP E-LINE SHEAVES AND BRING TOOLS TO RIG FLOOR -MAKE UP TOOLS PER HES -RUN IN HOLE WITH EZSV 2/26/2015 ;00:00 - 01:00 1.00 STWH,IP P DECOMP RIH AND SET HES 9 5/8"EZSV(7.75"OD) -RIH WITH EZSV/GR/CCL ON E-LINE FROM SURFACE TO 3630'ELMD -LOG FROM 3630'TO 3150' -RIH TO 3516'MD AND PUT EZSV TOP ON DEPTH AT 3530'MD,5'ABOVE COLLAR -E-LINE SET EZSV, WEIGHT INDICATOR DROPPED FROM 1015 LBS TO 867 LBS INDICATING PLUG SET AND RELEASED. -SET TOP OF EZSV AT 3,530'MD BOTTOM OF EZSV AT 3,533'MD -PULL OUT OF HOLE AND LAY DOWN E-LINE _ I TOOLS ON RIG FLOOR 01 00 - 02:00 1.00 STWHIP P DECOMP PRESSURE TEST 9-5/8"CASING AGAINST EZSV MIT CASING AGAINST EZSV AT 3,530'MD -CONFIRM VALVE ALIGNMENT PRIOR TO 'TEST -PUMPED 45 STKS(4.2 BBLS)TO 4100 PSI FOR 30 CHARTED MINUTES. -30 PSI LOST IN 1ST 15 MINS -0 PSI LOST IN 2ND 15 MINS I-MIT MEETS BP STP CRT-AK-10-45 CRITERIA -BLEED OFF PRESSURE,BLED BACK 4 BBLS -MONITOR WELL,WELL IS STATIC 02:00 - 02:30 0.50 STWHIP P DECOMP PJSM RIG DOWN E LINE 1 I1 I 1 1 -L -MOBILIZE ELINE FROM RIG FLOOR Printed 7/14/2015 11:42:28AM • North America-ALASKA-BP " P e of•47 77,7 Operation Summary Report Common Well Name 09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual(g)67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ! Phase Description of Operations (hr) (usft) 02:30 - 06:00 3.50 WHSUR P DECOMP PJSM NIPPLE DOWN BOP AND REPLACE TUBING SPOOL -DRAIN STACK -LAY DOWN MOUSE HOLE -N/D BELL NIPPLE '-SET BACK RISER AND BOP STACK N/D TUBING SPOOL&CHANGE PACKOFF PER CAMERON REP **BARRIERS FOR BREAKING CONTAINMENT& IPACKOFFCHANGEOUT** -PRESSURE TESTED CEMENT PLUG -PRESSURE TESTED EZSV KILL WEIGHT FLUID.-8.5-PPG SEAWATER MONITORED OUTER ANNULUS WITH 0 PSI, SINCE 0200 HRS,2-23-15. *SIMOPS BUILD 4"DP STANDS OFFLINE 06:00 - 10.00 4.00 WHSUR P DECOMP NIPPLE UP NEW TUBING SPOOL&BOP -NIPPLE UP NEW MCEVOY SSH TUBING SPOOL -INSTALL SECOND ANNULUS VALVE ON TUBING SPOOL -MAKE UP MOUSEHOLE -CAMERON TEST 9 5/8"PACKOFF TO 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 MIN *SIMOPS BUILD 4"DP STANDS OFFLINE 10:00 - 13:00 3.00 BOPSUR P DECOMP PRESSURE TEST BOP SERVICE BREAK AND TUBING SPOOL -R/U TEST PLUG -N/U RISER AND BOP -FILL STACK AND REMOVE AIR FROM LINES -TEST BOP BREAK,TUBING SPOOL AND SECONDARY ANNULUS VALVE PT 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MINUTES -PASSING TEST 13.00 - 14:30 1.50 WHSUR " P DECOMP PREPARE FOR MAKING UP WINDOW MILLING BHA -PULL TEST PLUG I-SET WEAR RING:12.25"ID MOBILIZE BHA COMPONENTS TO RIG FLOOR 14 30 - 17 00 2.50 STWHIP P WEXIT MAKE UP BAKER WHIPSTOCK ASSEMBLY MAKEUP 9-5/8"GEN II 3-STRING MILL AND WINDOW MILL ASSEMBLY -CONFIRM ANCHOR SET FOR 18 KLBS SHEAR AND REMOVAL OF SHIPPING PIN -BOT REP AND SLB DD ON RIG FLOOR I-ORIENT UBHO WITH WHIPSTOCK HIGHSIDE AND CONFIRM GYRO DATA TOOL PROPERLY ORIENTED M/U 9 X 6 1/2"DRILL COLLARS -M/U 2 JOINTS OF 5"HWDP OVERALL BHA LENGTH=864.18'MD Printed 7/14/2015 11:42:28AM • • North America ALAS BP f Page 9 of 37 4.4 ?� Operation Summary Report ter. Common Well Name:09-31 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 i Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual©67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 19:00 2.00 STWHIP P WEXIT RUN IN HOLE WITH 9-518"WHIPSTOCK/MILL ASSEMBLY -RIH FROM 829'MD TO 3,505'MD -PU 130 K,SO 126 KAT 2,726'MD -RIH ON 4"DP FROM DERRICK -FILL PIPE EVERY 15 STANDS -MONITOR TRIP VIA TRIP TANK-PROPER - DISPLACEMENT 19:00 - 21:00 2.00 STWHIP P WEXIT PJSM ORIENT AND SET HIPSTOCK RIG UP WIRELINE AND GYRO W -ORIENT WHIPSTOCK TO 326 DEGREES -POOH WITH GYRO AND SURVEY EVERY 100' MD -RIG DOWN HES WIRELINE 21 00 - 21 30 0.50 STWHIP P WEXIT SET WHIPSTOCK -RIH TO 3,527'MD AND TAG EZSV -PU 128K,SO 124 K -SET WHIPSTOCK PER BAKER REP -S/O 1,8K TO SET ANCHOR -P/U 15K OVER STRING WEIGHT TO CONFIRM ANCHOR SET -S/O 49K AND SHEAR WINDOW MILL OFF OF SLIDE 21:30 - 22.30 1.00 STWHIP P WEXIT PJSM DISPLACE WELL FROM 8.5 PPG SEAWATER N I-DISPLACE WTOELL9.5 TO PPG 9.5 LSPPG D LSND �-610 GPM,690 PSI -RECORD SLOW PUMP RATES WITH NEW BHA AND NEW MUD 22:30 23:30 1.00 STWHIP P WEXIT KICKOFF DS 09-31C SIDETRACK AND MILL WINDOW MILL WINDOW IN 9 MD 5/8"CASING WITH 8-1/2" MILLING ASSEMBLY MILL FROM 3,505 TO 3,508'MD • -513 GPM,845 PSI,90 RPM,2 KFT-LBS TORQUE ON BOTTOM, 1 KFT-LBS TORQUE OFF,2-5 KLBS WOB,120K ROT WT -MONITOR DITCH MAGNETS 23 30 - 00.00 0.50 STWHIP P WEXIT RIG SERVICE CLEAN AND GREASE ST-80CLEAR,IDM,BLOCKSRIGFLOOR,AND TOP DRIVE Printed 7/14/2015 11:42:28AM III North America ALASKA BP "/44� N Page 10 of 37 Operation Summary Report Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay I Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual©67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT 1 NPT Depth Phase Description of Operations (hr) I (usft) 2/27/2015 00:00 - 04:00 4.00 STMILL P WEXIT KICKOFF DS 09-31C SIDETRACK AND MILL WINDOW -MILL WINDOW IN 9-5/8"CASING WITH 8-1/2" MILLING ASSEMBLY -MILL FROM 3,508'MD TO 3,522'MD -DRILLADDITIONAL 20'OF NEW 8-1/2"HOLE TO ENSURE TOP WATERMELON MILL PASSES THROUGH WINDOW i I -513 GPM,845 PSI,90 RPM,2 KFT-LBS 1 TORQUE ON BOTTOM, 1 1 KFT-LBS TORQUE OFF,2-5 KLBS WOB,120K ROT WT -WORK MILLS THROUGH WINDOW MULTIPLE I I !TIMES TO ENSURE SMOOTH WINDOW 1-NO DRAG THROUGH VVfNDOW WITH PUMPS I OFF AND NO ROTATION. -MONITOR DITCH MAGNETS 1-PUMP 30 BBL HIGH VIS SWEEP i 'CONSISTENT AMOUNT OF METAL SHAVINGS 'IN RETURNS THROUGHOUT MILLING OPERATIONS MINIMAL INCREASE IN CUTTINGS RETURNED FROM SWEEP TOP OF WINDOW=3,505'MD,3,505'TVD MIDDLE WINDOW=3,514'MD, 3,514'TVD BOTTOM WINDOW=3,522'MD, 3,522'TVD 04:00 - 05:30 1.50 STMILL P _ �, WEXIT ;CIRCULATE HOLE CLEAN 1-CIRCULATE 2 BOTTOMS UP. 510 GPM,842 PSI -CIRCULATE UNTIL RETURNS ARE CLEAN -PULL INTO WINDOW AND FLOWCHECK I WELL PRIOR TO POOH 05:30 - 07:30 2.00 STMILL P WEXIT PULL OUT OF THE HOLE WITH 8 1/2"MILLING ASSEMBLY -POOH ON ELEVATORS FROM 3,505'MD TO 1841'MD 1-POOH STANDING BACK 4"DP IN DERRICK -MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT -FLOW CHECK WELL PRIOR TO PULLING BHA INTO STACK,WELL IS STATIC 07 30 - 09 30 2.00 1, STMILL P WEXIT PJSM LAY DOWN 8-1/2"MILLING BHA -STAND BACK 5"HWDP -LAY DOWN ALL 9 DRILL COLLARS I 1 1_LAY DOWN MILLING ASSEMBLY PER BAKER CLEAN AND CLEAR RIG FLOOR OF BOT MILLS i 1AND HANDLING TOOLS 1 ALL MILLS IN GAUGE,NO EXCESSIVE WEAR NOTED 09 30 - 10:30 1.00 BOPSUR P WEXIT PJSM FLUSH BOPS -M/U STACK FLUSHING TOOL -WASH AND JET BOPS DOWN PAST I WELLHEAD i j-FUNCTION BOPS I-REFLUSH BOP STACK -CLEAN DITCH MAGNETS Printed 7/14/2015 11:42:28AM III North America ALASKA BP Page 11 of 37 Operation Summary Report Common Well Name.09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 IX3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12.00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 10:30 - 13:30 3.00 DRILL P WEXIT PJSM MAKE UP 8-1/2" DRILLING ASSEMBLY -BRING SLB SUBS AND X/O'S TO THE RIG ,FLOOR I-MAKE UP MOTOR BHA PER SLB I-8-1/2"MILLED TOOTH BIT,6-3/4"XP MOTOR, 8-3/8"N/M STAB,N/M X/O SUB,PERISCOPE 675 LWD,TELESCOPE 675 MWD,NM UBHO ,8-3/8"NM STABILIZER,(3)NM FLEX COLLAR, FLOAT SUB, (15 JTS)5"HWDP,HYDRAULIC [JARS,(5 JTS)5"HWDP,X/O BHA OAL:838.26' -SCRIBE MOTOR TO GYRO DATA FOR OFFSET SCRIBE MOTOR TO MWD FOR OFFSET 13:30 - 15:30 2.00 DRILL P WEXIT RIH WITH 8-1/2"DRILLING BHA -RIH ON ELEVATORS WITH 4"DP FROM DERRICK -RIH FROM 838'MD TO WINDOW AT 3,505' MD. -BREAK CIRCULATION EVERY 10 STANDS 450 GPM,850 PSI -MONITOR TRIP VIA TRIP TANK PROPER DISPLACEMENT 15:30 - 16:00 0.50 DRILL P WEXIT PJSM WITH HES TO RIG UP GYRO '-RIGUPGYRO 16:00 - 23:30 7.50 DRILL j P INTI :DRILL 8-1/2"INTERMEDIATE HOLE ESTABLISH BASELINE ECD WITH 9.5 PPG LSND ECD ACTUAL:10.35 PPG,CALCULATED:10.0 PPG DRILL FROM 3,542'MD TO 3,800'MD(3770' I TVD) -500 GPM, 1480 PSI ON,1210 PSI OFF 40 RPM,3K TORQUE ON,1K TORQUE OFF PU 120K,SO 112K,ROT 116K SURVEY WITH GYRO EVERY 90 FT -ACTUAL ROTATE TIME=0.71 HRS -ACTUAL SLIDE TIME=1.85 HRS TOTAL BIT TIME:2.56 HRS,TOTAL JAR TIME: 2.56 HRS MUD WEIGHT IN&OUT:9.5 PPG 23:30 - 00:00 0.50 DRILL P INTI RIG SERVICE CLEAN AND CLEAR RIG FLOOR GREASE ST-80,IDM,BLOCKS,AND TOP DRIVE Printed 7/14/2015 11:42.28AM Norm America-ALASKA-BP ,, ;,, Page 12 of 37 , Operation Summary Report Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date.3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase i Description of Operations (hr) (usft) 2/28/2015 00:00 - 06:30 6.50 DRILL j P INTI DRILL 8-1/2"INTERMEDIATE HOLE DRILL FROM 3,800'MD TO 4,050'MD 1-505 GPM, 1340 PSI ON,1320 PSI OFF 40 RPM,3K TORQUE ON,1K TORQUE OFF I-PU 121K,SO 121K,ROT 119K FIRST CLEAN SURVEY AT 3,955'MD PUMP 30 BBL HI-VIS SWEEP AT 3955 FT MINIMAL INCREASE IN CUTTINGS RETURNED CIRCULATE BOTTOMS UP AT 4,050'MD -PUMP AT 500 GPM&1,305 PSI -PREPARE TO POOH AND PICK UP ROTARY STEERABLE ASSEMBLY MUD WEIGHT IN&OUT:9.5 PPG MONITOR WELL 10 MINS PRIOR TO POOH: WELL IS STATIC 06.30 - 08.30 2.00 DRILL P INTI PJSM PULL OUT OF THE HOLE WITH 8 1/2" DRILLING ASSEMBLY POOH AFTER OBTAINING REQUIRED BUILD POOH ON ELEVATORS FROM 4,050'MD TO 850'MD POOH STANDING BACK 4"DP IN DERRICK MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT -FLOW CHECK WELL PRIOR TO PULLING BHA INTO STACK,WELL IS STATIC 08:30 - 12.00 3.50 DRILL P INTI PJSM LAY DOWN 8-1/2"MOTOR ASSEMBLY ,-STAND BACK 5"HWDP&FLEX COLLAR -LAY DOWN MOTOR ASSEMBLY PER SLB 12-00 - 14:00 2.00 DRILL P INTI PJSM PULL WEAR RING -MAKE UP WEAR RING PULLING TOOL& PULL WEAR RING -M/U STACK FLUSHING TOOL -FUNCTION TEST BOP 1-WASH AND JET BOP DOWN PAST WELLHEAD -SET WEAR RING:12.25"ID 14.00 - 15:30 1.50 DRILL P INTI PJSM MAKE UP&RUN IN HOLE WITH 8-1/2" SLB RSS ASSEMBLY I-BRING SLB SUBS AND X/O'S TO THE RIG FLOOR -MAKE UP BHA PER SLB 1-8-1/2"PDC BIT,6-3/4"X6 RSS,PD E-MAG RECIEVER,PD FLEX COLLAR, PERISCOPE 675 LWD, TELESCOPE 675 MWD,8-3/8"NM STABILIZER,(3)FLEX COLLAR,FLOAT SUB,(6 JTS)5"HWDP,HYDRAULIC JARS,(14 JTS) 5"HWDP,BOTTLENECK X/O,(96 JTS)4"DP, 8-1/2"GHOST REAMER -OAL OF BHA =829.66 15:30 - 18:00 2.50 DRILL P INTI RIH WITH 8-1/2"RSS DRILLING ASSEMBLY -RIH ON ELEVATORS WITH 4"DP FROM 1 DERRICK RIH FROM 838'MD TO WINDOW AT 3,505' MD. BREAK CIRCULATION EVERY 15 STANDS 450 GPM,800 PSI 1-MONITOR TRIP VIA TRIP TANK.PROPER DISPLACEMENT Printed 7/14/2015 11.42:28AM % • North America-ALASKA BP • ,t Page 13 of 37 s Operation Summary Report Common Well Name.09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date 2/19/2015 End Date.3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI.500292139600 Active datum:09-31 D actual©67.05usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 00:00 6.00 DRILL N WAIT 3,475.00 INTI PHASE 3 WEATHER CONDITIONS DISCUSS PLAN FORWARD WITH SUPERINTENDANT AND ODE STOP RUNNING IN HOLE AT 3,475'MD I-CIRCULATE ACROSS THE TOP OF WELL, MONITOR WELL -SUSPEND ALL OTHER OPERATIONS 24 HR LOSSES:11.2 BBLS OF 9.5 PPG LSND 3/1/2015 00:00 - 17:00 17.00 DRILL N WAIT 3,575.00 INTI PHASE 3 WEATHER CONDITIONS STOP RUNNING IN HOLE AT 3,475'MD CIRCULATE ACROSS THE TOP OF WELL, MONITOR WELL -SUSPEND ALL OTHER OPERATIONS 17:00 - 20:00 3.00 DRILL N WAIT 3,575.00 INTI PHASE 3 CONDITIONS LiFTEDAT 1700 HRS -FRESH RIG TEAM ARRIVE ON LOCATION AT 11800 HRS PRE-SPUD MEETING FOR NEW RIG TEAM WSL DISCUSS RECENT GWO AK INCIDENTS &PRE-SPUD FOR DS 09-31 D ' 1 I-CIRCULATE BOTTOMS UP AT WINDOW I PRIOR TO RUNNING IN OPEN HOLE -425 GPM,945 PSI 20:00 - 20:30 0.50 DRILL P INTI. I RIG SERVICE -ADD OIL TO TOP DRIVE GREASE BLOCKS,WASHPIPE -PERFORM DERRICK INSPECTION 20:30 - 21:00 0.50 DRILL P INTI RIH WITH 8-1/2"RSS DRILLING ASSEMBLY RIH ON ELEVATORS WITH 4"DP FROM I DERRICK P/U:114K,S/O:108K AT 3,472'MD -RIH TO 4050'MD. MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT -ESTABLISH BASELINE ECDS 1-550 GPM AND 1530 PSI -ECD ACTUAL 10.2 PPG,CALCULATED:9.94 PPG SUPER SUCKER THAT WAS BACKED TO CUTTINGS BOX INOPERABLE AND BRAKES LOCKED DUE TO HIGH WINDS/BLOWING SNOW OVER LAST 24 HRS WAITING FOR AVAILABLE CH2 FIELD MECHANIC 21 00 - 00:00 3.00 DRILL N WAIT 4,050.00 INTI FIELD MECHANIC FOR CH2 ON LOCATION, -REPLACEMENT SUPERSUCKER EN ROUTE -MECHANIC WORKING ON SUPER SUCKER AT CUTTINGS BOX -CIRCULATE AND CONDITION MUD -MUD WEIGHT IN:9.5 PPG,M/W OUT: 9.6 PPG 24 HR LOSSES:9 BBLS LSND Printed 7/14/2015 11:42:28AM ONorth America-ALASKA 7 Page 14 of 37 Operation Summary Report Common Well Name.09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/2/2015 00:00 - 02:00 2.00 DRILL N WSEQ 4,050.00 INTI SUPERSUCKER MECHANICAL ISSUES -REPLACEMENT SUPERSUCKER ON LOCATION • -INOPERABLE SUPERSUCKER MOVED FROM CUTTINGS BOX SECOND SUPERSUCKER ISSUES BUILDING VACCUUM SUCTION LINE FROZEN -THIRD SUPERSUCKER ON LOCATION AT 01:30 HRS AND HOOKS UP TO CUTTINGS BOX CIRCULATE AND CONDITION MUD I-550 GPM,1530 PSI -MUD WEIGHT IN:9.5PPG,M/W OUT: 9.5 PPG 02:00 - 12:00 10.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 4,050'MD TO 5,302(5,087'TVD) 600 GPM,2110 PSI ON, 2,085 PSI OFF -170 RPM,5K TORQUE ON,2K TORQUE OFF -P/U=133K,S/0=125K,ROT=125K SURVEY EVERY-90 FT i-SHOOT SURVEY AT 5,217'MD,DLS:5.05 ,DEG I-PICK UP HOLE AND SHOOT SURVEYS AT 5,186'MD AND 5,154'MD -DLS AT 5,186:5.60 DEG -DLS AT 5,154'MD:4.95 DEG 1-MW IN&OUT:9.6PPG PUMP 30 BBL HI-VIS SWEEP AT 4,400'MD& 5,000'MD 1 -35%INCREASE IN CLAY AND SAND IN I RETURNS -ECD ACTUAL 10.59 PPG,CALCULATED:10.0 IPPG ACTUAL ROTATE TIME:6 HRS TOTAL BIT TIME:6 HRS TOTAL JAR TIME:11 HRS 12.00 - 23:30 11.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 5,302'MD TO 6,989'MD(5,928'TVD) -600 GPM,2630 PSI ON, 2,595 PSI OFF !-170 RPM,7K TORQUE ON,5K TORQUE OFF -P/U=152K,S/0=122K,ROT=126K -SURVEY EVERY-90 FT -MW IN:9.5 PPG,MW OUT:9.6 PPG PUMP 20 BBL HI-VIS SWEEP AT 5,500'MD& 6,200'MD&6,700'MD -20%INCREASE IN CUTTINGS RETURNS ECD ACTUAL 10.51 PPG,CALCULATED. 10.27 PPG -KICK WHILE DRILLING DRILL WITH AAR ACTUAL ROTATE TIME:7.35 HRS TOTAL BIT TIME:13.35 HRS TOTAL JAR TIME:18.35 HRS Printed 7/14/2015 11:42:28AM • North America-ALASKA-BP_ -' gage 15 of 37 Operation Summary Report" Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 1 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM i Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual c67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 DRILL P i INTI RIG SERVICE CLEAN AND CLEAR RIG FLOOR GREASE ST-80,IDM,BLOCKS,AND TOP DRIVE 24 HR LOSSES:26 BBLS LSND 3/3/2015 100:00 - 03:00 3.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 6,989'MD TO 7,363'MD -600 GPM,2720 PSI ON, 2,695 PSI OFF l 170 RPM,7K TORQUE ON,5K TORQUE OFF P/U=158K,5/0=124K,ROT=130K SURVEY EVERY-90 FT -MW IN:9.5 PPG,MW OUT:9.6 PPG 1-PUMP 30 BBL HI-VIS SWEEP AT 7,255'MD: 125%INCREASE IN CUTTINGS RETURNS 03 00 - 05:00 2.00 DRILL P INTI 1WORK GHOST REAMERTHROUGH WINDOW OBSERVE TORQUE LIMIT STALL AT 7,363'MD -GHOST REAMER AT WINDOW -PICK UP 20 FT -CBU TO CHECK FOR METAL ACROSS SHAKERS -NO METAL -ATTEMPT TO WORK REAMER THROUGH WINDOW -VARY RPM 40,60,80 RPM AT 4 FPH, !UNSUCCESSFUL -CONTINUE TO STALL AT 7,363'MD -PICK UP5FT -RIH AT 4 FPH&100 RPM -SUCCESSFUL WORK REAMER THROUGH WINDOW AT 7,367'MD -PULL UP THROUGH WINDOW WITH NO ROTATION,SUCCESSFUL. 05:00 - 12:00 7.00 DRILL P INTI i DRILL 8-1/2"INTERMEDIATE HOLE FROM 6,989'MD TO 8,221'MD I-600 GPM,2890 PSI ON, 2855 PSI OFF -170 RPM,8K TORQUE ON,6K TORQUE OFF -P/U=172K,S/0=127K,ROT=138K -ECD:ACTUAL=10.4 PPG,CALC=10.2 PPG -SURVEY EVERY-90 FT -ACTUAL ROTATE TIME=6.9 HRS -MUD WEIGHT:9.5 PPG IN,9.5 PPG OUT PUMP 30 BBL HI-VIS SWEEP AT 7,800'MD: 10%INCREASE IN CUTTINGS RETURNS Printed 7/14/2015 11:42:28AM EJ ` North America ALASKA BP. • Page 16 at 37 Operation Summary Report r Common Well Name:09-31 1AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date.3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 23:30 11.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 8,221'MD TO 9,451'MD I-600 GPM,3610 PSI ON, 3595 PSI OFF I-170 RPM,8K TORQUE ON,7K TORQUE OFF P/U=183K,S/0=132K,ROT=143K -ECD:ACTUAL=11.24 PPG,CALC=10.84 PPG SURVEY EVERY-90 FT ACTUAL ROTATE TIME=8.39 HRS JAR HRS.33.5 MUD WEIGHT:10.1 PPG IN,10.1 PPG OUT -PUMP 30 BBL HI-VIS SWEEP AT 8,500'MD: 10%INCREASE IN CUTTINGS RETURNS I PUMP 30 BBL HI-VIS SWEEP AT 9,000'MD: 5%INCREASE IN CUTTINGS RETURNS START ADDING SPIKE FLUID TO MUD SYSTEM AT 9100',ENTIRE SYSTEM WEIGHTED TO 10.0 PPG IN 2X SURFACE TO SURFACE CIRCULATIONS. 23:30 - 00:00 0.50 DRILL P INTI RIG SERVICE -GREASE TRAVELING ASSEMBLY,ROTARY AND WASHPIPE 3/4/2015 00:00 - 12.00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 9,451'MD TO 10,404'MD I I 4 600 GPM,4050 PSI ON, 4025 PSI OFF -170 RPM,10K TORQUE ON,8K TORQUE OFF -P/U=214K,S/0=143K,ROT=150K -ECD:ACTUAL=11.35 PPG,CALC=10.84 IPPG { SURVEY EVERY-90 FT -ACTUAL ROTATE TIME=8.29 HRS -JAR HRS.42 -MUD WEIGHT:10.1 PPG IN,10.1 PPG OUT I-PUMP 30 BBL HI-VIS SWEEP AT 9,550'MD: 5%INCREASE IN CUTTINGS RETURNS Printed 7/14/2015 11 42:28AM . � r North America-ALASKA BP Page 17,9f 3-7 Operation Summary Report Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 I End Date:3/18/2015 X3-013XD-C:(10,093,450.00) ' Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual©67.05usft(above Mean Sea Level) Date From-To : Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 10,404'MD TO 11,200'MD(8572'TVD) I -550-575 GPM,3820 PSI ON, 3790 PSI OFF I II-170 RPM,11K TORQUE ON,10K TORQUE OFF -P/U=244K,S/O=137K,ROT=165K -ECD:ACTUAL=11.20 PPG,CALC=10.84 PPG SURVEY EVERY-90 FT -ACTUAL ROTATE TIME=9.08 HRS -JAR HRS.50.11 I -MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT j*START ADDING SPIKE FLUID TO MUD I'SYSTEM AT 10200',ENTIRE SYSTEM I I WEIGHTED TO 10.2 PPG.IN 2X SURFACE TO I SURFACE CIRCULATIONS. *CLAY STRINGER AT 11,160'MD.ROP DROP FROM 50 TO 0 FT/HR.RESEAT BIT AND DRILL THROUGH WITH 16K WOB.RESUME I CONTROL DRILL PARAMETERS OF 8K WOB I1 AND 50 FT/HR ROP. I *GEO CALL HRZ TOP AT 10,941'MD AND SET '.MAX DRILL DEPTH OF 11230'MD.INITIATE 1-CONTROL DRILL AT 11,130'MD AT 50FT/HR ' I AND PREPARE FOR DRILLING BREAK TO SIGNIFY LCU. 3/5/2015 00:00 - 00:30 0.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 11,200'MD TO 11,230'MD i 550 GPM,3650 PSI ON, 3600 PSI OFF -120 RPM,11K TORQUE ON,10K TORQUE I OFF -P/U=244K,S/O=137K,ROT=165K I-ECD:ACTUAL=11.20 PPG,CALC=10.84 PPG -SURVEY EVERY-90 FT I-ACTUAL ROTATE TIME=9.08 HRS I I-JAR HRS.50.11 MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT *GEO CALL HRZ TOP AT 10,941'MD AND SET MAX DRILL DEPTH OF 11,230'MD.INITIATE CONTROL DRILL AT 11,130'MD AT SOFT/HR AND PREPARE FOR DRILLING BREAK TO I I SIGNIFY LCU.NO CLEAR DRILLING BREAK 'OBSERVED. 00:30 - 01:30 1.00 DRILL I P INTI CIRCULATE BOTTOMS UP -CIRCULATE BOTTOMS UP LOOKING FOR I SHUBLIK SAMPLES(TRACE LIMESTONE) I RECIPROCATE PIPE 60'MD I I I I -550 GPM,3572 PSI -120 RPM,11K TORQUE -MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT -CALL TOWN GEO Printed 7/14/2015 11.42:28AM • North America ALJ4K 1 „ Page ra of 37 Operation Summary Report` t Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 'X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft). 01:30 - 03:00 1.50 DRILL P INTI DRILL AHEAD 5'MD AS PER TOWN GEO -DRILL AHEAD 5'FT TO 11,235'MD -HOLD DRILLING PARAMETERS CONSTANT, j LOOKING FOR REVERSE DRILLING BREAK -ROP DROP FROM 50 FT/HR TO 20 FT/HR TO 5 FT/HR OVER 5'INTERVAL -550 GPM,3500 PSI 120 RPM,11K TORQUE ON -WOB 8-12K 03:00 - 04:00 1.00 DRILL P INTI CIRCULATE BOTTOMS UP FOR SAMPLES II-CIRCULATE BOTTOMS UP SHUBUK CUTTINGS IN SAMPLES -RECIPROCATE PIPE 60'MD -550 GPM,3572 PSI !-120 RPM,11K TORQUE i-MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT -CALL TOWN GEO DECISION TO CALL TD *TOTAL 4 BOTTOMS UP PRIOR TO POOH. SHAKERS CLEAN AND SHALE LOOKING STABLE. 04 00 - 05:00 1.00 DRILL P INTI PUMP OUT OF THE HOLE FROM 11,235'TO 10,878'MD -OBTAIN SPR ',-MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM:STATIC -86 GPM,250 PSI AT 10,900'MD -P/U 230K,S/O 144KAT 10,900'MD -MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT -MAX TRIP SPEED AT 70 FT/MIN 05:00 - 05:30 0.50 DRILL P INTI 'POOH ON ELEVATORS FROM 10,878'TO 10,640'MD -TIGHT HOLE ENCOUNTERED AT 10640'MD W/30K OVERPULL MONITOR TRIP VIA TRIP TANK:WELL TAKING EXTRA 0.5-1 BBL FOR 5 STANDS 05:30 - 06:30 1.00 DRILL P INTI RIH WITH 1 STAND OF 4"DP FROM 10640'TO 10730'MD -ROTATE AND CIRCULATE 1X BOTTOMS UP TO CLEAN HOLE RECIPROCATE 30' -550 GPM,3550 PSI -100 RPM,11K TORQUE 06 30 - 08:30 2.00 DRILL P INTI POOH ON ELEVATORS FROM 10730'TO 8950' MD TIGHT HOLE ENCOUNTERED AT 10640' 30-45K OVERPULL -ATTEMPT TO WASH THROUGH AT 550 GPM WITH NO ROTATION WITHOUT SUCESS -REAM THROUGH TIGHT SPOT AT 10,640'MD 550 GPM,3355 PSI 100 RPM,9K TORQUE -WIPE THROUGH TIGHT SPOT NO ROTARY OR PUMPS.OBSERVED NO OVERPULL -POOH FROM 10,640'MD TO 8950'MD -COULD NOT WIPE THROUGH TIGHT SPOT AT 8950'MD WITH 30K OVERPULL -MONITOR TRIP VIA TRIP TANK WELL TAKING EXTRA 0.5-1 BBL FOR 5 STANDS Printed 7/14/2015 11:42.28AM • North America-ALASKAP Paw 19 of 37 y „/3 Operation Summary Report' Common Well Name 09-31 lAFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual©67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 08:30 - 09:30 1.00 DRILL P INTI RIH WITH 1 STAND OF 4"DP FROM 8950'TO 9030'MD -ROTATE AND CIRCULATE 1X BOTTOMS UP TO CLEAN HOLE RECIPROCATE 60' -550 GPM,3550 PSI -80 RPM,9K TORQUE 09.30 - 14:00 4.50 DRILL P INTI BACKREAM OUT OF THE HOLE FROM 9030' TO 7265'MD COULD NOT WIPE THROUGH TIGHT SPOT 'AT 8950'MD DECISION MADE TO BACKREAM FOR REMAINDER OF SHORT TRIP,INFORM ODE BACKREAM FROM 9190'TO 7265'MD (ABOVE GHOST REAMER DEPTH AT TD) i-500 GPM,2587 PSI -150 RPM,10K TORQUE,130K ROT WEIGHT -BACKREAM AT 800-1000 FT/HR -GHOST REAMER IN 9 5/8"CASING 14:00 - 15:30 1.50 DRILL P INTI CIRCULATE BOTTOMS UP -ROTATE AND CIRCULATE 2X BOTTOMS UP TO CLEAN HOLE -RECIPROCATE 90' 300 GPM,975 PSI(HAD TO REPAIR SWABS I ON PUMP 2) -100 RPM,5K TORQUE 15.30 - 20:00 4.50 DRILL P INTI RIH WITH 8-1/2"INTERMEDIATE BHA FROM 7265'TO 11,175"MD RIH ON ELEVATORS WITH 4"DP STANDS FROM THE DERRICK - FILL PIPE EVERY 15 STANDS -RIH FROM 7265'MD TO 10230'MD -TAG TIGHT SPOT AT 10230'MD WITH 30K DOWN,30K OVERPULL ATTEMPT TO WORK THROUGH TWICE WITH NO SUCCESS -REAM STAND DOWN AND UP AT 550 GPM, 3550 PSI,100 RPM,11K TORQUE -RUN STAND IN ON ELEVATORS,HOLE SLICK -TAG TIGHT SPOT AT 10,335'MD WITH 40K DOWN,40K OVERPULL ATTEMPT TO WORK THROUGH TWICE WITH NO SUCCESS -REAM STAND DOWN AND UP AT 550 GPM, 13550 PSI,100 RPM,11K TORQUE -RUN STAND IN ON ELEVATORS,HOLE SLICK -TAG TIGHT SPOT AT 10,445'MD WITH 40K DOWN,40K OVERPULL -ATTEMPT TO WORK THROUGH TWICE WITH NO SUCCESS -REAM STAND DOWN AND UP AT 550 GPM, 3550 PSI,100 RPM,11K TORQUE -RUN STAND IN ON ELEVATORS,HOLE SLICK RIH FROM 10,530'MD TO 11,175 MD WITH NO ADDITIONAL TIGHT SPOTS Printed 7/14/2015 11.42:28AM , •„ anzeototwoomplowir,: North America-ALASK BP/, Pale 20 of 37 Operation Summary Report � . Common Well Name 09-31 AFE No Event Type RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ! Phase Description of Operations (hr) (usft) 20:00 - 23:30 3.50 DRILL P INTI CIRCULATE BOTTOMS UP 4 TIMES AT 11,235' MD -WASH LAST STAND TO BOTTOM FROM 11,175'MD TO 11,235'TD -550 GPM,3850 PSI -TAG UP AT 11,215'MD WITH 200 PSI INCREASE IN PUMP PRESSURE AND 15K DOWN -ROTATE 40 RPM,11K TORQUE AND REAM DOWN LAST 20' -CIRCULATE TO CONDITION HOLE -550 GPM,3600 PSI -100 RPM,10K TORQUE OFF -PU 240K SO 150K ROT 166K RECIPROCATE 60' -ECD:ACTUAL=10.95 PPG,CALC=10.84 PPG -MUD WEIGHT=10.2 PPG IN,10.2 PPG OUT -PUMP 60 BBL HI-VIS SWEEP-MINIMAL INCREASE IN CUTTING WITH SWEEP AT SURFACE -SOME 1"-3"CHUNKS OF UGNU COAL ACROSS SHAKERS THAT CLEARED UP AFTER CIRCULATION i*HAD 2 SWABS GO OUT ON PUMP 1. CONTINUE CIRCULATION AT 450 GPM UNTIL SWABS REPLACED AND RESUME CIRCULATION AT 550 GPM 23:30 - 00:00 0.50 DRILL P INTI RIG SERVICE -GREASE WASHPIPE,BLOCKS AND TRAVELING ASSEMBLY 3/6/2015 00:00 - 01:30 1.50 DRILL P" INTI PUMP OUT OF THE HOLE FROM 11,235'TO 10,878'MD -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM:STATIC -86 GPM,250 PSI AT 10,900'MD P/U 240K,S/O 135K AT 10,900'MD -MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT -MAX TRIP SPEED AT 70 FT/MIN 01:30 - 02:00 0.50 DRILL P INTI POOH WITH 8 1/2"BHA ON ELEVATORS FROM 10,878'TO 10,020'MD -TIGHT HOLE ENCOUNTERED AT 10,660'MD, WITH 35K OVERPULL -WIPE THROUGH TIGHT SPOT TWICE.NO OVERPULL OBSERVED -POOH FROM 10,660'MD TO 10,020 MD WITH I NO ADDITIONAL TIGHT SPOTS MONITOR TRIP VIA TRIP TANK WELL TAKING EXTRA 0.5-1 BBL FOR 5 STANDS 02:00 - 02:30 0.50 DRILL P INTI RIH WITH 8-1/2"INTERMEDIATE BHA FROM 10,020'TO 10,600'MD -RIH ON ELEVATORS WITH 4"DP STANDS FROM THE DERRICK FILL PIPE EVERY 20 STANDS -NO TIGHT SPOTS ENCOUNTERED 1-MONITOR TRIP VIA TRIP TANK:WELL TAKING EXTRA 0.5-1 BBL FOR 5 STANDS Printed 7/14/2015 11.42'28AM J orth America ALASKA 13P Page 21 of 37 -r,c,:,:-::-2,'Ilk,,,o,/;4004CLAN/i!..Wiki: fi:-; Operation Summary Report Ark Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 0 0 5.50 DRILL P INTI POOH WITH 8 1/2"BHA ON ELEVATORS FROM 10600'TO 3477'MD WIPE THROUGH PREVIOUS TIGHT SPOT AREAS 9750-9850 AND 8700-8650'MD -MONITOR TRIP VIA TRIP TANK:WELL TAKING EXTRA 0.5-1 BBL FOR 5 STANDS -OBSERVED NO OVERPULL F/8,700'T/3,477' MUD WEIGHT 10.2 PPG IN,10.2 PPG OUT -MONITOR WELL AT WINDOW:STATIC 08:00 - 08:30 0.50 DRILL P INTI CBU 1X BOTTOMS UP 600 GPM,2005 PSI 80 RPM,TQ 2K,RECIPROCATE 90' 08:30 - 10:30 2.00 DRILL P INTI POOH WITH 8 1/2"BHA ON ELEVATORS FROM 3477'TO 829' PU 109K,SO 109K AT 3477' I-MONITOR TRIP VIA TRIP TANK,WELL TAKING EXTRA 0.5-1 BBL FOR 5 STANDS -MUD WEIGHT 10.2 PPG IN,10.2 PPG OUT 10:30 - 11:00 0.50 BOPSUR P INTI WEEKLY BOPE FUNCTION TEST ,-MONITOR WELL FOR 10 MINUTES,CONFIRM STATIC -PUMP OUT STACK FUNCTION ANNULAR,LOWER PIPE RAMS, AND HCR'S,VERIFY W/SECOND PERSON PRIOR TO FUNCTIONING 11 00 - 12:00 1.00 DRILL P INTI L/D BHA -STAND BACK 3 STANDS OF 5"HWDP FOR UPCOMING LINER RUN { -REMOVE 4"INSERTS AND INSTALL 5" INSERTS IN PS-21'S -REMOVE 4"INSERTS AND INSTALL 5" I INSERTS IN BX ELEVATORS MONITOR WELL VIA TRIP TANK,WELL TAKING EXTRA 0.5-1 BBL FOR 5 STANDS 12:00 - 14:30 2.50 DRILL P INTI L/D SLB 8-1/2"INTERMEDIATE BHA -L/D REMAINING 5"HWDP -L/D FLEX COLLARS,LWD,MWD,RSS,BIT -CLEAN AND CLEAR RIG FLOOR -GHOST REAMER 1/8"UNDERGUAGE 14:30 - 16:00 1.50 DRILL P INTI CHANGE OUT SAVER SUB -CHANGE OUT SAVER SUB FROM 4"XT-39 TO 4 1/2"IF -RE-TAP STRIPPED THREAD ON COMPRESSION RING 16.00 - 16:30 0.50 DRILL P INTI RIG SERVICE -GREASE WASH PIPE,ROLLER ASSEMBLY 1-GREASE BLOCKS AND PS-21S 16:30 - 19:00 2.50 CASING P INTI RIG UP DOYON CASING EQUIPMENT Ij!-REMOVE BX ELEVATORS INSTALL VOLANT RUNNING TOOL I-INSTALL BAIL EXTENSIONS AND 7"SIDE DOOR ELEVATORS -RIG UP FILL UP HOSE 19:00 - 20:30 1.50 CASING P INTI MAKE UP HANGER ASSEMBLY AS PER BAKER M/U BAKER ZXPN LINER HANGER ASSEMBLY AND TWO SINGLES OF HWDP RACK BACK IN DERRICK Printed 7/14/2015 11:42:28AM Qf(1 AITl2Flf1 ALASKA Page 22 of 37 Operation Summary Report Common Well Name.09-31 I AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 i End Date:3/18/2015 X3 013XD C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To I Hrs I Task Code NPT I NPT Depth Phase I Description of Operations (hr) (usft) 20:30 - 00:00 i 3.50 CASING P INTI RUN 7",26#,L-80,VAM TOP HC LINER TO 1500'MD -CHECK FLOATS,GOOD I-USE JET LUBE SEAL GUARD PIPE DOPE I-TORQUE CONNECTIONS TO 11,950 FT-LBS BAKER LOCK SHOE TRACK ASSEMBLY I-RUN 1 FLOATING CENTRALIZER ON JOINTS `3-48 -FILL CASING EVERY 10 JOINTS -PU 64K,SO 64K -BREAK CIRCULATION EVERY 10 JTS AT 3 BPM FOR-5 MINUTES MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT 3/7/2015 00:00 - 03:30 3.50 CASING P INTI RUN 7",26#,L-80,VAM TOP HC LINER FROM 1500'TO 3500'MD USE JET LUBE SEAL.GUARD PIPE DOPE -TORQUE CONNECTIONS TO 11,950 FT-LBS RUN 1 FLOATING CENTRALIZER ON JOINTS 3-48 -FILL CASING EVERY 10 JOINTS -PU 106K,SO 102K -BREAK CIRCULATION EVERY 10 JTS AT 3 BPM FOR-5 MINUTES -MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT -MONITOR TRIP VIA TRIP TANK:WELL TAKING EXTRA2.1 BBLS PER 10 JOINTS. 03:30 - 04:30 1.00 CASING P INTI CIRCULATE BOTTOMS UP AT THE WINDOW II-CIRCULATE BOTTOMS UP 1.5 TIMES AT 3494' 1-6 BPM,524 PSI -PU 95K,SO 86K -MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT 04:30 - 14:30 10.00 CASING. P INTI RUN 7",26#,L-80,VAM TOP HC LINER FROM 3494'TO 7856'MD -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 11,950 FT-LBS I-FILL CASING EVERY 10 JOINTS BREAK CIRCULATION EVERY 10 JTS AT 3 I BPM FOR-5 MINUTES -MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT -MONITOR TRIP VIA TRIP TANK WELL TAKING EXTRA 1-1.5 BBLS PER 10 JOINTS. 14:30 - 15.00 0.50 CASING P INTI RIG DOWN DOYON CASING EQUIPMENT -REMOVE BAIL EXTENSIONS AND 7"SIDE DOOR ELEVATORS RIG UP BX ELEVATORS RIG DOWN VOLANT RUNNING TOOL 15:00 - 17:30 2.50 CASING P INTI 1-MAKE UP LINER HANGER/PACKER I ASSEMBLY TO 7"LINER AS PER BAKER -INSTALL LINER WIPER PLUG ON BOTTOM OF RUNNING TOOL -RUN IN HOLE TO 7989'MD -PU 205K SO 120K -CIRCULATE 1.5X LINER VOLUMES AT 3 BPM, 400 PSI Printed 7/14/2015 11:42:28AM • Narth Arnenca AL3.ASKA • Page 23,9f 37 Operation Summary Report' ` Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 22:00 4.50 CASING I P INTI RUN IN HOLE WITH 7"LINER ON DRILL PIPE FROM THE DERRICK -RUN IN HOLE WITH 7"LINER ON 4 STANDS AND 1 SINGLE OF 5"HWDP FROM 7856'TO 7976'MD RUN IN HOLE WITH 7"LINER ON 5"DRILL PIPE FROM 7976'TO 10,800'MD TO TOP OF HRZ -BREAK CIRCULATION EVERY 5 STANDS STAGING UP TO 3 BPM FOR 5 MINUTES -RUN IN HOLE WITH 7"LINER ON 5"DRILL PIPE FROM 10,800'TO TD AT 11,235'MD I-OBTAIN PU/SO WEIGHTS EVERY 5 STANDS 1-PU 330K,SO.152KAT 10,800'MD i-MUD WEIGHT:10.2 PPG IN,10.2 PPG OUT - 00:00 2.00 CASING P INT1 22:00 I CIRCULATE AND CONDITION MUD -STAGE PUMPS UP TO 7 BPM -INITIAL CIRCULATING PRESSURE 710 PSI, FINAL CIRCULATING PRESSURE 590 PSI -RECIPROCATE PIPE 5FT(PIPE STRECTH ONLY) STAGE UP PUMPS -0.5 BPM:ICP 510 PSI,100% RETURN FLOW 1 BPM:ICP 555 PSI,100% RETURN FLOW 1.5 BPM:ICP 611 PSI,100% RETURN FLOW -2 BPM:ICP 635 PSI,100% RETURN FLOW -2.5 BPM:ICP 650 PSI,100% RETURN FLOW -3 BPM:ICP 675 PSI,100% RETURN FLOW 3.5 BPM:ICP 700 PSI,100% RETURN FLOW 4 BPM:ICP 754 PSI,100% RETURN FLOW -4.5 BPM:ICP 830 PSI,100% RETURN FLOW (PRESSURE INCREASED 100-150 PSI ' INDICATING PACK OFF BACK OFF TO 4 BPM) 1-4 BPM:ICP 800 PSI,100% RETURN FLOW 1"5 BBLS LOSS DURING STAGE UP CIRCULATION TO 4 BPM Printed 7/14/2015 11.42:28AM III North America ALASKA BP ase P 24 of 37 Operation titninary Report 114, Common Well Name:09-31 AFE No Event Type RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date I From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/8/2015 00:00 - 12:00 11.00 CASING P INTI CIRCULATE AND CONDITION MUD -STAGE PUMPS UP -4 BPM:ICP 760 PSI,100% RETURN FLOW -4.5 BPM:ICP 830 PSI,100% RETURN FLOW (PRESSURE INCREASED 200 PSI AND CLIMBING INDICATING PACK OFF) •—SHUT OFF PUMPS AND RE-START STAGE UP I-1 BPM:ICP 400 PSI,100% RETURN FLOW -1.5 BPM:ICP 465 PSI,100% RETURN FLOW 1-2 BPM:ICP 490 PSI,100% RETURN FLOW 2.5 BPM ICP 510 PSI,100% RETURN FLOW 3 BPM:ICP 560 PSI,100% RETURN FLOW -3.5 BPM:ICP 630 PSI,100% RETURN FLOW t-4 BPM:ICP 680 PSI,100% RETURN FLOW I-4.5 BPM:ICP 750 PSI,100% RETURN FLOW (PRESSURE INCREASED 150-200 PSI AND CLIMBING INDICATING PACK OFF) -3 BPM:ICP 595 PSI,100% RETURN FLOW -3.5 BPM:ICP 680 PSI,100% RETURN FLOW -4 BPM:ICP 760 PSI,100% RETURN FLOW -4.5 BPM:ICP 850 PSI,100% RETURN FLOW -5 BPM:ICP 1065 PSI,100% RETURN FLOW -1-2 BBUHR LOSSES WHILE CIRCULATING -RECIPROCATE PIPE 3-5 FT(PIPE STRETCH ONLY) MUD CONDITIONED TO 10.2 PPG IN/10.2 PPG OUT I CALL ODE:DISCUSS TO PUMP A WEIGHTED SWEEP WITH ELEVATED VIS TO ATTEMPT TO CLEAN HOLE AND REMOVE PARTIAL PACK OFF 12:00 - 18.00 6.00 CASING P INTI PUMP WEIGHTED SWEEP ,,-PUMP 10.7 PPG,30 BBL WITH ELEVATED VISCOSITY NO INCREASE IN CUTTINGS WITH SWEEP AT SURFACE -PRESSURE GRADUAL INCREASE FROM 1100 PSI TO 1235 PSI OVER 6 HOUR CIRCULATION -CALL ODE TO DISCUSS:PERMISSION TO PROCEED WITH CEMENT JOB 18:00 - 22:00 4.00 CASING P INTI I CIRCULATE AND CONDITION WELL -PJSM FOR CEMENT JOB -CIRCULATING PRESSURE SPIKE FROM 1180 PSI TO 1350 PSI AND CLIMBING DURING MEETING REDUCE PUMP RATE TO NOT INDUCE ILOSSES -STAGE UP PUMPS GRADUALLY TO 3-5 BPM WORKING THROUGH SMALL PARTIAL PACKOFFS -CIRCULATE 4.5-5 BPM UNTIL PRESSURE CONSISTENT FOR CEMENT JOB FINAL CIRCULATING PRESSURE 4.5 BPM, 1030 PSI Printed 7/14/2015 11:42:28AM North America-ALASKA BP .Page 25 of 37• Op▪e▪ ration Summary Report 7 �' Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud DateTme:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 CASING P INTI CEMENT 7"INTERMEDIATE LINER AS FOLLOWS: PRESSURE TEST SLB LINES 250 LOW,4500 PSI HIGH -PUMP 50 BBLS OF 12.0 PPG MUD PUSH II SPACER @ 5 BPM,ICP 1175 PSI,FCP 1240 PSI,95%RETURN FLOW PUMP 66 BBLS OF 15.8 PPG CLASS G TAIL @ 5 BPM,ICP 1537 PSI,FCP 1440 PSI EXCESS IVOLUME 30% (YIELD 1.17 CU.FT/SK)95% RETURN FLOW DROP DRILL PIPE WIPER DART PERFORM DISPLACEMENT WITH SLB PUMPS -DISPLACEMENT FLUID:10.2 PPG,LSND CHASE WIPER DARTAT 7BPM UNTIL CATCH ,PRESSURE -PUMP 10 BBLS WATER AT 5 BPM AND SWITCH TO MUD ICP 1420 PSI 10%RETURN FLOW,FCP 1400 PSI 10%RETURN FLOW 50 BBLS DISPLACED AT 5 BPM:ICP 1188 PSI 11%RETURN FLOW,FCP 1398 PSI 95% RETURN FLOW 1-10 BBLS DISPLACED AT 3 BPM:ICP 1200 PSI -10%RETURN FLOW,FCP 1240 PSI 95% tRETURN FLOW LATCH UP CONFIRMED AT 53.5 BBLS DISPLACED(PRESSURE INCREASED FROM 1300 PSI TO 2000 PSI WHEN DART LATCHED) -175 BBLS DISPLACED AT 5 BPM:ICP 1570 PSI 95%RETURN FLOW,FCP 1870 PSI 95% RETURN FLOW Printed 7/14/2015 11:42:28AM ' Aww•`.,' ;;:44:4Y&6o:-444 „v3 , North America-ALASKA-BP • '''',4,:?.;gffyg*::','.p page 26 of 37 74:11re.,;;w5tfr4,1%. 66,00*tf;y4:;;;e4M*14 Operation Summary Report',.!".0S4',,-i;;'(-`tt - _ Common Well Name 09-31 AFE No Event Type RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 1 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay 1 Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31D actual @67.05usft(above Mean Sea Level) Date 1 From-To 1 Hrs Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (usft) 3/9/2015 00:00 - 02:00 2.00 CASING P ' INTI CONTINUE CEMENT 7"INTERMEDIATE LINER AS FOLLOWS: DISPLACE -10 BBLS DISPLACED AT 3 BPM:ICP 1600 PSI 95%RETURN FLOW,FCP 1635 PSI 95% RETURN FLOW -40 BBLS DISPLACED AT 5 BPM:ICP 1870 PSI 195%RETURN FLOW,FCP 2020 PSI 95% RETURN FLOW 1 1 -10 BBLS DISPLACED AT 3 BPM:ICP 1620 PSI 90%RETURN FLOW,FCP 1672 PSI 95% RETURN FLOW(CEMENT PASSING SHOE) -40 BBLS DISPLACED AT 4 BPM:ICP 1770 PSI 95%RETURN FLOW,FCP 1740 PSI 95% RETURN FLOW -REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 1100 PSI -STOP PUMPS AT 354.5 BBLS(353 LINER VOLUME AND 3.4 BBL SHOE TRACK) I-CALL ODE TO DISCUSS:DECISION TO PUMP 1 MORE BBL:NO PLUG BUMP WITH 0.8 BBL 1,CEMENT IN SHOE -CHECK FLOATS-GOOD CALL ODE AND VVTL TO DISCUSS:DECISION TO LEFT HAND SECONDARY RELEASE AND SET LINER TOP PACKER -TOTAL LOSSES DURING CEMENTING AND DISPLACEMENT:58 BBLS. 1 -TOTAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE:3 BBLS. -CEMENT IN PLACE AT 00:55 ON 03/09/2015 1-RECIPROCATE PIPE 4 FT AT SURFACE(PIPE I STRETCH ONLY)DURING CEMENTING UNTIL MUD PUSH PASSED SHOE. 02.00 - 03:00 1.00 CASING P INTI SET BAKER LINER TOP PACKER -R/D CEMENT HOSE TO BAKER CEMENT 1HEAD TRAP 4650 FT-LBS LEFT HAND TORQUE -WORK TORQUE DOWN TO HANGER S/O TO 60K AND P/U TO 100K -OBSERVE SHEAR OF SECONDARY RELEASE SHEAR PINS -ROTATE 1 TURN BACK TO THE RIGHT -PICK UP AND CONFIRM RELEASE -P/U AND BREAK OVER AT 116K -P/U 7'TO EXPOSE DOG SUB S/O 60K AND SET LINER TOP PACKER -PICK UP AND ROTATE 20 RPM,700 FT-LBS 1TORQUE -S/O TO 50K AND CONFIRM PACKER SET -UNSTING FROM LINER HANGER AND MARK NO GO 03.00 - 04:00 1.00 CASING P INTI CIRCULATE BOTTOMS UP 10 BPM,350 PSI -NO LOSSES -RECIPROCATE PIPE 40'ABOVE NO-GO Printed 7/14/2015 11-42 28AM North America-ALASKA-BP • Page 27 of 37 Operation Summary Report Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual 167.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 09:00 5.00 CASING p INT1 i POOH WITH BAKER RUNNING TOOL -MONITOR WELL FOR 10 MIN:STATIC -POOH WITH BAKER LINER RUNNING TOOL AND UD 5"DP AND 5"HWDP TO PIPE SHED -LAY DOWN HRD RUNNING TOOL PER BAKER REP NO DAMAGE TO BAKER RUNNING TOOL, DOGS SHEARED INDICATING GOOD PACKER SET A HALF FIN OF DRILL PIPE WIPER DART WAS ATTACHED TO THE LINER RUNNING TOOL -MONITOR TRIP VIA TRIP TANK PROPER DISPLACEMENT 09:00 10:30 1.50 CASING P INTI CLEAN AND CLEAR RIG FLOOR -DRAIN STACK -PULL WEAR RING I-FLUSH BOPS AND -SET CAMERON TEST PLUG AND RUN IN LDS 10:30 - 13:00 2.50 BOPSUR P INTI CHANGE UPPER RAMS CLOSE BLIND RAMS -CHANGE 7"RAMS TO 2-7/8"X 5-1/2"VBR 13.00 - 14:00 1.00 BOPSUR P INTI RU TO TEST BOPE -MU SAFETY VALVE ASSY,PU AND MU 2 7/8" TEST JT ASSY, -FILL KILL LINE,STACK,CHOKE LINE,CHOKE MANIFOLD AND MGS 14:00 - 21:00 7.00 BOPSUR P INTI TEST BOPE TO 250 PSI LOW,4000 PSI HIGH I FOR 5 MINUTES EACH -TEST WITH 2-7/8"AND 4-1/2"TEST JOINTS ANNULAR TESTED WITH 2 7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH -TEST 2 7/8"X 5 1/2"VARIABLE RAMS WITH 2 7/8"AND 4.5"TEST JOINT,250 PSI,4000 PSI,5 MIN,CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,4000 PSI,5 I MIN,CHARTED TEST WITH FRESH WATER. NO FAILURES. -ALL TEST CHARTED,SEE ATTACHED BOP TEST CHARTS TEST WITNESS WAIVED BY AOGCC REP CHUCK SHEAVE NOTICE GIVEN TO AOGCC ON 03/06/2014 21:00 - 22:00 1.00 BOPSUR P INTI RD BOPE TEST EQUIPMENT -LD TEST EQUIPMENT,CLEAN AND CLEAR RIG FLOOR RIG UP FOR CASING TEST Printed 7/14/2015 11:42:28AM 7. r, North America ALASKA " ; , _. a ,, :... ;,. ...,, , Operation SummaryReport Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 0911 Rig Name/No.:PARKER 273 1 Spud Date/Time:7/2/1985 12:00:00AM I Rig Release:3/22/2015 Rig Contractor.PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual t 67.05usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations I_ (hr) (usft) 22:00 - 23:00 1.00 CASING P ' INT1 I PRESSURE TEST 7"LINER AND LTP TO 250 PSI LOW FOR 5 MIN/4000 PSI HIGH FOR 30 MIN '-CEMENT IN PLACE AT 00:55 ON 03/09/2015 -9.55 HOURS FOR 500 PSI COMPRESSIVE 1 STRENGTH ACHIEVED AT 10:55 AM ON 03/09/2015 -GOOD 250 PSI LOW TEST WHILE PRESSURING UP TO 4000 PSI THE I PRESSURE LEVELED OFF AT 1500 PSI 1-SHUT DOWN PUMPS AND MONITOR PRESSURE:PRESSURE BLED OFF DOWN TO 1 1 800 PSI j -BLEED OFF PRESSURE:3.6 BBLS i•RETURNED I PUMPED 7.9 BBLS 1 �-CALL ODE AND WTI'TO DISCUSS -DECISION TO M/U AND RIH WITH 7"HES CHAMP PACKER TO TEST LTP AND 7"LINER SEPARATELY TO DETERMINE LEAK PATH 123:00 - 23:30 0.50 CEMT P INTI INSTALL WEAR RING a-INSTALL WEAR RING(WEAR RING ID:12.25) 23:30 - 00:00 0.50 i CEMT P INTI 'RIG SERVICE "-GREASE TOP DRIVE,IDM,ST-80 AND BLOCKS 3/10/2015 00:00 - 02:00 2.00 CEMT P 11,233.00 !NTT C/O SAVER SUB -C/O SAVER SUB FROM 41/2"IF TO 4"XT-39 02:00 - 06:00 4.00 CEMT N. CEMT 11,23&00 j INTI MAKE UP AND RIH WITH HES CHAMP IV PACKER -M/U HES 7"CHAMP IV PACKER WITH 5.94" 1 I MAX OD -RIH WITH 7"PACKER FROM SURFACE'TO 3514'MD I-LINER TOP PACKER AT 3346'MD 1 I-SET HES PACKER BY RIGHT HAND I ROTATION ON UP STROKE AND SET DOWN 20K TO CONFIRM SET I-MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT 06:00 - 06.30 I 0.50 I CEMT N CEMT 11,233.00 ; INTI TEST 7"LINER TO 4000 PSI. -PUMP DOWN DRILL STRING TO TEST 7" LINER -ATTEMPT TO PRESSURE UP TO 4000 PSI HIGH FOR 10 MIN -PRESSURE BUILT TO 2000 PSI AND LEVELED OFF ' I-SHUT DOWN PUMPS AND BLEED OFF I PRESSURE 06:30 - 07:00 0.50 CEMT N CEMT 11,233.00 ' INT1 TEST IA AND LINER TOP PACKER TO 4000 PSI. I CLOSE UPPER VBRS -PUMP THROUGH KILL LINE AND PRESSURE I UP IA TO TEST 7"LINER TOP PACKER -PRESSURE UP TO 4000 PSI HIGH FOR 10 MIN -� 1 I -GOOD TEST Printed 7/14/2015 11:42:28AM 411 North America ALASKA BP Page 29 of 37 Operation Summary Report 1, Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations ', (hr) (usft) ' 07:00 - 13:00 6.00 CLEAN N CEMT 11,233.00 INTI RIH WITH HES CHAMP IV PACKER TO 11,036' MD -ROTATE TO LEFT AND UN-SET PACKER -P/U TO CONFIRM PACKER RELEASED -CONTINUE RIH WITH HES PACKER FROM 3514'TO 11,036'MD I-WASH DOWN LAST TWO STANDS AT 210 GPM,895 PSI -MONITOR TRIP VIA TRIP TANK:WELL TAKING EXTRA 0-0.5 BBL FOR 5 STANDS 13:00 - 16:00 3.00 CEMT N CEMT 11,233.00 INTI TEST 7"LINER TO 4000 PSI. SET HES PACKER AT 11,036'MD BY RIGHT HAND ROTATION ON UP STROKE AND SET DOWN 20K TO CONFIRM SET I-CLOSE UPPER VBRS 1-PUMP DOWN IA THROUGH KILL LINE TO TEST 7"LINER PRESSURE UP TO 250 PSI LOW FOR 5 MIN: GOOD TEST -PRESSURE UP TO 4000 PSI HIGH FOR 30 MIN:GOOD TEST -PRESSURE TEST MEETS ALL BP MIT CRITERIA -APPROVAL TO PROCEDE FROM WTLAND ODE 16:00 - 22:30 6.50 CEMT N CEMT 11,233.00 INTI 'POOH AND UD HES CHAMP PACKER RIH AND TAG LANDING COLLAR ON DEPTH AT 11,146'MD -MONITOR WELL FOR 10 MIN:STATIC -PUMP DRY JOB -POOH WITH HES CHAMP PACKER FROM 11,146'MD TO SURFACE -L/D HES CHAMP 4 PACKER 22:30 - 23:00 0.50 CEMT P INTI FRIG SERVICE -SERVICE TOP DRIVE -INSPECT PS-21 SLIPS -INSTALL MASTER BUSHINGS 23:00 - 00:00 1.00 CEMT I INTI MAKE UP SLB 6.125"MOTOR DRILLING BHA #5 -MAKE UP DRILLING BHA#5 PER SLB -RIH WITH BHA -6.125"SMITH XR20 INSERT BIT,PDM 475 MOTOR WITH 1.50 BEND,6"NM STABILIZER, NM PONY COLLAR,X/O,IMPULSE MWD, SONIC SCOPE LWD(3)FLEX COLLAR, CROSSOVER SUB, -OAL OF BHA =200.41' —I 3/11/2015 00:00 - 01:00 I 1.00 CEMT P INTI IMAKE UP SLB 6.125"MOTOR DRILLING BHA #5 -MAKE UP DRILLING BHA#5 PER SLB RIH WITH BHA I-6.125"SMITH XR20 INSERT BIT,PDM 475 MOTOR WITH 1.50 BEND,6"NM STABILIZER, NM PONY COLLAR,X/O,IMPULSE MWD, SONIC SCOPE LWD(3)FLEX COLLAR, CROSSOVER SUB, I 1 -OAL OF BHA =200.41' Printed 7/14/2015 11:42:28AM 0 North America ALASKA BP "„Page 30 of F, Operation Summary Report Common Well Name 09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date ! From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) j P (usft) 01:00 - 14:30 13.50 CEMT INTI I RIH WITH 6.125"MOTOR DRILLING BHA#5 FROM 200'MD TO 11,146'MD '-RIH ON ELEVATORS WITH 4"DP FROM DERRICK SHALLOW HOLE TEST MWD TOOL AT 1800' MD-PASS -CONTINUE RIH WITH SLB BHA FROM 1800' MD TO 7000'MD -TURN ON PUMPS AND DOWNLINK TO SONICSCOPE LWD TOOL TO TURN ON !MEMORY LOG � ' TIH AND MEMORY LOG WITH SONICSCOPE FROM 7000'MD TO 11,146'MD -WASH DOWN LAST STAND AT 250 GPM,2500 PSI I -TAG LANDING COLLARAT 11,146'MD TtH SPEED MAX 890 FT/HR -FILL PIPE EVER 20 STANDS -MONITOR TRIP VIA TRIP TANK:PROPER ' DISPLACEMENT 14:30 - 16.30 2.00 CEMT i P INTI i DISPLACE 10.2 PPG LSND TO 8.6 PPG 'FLO-PRO MUD -PUMP 30 BBL OF 10.2PPG HI-VIS SPACER PUMP 30 BBLS WATER -DISPLACE WELL TO 8.6 PPG FLO-PRO -VOLUME TRACK BBL IN=BBL OUT -OBTAIN SPR WITH NEW MUD 16:30 - 17.00 0.50 CEMT P I INTI PERFORM NEGATIVE PRESSURE TEST -MONITOR WELL FOR 30 MIN:STATIC -CALL WTL TO DISCUSS:APPROVAL TO PROCEDE WITH OPERATIONS 17:00 - 18:30 1.50CEMT P INTI SLIP AND CUT DRILL LINE SLIP AND CUT 102',12 WRAPS 18:30 - 19:00 0.50 CEMT P INTI RIG SERVICE I -GREASE WASHPIPE AND BX ELEVATORS 1 -CHECK FLUID LEVEL IN TOP DRIVE 19:00 - 19:30 0.50 CEMT P INTI D2 DRILL -CONDUCTED A D2 DRILL WITH RIG CREW ! j-DISCUSSED POTENTIAL FOR U-TUBE WHILE DRILLING SHOE TRACK -DISCUSS GAIN/LOSS ALARM SETTINGS AND FLOW OUT ALARMS I -CREWS DISCUSSED ACTIONS AFTER THE WELL IS SHUT IN WITH RECORDING PRESSURES AND FREQUENCY 19:30 - 23.00 3.50 CEMT P INTI DRILL OUT CEMENT AND 7"SHOE TRACK FROM 11,146'MD TO 11,233'MD I!I ! 1-DRILL FOR 110 MIN AT 11,146'MD TO DRILL UP LANDING COLLAR AND PLUG -230 GPM 1,450 PSI -40 RPM 4-5K TORQUE -P/U 180K,S/O 150K,ROT 160K 23:00 - 00:00 1.00 CEMT P INTI DRILL NEW FORMATION FROM 11,233'MD TO 11,250'MD -DRILL FROM 11,233'MD TO 11,250'MD -230 GPM 1,460 PSI 1 -40 RPM 5-6K TORQUE -WOB INCREASED FROM 1K TO 10K I -NO CEMENT RETURNS -PULL INTO SHOE AND FLOW CHECK WELL: STATIC Printed 7/14/2015 11:42 28AM NO11h,,kFR!TKc AL�4S#« Page 31 Qf 37 • Operation Summary Report , ; Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 I End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site PB DS 09 Rig Name/No.:PARKER 273 ; Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UVN:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ; (usft) 3/12/2015 00:00 - 02:00 2.00 CEMT P INTI DRILL NEW FORMATION FROM 11,250'MD TO 11,260'MD -DRILL FROM 11,250'MD TO 11,260'MD -230 GPM 1,460 PSI -40 RPM 5-6K TORQUE 1-NO CEMENT RETURNS 1-PULL INTO SHOE AND FLOW CHECK WELL: 'STATIC 02:00 - 03:00 1.00 CEMT P INTI CIRCULATE BOTTOMS UP -PULL BACKTO 7"SHOE -250 GPM,1360 PSI,20 RPM 03'00 - 03:30 0.50 CEMT P INTI RIG UP AND PERFORM FIT -MUD WEIGHT:8.6 PPG,8597'TVD,11,233' MD PUMP TO 872 PSI -FIT EMW:10.55 PPG RECEIVE ODE APPROVAL TO CONTINUE -SEE ATTACHED CHART -BLEED DOWN TEST EQUIPMENT 03:30 - 18:00 14.50 DRILL I P fi PROD1 DRILL 6.125'PRODUCTION HOLE FROM 11,260'MD TO 11,515'MD 1-2'40 GPM,1546 PSI ON,1490 PSI OFF 40 RPM,6-10K TORQUE ON,6-10K TORQUE OFF -10-20K WOB -ROP 20-40 FT/HR -PU 183K,SO 151K AT 11,260'MD -SURVEY EVERY-30 FT -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -INCREASE LUBE CONCENTRATIONS FROM 1%TO1.5%AT11,348'MD -INCREASE LUBE CONCENTRATIONS FROM 1.5%TO 2.0%AT 11,475'MD i-TROUBLE TRANSFERING BIT WEIGHT FOR SLIDE:DISCUSS WITH ODE AND DECISION TO PUMP A 20 BBL STEEL LUBE PILL 18:00 - 19:30 1.50 DRILL P PROD1 CIRCULATE STEEL LUBE PILL -240 GPM,1520 PSI -40 RPM,6-14K TORQUE -TORQUE REDUCED TO 6K WHILE STEEL LUBE TRAVELED UP ANNULUS 19:30 - 00:00 4.50 DRILL P PROD1 DRILL 6.125"PRODUCTION HOLE FROM 11,515'MD TO 11,590'MD -240 GPM,1600 PSI ON,1520 PSI OFF 40 RPM,7K TORQUE ON 10-20K WOB -ROP 10-40 FT/HR -PU 200K,SO 150K,ROT 161K -SURVEY EVERY-30 FT -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT LAST 24 HOURS -ACTUAL ROTATE TIME=1.43 HRS -ACTUAL SLIDE TIME=7.72 HRS Printed 7/14/2015 11:42.28AM • North Amenca ALASKA BP •40%;40t, Page 32©f 37 Operation Summary Report Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM 11Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/13/2015 00:00 - 08:00 8.00 DRILL P PROD1 1DRILL 6.125'PRODUCTION HOLE FROM 111,590'MD TO 11,741'MD(8,891'TVD) -240 GPM,1540 PSI ON,1495 PSI OFF -40 RPM,6K TORQUE ON,6K TORQUE OFF P/U 197K,S/O 142K -10-20K WOB -ROP 10-40 FT/HR -SURVEY EVERY-30 FT -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -INCREASE LUBE CONCENTRATIONS FROM 12.0%TO 3.0%BY 11,657'MD -SLIDES IMPROVED ONCE PAST 11,620'MD 08:00 - 09:00 1.00 DRILL P PROD1 BACKREAM FROM 11,741'MD TO 11,187'MD BACKREAM TO THE 7"SHOE DUE TO LOW ROP AND DIFFICULTY GETTING WEIGHT TRANSFER -240 GPM,1485 PSI -40 RPM,6-8K TORQUE -BACKREAM AT 1500 FT/HR -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT j MONITOR WELL FOR 10 MINUTES AT SHOE: WELL STATIC 09:00 - 10:00 1.00 DRILL P PROD1 CIRCULATE STEEL LUBE PILL -240 GPM,1520 PSI -40 RPM,6-12 TORQUE 10:00 - 11 00 1.00 DRILL P , PROD1 RUN IN HOLE WITH 6-1/8"PRODUCTION BHA -RIH ON ELEVATORS FROM 11,187'MD TO 11,741'MD -CIRCULATE IN NUT PLUG PILL -CIRCULATE IN ALPINE GLASS BEADS 1100 16.30 5.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 11,741'MD TO 11,812'MD(8,899'TVD) -240 GPM,1700 PSI ON,1620 PSI OFF -40 RPM,6-8K TORQUE ON,4K TORQUE OFF -P/U 195,S/O 151K,ROT 164K -10-20K WOB -ROP 10 FT/HR -SURVEY EVERY-30 FT -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -CIRCULATE IN NUT PLUG AND ALPINE 1 GLASS BEADS NO OBSERVED CHANGES WHILE SLIDING LAST 24 HOURS -ACTUAL ROTATE TIME=0.03 HRS -ACTUAL SLIDE TIME=6.61 HRS 16:30 - 23:30 7.00 DRILL P PROD1 PULL OUT OF HOLE WITH SLB MOTOR BHA#5 FROM 11,812'MD TO 5,405'MD TO P/U RSS BHA 1 1-MONITOR WELL FOR 10 MIN:STATIC -POOH ON ELEVATORS -STAND 4"DP IN DERRICK -P/U 199K,S/O 138KAT 11,811'MD -MONITOR WELL FOR 10 MIN AT 7"SHOE: STATIC -MUD WEIGHT IN&OUT=8.6 PPG NO TIGHT SPOTS ENCOUNTERED IN IOPENHOLE -PULLED 5 STANDS AND TRIP WAS OFF 1.5 BBLS -FLOW CHECK WELL:STATIC Printed 7/14/2015 11:42.28AM Nerth America ALS BP Page 33 of 37 is Operation Summary Report` Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 DRILL P PROD1 CIRCULATE BOTTOMS UP AT 5,405'MD -245 GPM,1365 PSI -20 RPM,1K TORQUE -HOLE UNLOADED GROUND CUTTINGS,NUT PLUG,AND GLASS BEADS *SIMOPS -LUBRICATE RIG -GREASE ST-80,TOP DRIVE,BLOCKS,IDM, PS-21 3/14/2015 00:00 - 01:00 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP AT 5,405'MD -245 GPM,1365 PSI -20 RPM,'1K TORQUE HOLE UNLOADED GROUND CUTTINGS,NUT PLUG,AND GLASS BEADS, 01:00 - 04:30 3.50 DRILL j P PROD1 PULL OUT OF HOLE WITH SLB MOTOR BHA#5 FROM 5,405 MD TO 200'MD TO CHANGE BHA -MONITOR WELL FOR 10 MIN:STATIC -POOH ON ELEVATORS -STAND 4"DP IN DERRICK MONITOR TRIP VIA TRIP TANK PROPER DISPLACEMENT J-MUD WEIGHT IN&OUT=8.6 PPG 04:30 - 05:00 0.50- , DRILL ' P PROD1 1FUNCTION TEST BOPS AS PER AOGCC 7 DAY REQUIREMENT 05:00 - 06:00 1.00 DRILL P PROD1 LAY DOWN SLB MOTOR BHA#5 -MONITOR WELL 10 MIN PRIOR TO PULLING BHA THRU STACK:WELL IS STATIC -LAY DOWN 6.125"DRILLING BHA#5 PER SLB DD I-RACK BACK FLEX COLLARS,HWDP,AND JARS FUNCTION TEST BLINDS ONCE OUT OF HOLE BIT GRADE:2-3-WT-A-E-I-BT-PR 06.00 - 08:00 2.00 DRILL P PROD1 PICK UP SLB 6.125"X6 RSS DRILLING BHA#6 -MAKE UP DRILLING BHA#6 PER SLB I-LOAD SOURCE PER MWD RIH WITH BHA -6.125 PDC BIT,4-3/4"X6 RSS,PD E-MAG RECEIVER,PD XO SUB,IMPULSE MWD, ADNVISION 475,(3)FLEX COLLAR, CROSSOVER SUB -OAL OF BHA =174.76' 08:00 - 16:00 8.00 DRILL P PROD1 ,RIH WITH SLB X6 6.125"DRILLING BHA#6 FROM 175'MD TO 11,812'MD RIH ON ELEVATORS WITH 4"DP FROM DERRICK -BREAK CIRCULATION EVERY 20 STANDS -RIH AND SHALLOW HOLE TEST MWD TOOL AT 1592'MD-PASS RIH FROM 1592'MD TO 11,812'MD I-OBTAIN SPRS WITH NEW BHA I-MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT Printed 7/14/2015 11:42.28AM North America-ALASKA-BP . ;age Page 34 of 37 •-• , /,'„/ ';47; 41 p Ast...AAAVAA,AAAA),....A./AAA.:A., AA:4 A AiA yAAAAAAAAA.;AAA;A,AAAAAA.f„A4 - ''4""e;-AA''''",AAAACA';`,YAAf""OAPAAAA,",'!"0./AVIA:,A.A`AgnA %AA'" A " "A' "7"." A A.AAAA'A AAVAAAAAA,A,,An,:;AA"AAMAIAAWA` :A/A.A....A/AAA.AAA.AA.A.,A&A,AAAAN.A,AFArtAAAA2A,AA,. ic,,AfA0AAA.A.Ancu;/A4A0,,lA.k,,,,AVA.,,,,,AmA owt i,4);,S,0,4f610'1%,;;c4SAIA$VN•44,SV.0104',4/0„,,' Operation Summary Report :4%,i;',:?:;,.0;05:04g*Ve6/::MPE4,,t4gAN*„„:149,),„?.;:, Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date 2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:0000AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31D actual©67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 00:00 8.00 DRILL P PROD1 DRILL 6.125"PRODUCTION HOLE FROM 11,812'MD TO 12,200'MD(8,880'TVD) -260 GPM,2000 PSI 90 RPM,8K TORQUE ON,7K TORQUE OFF P/U 189K,S/O 145K,ROT 161K -5-10K WOB -ROP 120-140 FT/HR -SURVEY EVERY-30 FT -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -ACTUAL ROTATE TIME=4.82 HRS 3/15/2015 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6.125°PRODUCTION HOLE FROM 12,200MD TO*13,245'MD(8872 TVD) 260 GPM,2005 PSI -110 RPM,10K TORQUE ON,8K TORQUE OFF -P/U 196K,S/0 142K,ROT 159K -5-10K WOB ROP 110-130 FT/HR 1-SURVEY EVERY-30-90 FT -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -PUMP LOW VIS-HI VIS SWEEP AT 13,078' MD:5-10%INCREASE IN RETURNS WITH SWEEP AT SURFACE -ACTUAL ROTATE TIME=8.59 HRS 12 00 - 00-00 12.00 DRILL P PROD1 DRILL 6.125"PRODUCTION HOLE FROM 13,245'MD TO 14,478'MD(8872 TVD) -250 GPM,2060 PSI -110 RPM,10K TORQUE ON,8K TORQUE OFF -P/U 205K,S/O 136K,ROT 160K -5-10K WOB ROP 110-130 FT/HR -SURVEY EVERY 90 FT -MUD WEIGHT:8.7 PPG IN,8.8 PPG OUT -ACTUAL ROTATE TIME=9.45 HRS 3/16/2015 00:00 - 14:30 14.50 DRILL P PROD1 DRILL 6.125"PRODUCTION HOLE FROM 14,478'MD TO 15,855'MD -PRODUCTION SECTION TD AT 15,855'MD• 1-250 GPM,2150 PSI -110 RPM,10K TORQUE ON,8K TORQUE OFF -P/U 210K,S/O 132K,ROT 158K -5-10K WOB -ROP 110-130 FT/HR -SURVEY EVERY 90 FT -MUD WEIGHT:8.7 PPG IN.8.8 PPG OUT -CROSSED FAULT#1 AT 14,525'MD -WOB INCREASE FROM 5K TO 10K AT 14,525' 1MD 1-INCREASE IN DYNAMIC LOSS RATE FROM 1 BBL/HR TO 18 BBUHR -DYNAMIC LOSS RATE STABILIZED AT 10 BBL/HR -INCREASE IN DYNAMIC LOSS RATE FROM 10 BBL/HR TO 45 BBL/HR AT 15,055'MD DYNAMIC LOSS RATE STABILIZED AT 20-25 BBL/HR -PUMPED DRILL AHEAD PILL AT 15.330'MD -BROUGH BACK 10%INCREASE IN 1CUTTINGS -DYNAMIC LOSS RATE 20-25 BBL/HR Printed 7/14/2015 11 42:28AM North America ALASKA BP Page 35 of 37 y Operation Summary Report Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 14:30 - 18:00 3.50 DRILL P PROD1 CIRCULATE BOTTOMS UP 3 TIMES -260 GPM,2300 PSI 140 RPM,11K TORQUE RECIPROCATE PIPE 60' I-PUMP 40 BBLS 35 PPB LCM FOR FIRST BOTTOMS UP -LOSS RATE 25 BBL/HR 18:00 - 21:30 3.50 DRILL P PRODS '-;`POOH WITH 6.125"DRILLING BHA FOR SHORT TRIP FROM TD AT 15,855'MD TO 11,800'MD MONITOR WELL FOR 10 MINUTES:WELL 1 LOSSING 5 BBL/HR STAIC LOSS RATE -MUD WEIGHT 8.8 PPG IN,8.8 PPG OUT -P/U 205K S/O 138K AT 15,855'MD -POOH ON ELEVATORS FROM 15,855 MD TO 11,800'MD MONITOR WELL VIATRIP TANK:WELL TAKING EXTRA 1.5-2 BBLS PER 5 STANDS -TIGHT SPOT AT 15,454'MD COULD NOT I WORK THROUGH WITH 30-40K OVERPULL RUN STAND TO BOTTOM AND PUMP STAND OUT AT 260 GPM,1980 PSI WITH NO ROTATION CHECK STAND ON ELEVATORS,TIGHT SPOT tREMOVED -TIGHT SPOT AT 14,770 TAKING 30K TO WIPE THROUGH -TIGHT SPOT 14000-13965'MD TAKING 30K. RUN STAND TO BOTTOM.TIGHT SPOT REMOVED 21 30 - 00:00 2.50 DRILL P PROD1 MAD PASS LOG FROM 11,800'MD TO 11,445' MD -LOG AT 250'/HR AS PER SLB MWD -260 GPM,1830 PSI -LOG FROM 11,800'-11,500'MD 0 RPM AS PER DOG LEG ROTATION LIMITATIONS LOG FROM 11,500'-11,350'MD 80 RPM,6K TORQUE 3/17/2015 00:00 - 01:00 1.00 DRILL P PROD1 MAD PASS LOG FROM 11,450'MD TO 11,350" MD LOG AT 250'/HR AS PER SLB MWD 260 GPM,1830 PSI -LOG FROM 11,800'-11,500'MD O RPM AS PER DOG LEG ROTATION LIMITATIONS I-LOG FROM 11,500'-11,350'MD 100 RPM,8K TORQUE 02:00 1.00 DRILL P PROD1 -PULL UP INTO SHOE AT 11,233'MD 01:00 i CIRCULATE BOTTOMS UP -PULL INTO T SHOE AT 11,233'MD -260 GPM,1730 PSI -120 RPM,7K TORQUE �-RECIPROCATE 60' MONITOR WELL FOR 10 MINUTES:2-4 BBL/HR LOSS RATE -DYNAMIC LOSS RATE 8 BBL/HR Printed 7/14/2015 11:42:28AM '';':'„ .'*,./': ,1,;'„,„, , , 0 „ North encs Page 36 of 37 operation Summary Report` Common Well Name:09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31D actual r©67.05usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 05:00 3.00 DRILL P ' PROD1 RUN IN HOLE WITH 6-1/8"DRILLING BHA#6 I FROM 11,233'MD TO 15,855'MD '-RUN IN HOLE ON ELEVATORS WITH 4"DRILL PIPE STANDS 1 -P/U 180K S/O 135KAT 11,233'MD i-BREAK CIRCULATION EVERY 20 STANDS, 2$0 GPM,1650 PSI 1 ,--MUD WEIGHT 8.8 PPG IN,8.8 PPG OUT -MONITOR WELL VIA TRIP TANK WELL TAKING EXTRA 2 BBLS PER 5 STANDS -TIGHT SPOT AT 11,895'MD TAKING 15K, WIPED CLEAN -TIGHT SPOT AT 14,880'MD TAKING 15K, 1 WIPED CLEAN 05:00 - 08:00 3.00 DRILL P PROD1 CIRCULATE 2X BOTTOMS UP AT TD -250 GPM,2300 PSI I I-135 RPM,7K TORQUE 1-RECIPROCATE 90' -AVERAGE LOSS RATE 10 BBL/HR 08:00 - 11:30 3.50 DRILL P I PROD1 PULL OUT OF HOLE FROM 15,855'MD TO 11,350'MD -MONITOR WELL FOR 10 MINUTES:5-6 j BBL/HR LOSS RATE '-PULL OUT OF HOLE ON ELEVATORS I RACKING BACK 4"DP -P/U 210K,S/O 134KAT 15,800'MD MAD PASS AT 250 FT/MIN FROM 11,345'MD TO 111,285'MD -P/U 195K,S/O 140K -260 GPM,1910 PSI -80 RPM,6K TORQUE MUD WEIGHT 8.8 PPG IN,8.8 PPG OUT 11:30 - 12:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP AT 7"SHOE -260 GPM,1900 PSI 1-135 RPM,6K TORQUE I I-RECIPROCATE PIPE 80' 1 -MONITOR WELL FOR 10 MINUTES:5 BBL/HR STATIC LOSS RATE -DROP 2.33"DIAMETER RABBIT AT 11,233'MD 12:30 17:00 4.50 DRILL P PROD1 'PULL OUT OF HOLE FROM 11,233'MD TO I I 1 3,340'MD i -MONITOR WELL FOR 10 MINUTES:5 BBL/HR (LOSS RATE PULL OUT OF HOLE ON ELEVATORS 1 RACKING BACK 4"DP -P/U 180K,S/O 150KAT 11,200'MD -LAYDOWN 4"HWDP AND JARS FROM 4,845' MD TO 4,545'MD 17:00 - 18:30 1.50 DRILL P PROD1 CIRCULATE BOTTOMS UP AT 7"LINER TOP 1 I -260 GPM,1300 PSI I-100 RPM,2K TORQUE 18:30 20:00 1.50 DRILL PPROD1 PULL OUT OF HOLE FROM 3,340'MD TO 200' 1 1 MD -PULL OUT OF HOLE ON ELEVATORS RACKING BACK 4"DP -PU 80K,SO 75K Printed 7/14/2015 11.42:28AM • N9rthAmerica ALASKA BP Page 37 of 37 // .,... • Operation Summary Report ss Common Well Name.09-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/19/2015 End Date:3/18/2015 X3-013XD-C:(10,093,450.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 21:30 1.50 DRILL [ P 1 PROD1 I LAY DOWN DRILLING BHA#6 I-PJSM WITH SLB DD/MWD -MONITOR WELL 10 MIN PRIOR TO PULLING BHATHRU STACK:WELL IS STATIC -LAY DOWN 6.125"DRILLING BHA#6 PER SLB DD -RACK BACK FLEX COLLARS,HWDP,AND [FLEX COLLARS BIT GRADE:1-1-BT-T-X-I-ER-TD 21:30 - 22:00 0.50 DRILL P PROD1 RIG SERVICE -SERVICE RIG FLOOR EQUIPEMENT PERFORM DERRICK INSPECTION- 22:00 - 00:00 2.00 DRILL N CEMT PROD1 RIG UP E-UNE -PJSM WITH SLB E-LINE CREW BRING WIRELINE SHEAVES TO RIG FLOOR VIA TOOL CRANE -LOAD SLB USIT TOOL INTO PIPE SHED RIG UP SHEAVES 3/18/2015 00'00 - 08 30 8.50 DRILL N CEMT PROD1 RUN CEMENT BOND LOG ON E-LINE RIH WITH CCL-GR-MSIP-USIT -LOG FROM 7"SHOE TO TOP OF CEMENT ,-MAKE REPEAT PASS FROM 9,600'MD TO 8,600'MD -NO PRESSURE CONTROL EQUIPMENT REQUIRED PER SOP AND WTLAPPROVAL -AIR LINE WIPER AND HYDRAULIC CUTTER AT SURFACE 08.30 - 11:00 2.50 DRILL N CEMT PROD1 PJSM RIG DOWN E-LINE -DRAIN STACK BREAK DOWN E-LINE USIT ASSEMBLY -LAY DOWN TOOLS IN PIPE SHED AND LOAD ON SLB TRUCK -RIG DOWN E-LINE TRUCKS AND MOVE TO EDGE OF PAD j**END RON EVENT 3/18/2014 AT 1100 HRS. I SWITCH TO CON EVENT 3/18/2014** Printed 7/14/2015 11:42:28AM • • North America-ALASKA BP Page 1 of 8 Operation Summary Report. t, >�.r„/ Common Well Name:09-31 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/18/2015 1 End Date:3/22/2015 X3-013XD-C:(4,052,073.00) Project Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-310 actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/18/2015 11:00 - 12:00 1.00 CASING P RUNPRD **END RON EVENT 3/18/2014 AT 1100 HRS. SWITCH TO CON EVENT 3/18/2014** RIG UP TO RUN 4-1/2”LINER RIG UP DOUBLE STACK TONGS -CHANGE OUT PS-21 SLIP INSERTS -CHANGE OUT BX ELEVATOR INSERTS TO 4-1/2"DIAMETER,VERIFY OD WITH CALIPER 12:00 - 12:30 0.50 CASING P RUNPRD SERVICE RIG -LUBRICATE RIG FLOOR EQUIPMENT 12:30 - 19:00 6.50 CASING P RUNPRD RUN 4-1/2",12.6#,13CR,VT LINER FROM SURFACE TO 4,765'MD PJSM WITH DOYON CASING CHECK FLOATS:HOLDING -USE JET LUBE SEAL GUARD ON CONNECTIONS -TORQUE TURN CONNECTIONS TO 4,440 FT-LBS -2 CENTRALIZERS LOCKED DOWN ON JOINTS 1 AND 2 -2 CENTRLAIZERS FREE FLOATING ON JOINTS 3-110 FILL LINER ON THE FLY -TOP OFF EVERY EVERY 10 JOINTS -P/U 90K,S/O 93K 19:00 - 20:00 1.00 CASING P RUNPRD MAKE UP LINER HANGER ASSEMBLY PJSM WITH BAKER REP -CHANGE OUT PS-21 SLIP INSERTS I I ,-CHANGE OUT BX ELEVATOR INSERTS TO 4" DIAMETER,VERIFY OD WITH CALIPER -ADD PAL MIX 20:00 - 20:30 0.50 CASING P RUNPRD CIRCULATE 1.5X LINER VOLUME -STAGE PUMPS UP TO 7 BPM,340 PSI **SIMOPS:RIG DOWN CASING RUNNING TOOLS** 20:30 - 00:00 3.50 CASING P RUNPRD RUN IN HOLE WITH LINER HANGER ASSEMBLY FROM 4,920'MD TO 9,100'MD -RUN IN HOLE ON ELEVATORS AT 90 FT/MIN WITH 4"DP FROM DERRICK FILL LINER ON THE FLY -TOP OFF EVERY 10 JOINTS -FILL PIPE EVERY 10 STANDS -P/U 140K,S/O 126K 3/19/2015 00:00 - 02:00 2.00 CASING P RUNPRD RUN IN HOLE WITH LINER HANGER ASSEMBLY FROM 9,100'MD TO 11,183'MD I-RUN IN HOLE ON ELEVATORS AT 90 FT/MIN WITH 4"DP FROM DERRICK FILL PIPE EVERY 10 STANDS -P/U 140K,S/O 126K _ 02 00 - 03:00 1.00 CASING P RUNPRD CIRCULATE 1.5X LINER+DRILL PIPE VOLUME -STAGE PUMPS UP TO 7 BPM,930 PSI 03.00 - 06:00 3.00 CASING P RUNPRD RUN IN HOLE WITH LINER HANGER ASSEMBLY FROM 11,183 MD TO 15,830'MD RUN IN HOLE ON ELEVATORS AT 90 FT/MIN WITH 4"DP FROM DERRICK 1-FILL PIPE EVERY 10 STANDS -P/U 199K,S/O 135K Printed 7/14/2015 11.42.56AM North Arr e•". -ALASKA-BP • E ale 2 a€6 Operation Summary Report F .:,L Common Well Name:09-31 AFE No Event Type COM-ONSHORE(CON) Start Date.3/18/2015 End Date:3/22/2015 X3-013XD-C:(4,052,073.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum.09-31 D actual tLD67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (usft) 06:00 09:30 3.50 CASING P RUNPRD STAGE PUMPS UP TO FULL CEMENTING RATE -STAGE PUMPS UP IN 0.5 BBUMIN INCREMENTS UP TO 5 BBL/MIN -1BPM,830 PSI,1%RETURN FLOW -1.5 BPM,930 PSI,2%RETURN FLOW -2 BPM,1015 PSI,5"RETURN FLOW 2.5 BPM,1035 PSI,7%RETURN FLOW 3 BPM,1140 PSI,9%RETURN FLOW h.4 BPM,1055 PSI,10%RETURN FLOW -5 BPM,1260 PSI,12%RETURN FLOW I-INITIAL CEMENTING RATE:1260 PSI -FINAL PRESSURE AT CEMENTING RATE: 1450 PSI CIRCULATE TOTAL 1.5X BOTTOMS UP RECIPROCATE PIPE 20 FT AT SURFACE AT 400-600 FT/HR 09:30 12:00 2.50 CEMT P 1 RUNPRD CEMENT 4-1/2"PRODUCTION LINER -RIGGED UP WITH TWO HOSE SYSTEM FOR CEMENT JOB FILL LINES WITH 5 BBL WATER AND PRESSURE TEST 300 PSI LOW AND 4500 PSI HIGH FOR 5 MINUTES EACH PUMP 54 BBL OF 10 PPG MUDPUSH II SPACER AT 5 BPM,1200 PSI -PUMP 118 BBL OF 15.8 PPG CLASS G TAIL AT 5 BPM -RECIPROCATE PIPE 20 FT AT SURFACE WHILE PUMPING CEMENT -COME DOWN ON PUMPS AND LINE UP TO WASH WITH PERF PILL THROUGH TWO HOSE SYSTEM I-DROP DRILL PIPE WIPER DART I-TIME TO TAKE TO WASH UP LINES AND TO RELASE DART:4 MIN 30 SEC -DISPLACE WITH 83 BBLOF 8.6 PPG PERF PILL FOLLOWED BY 102.9 BBL OF 8.6 POWER PRO USING SLB PUMPS LATCH UP CONFIMED AT 115 BBL I DISPLACED REDUCE RATE TO 2 BPM PRIOR TO BUMPING THE PLUG:FINAL CIRULATING PRESSURE 1787 PSI I-BUMP PLUG AT 185.9 BBLS PUMPED AND 3,971 PSI -RECIPROCATE PIPE 20 FT AT SURFACE I DURING DIPSLACEMENT -TOTAL LOSSES ON CEMENT JOB:30.6 BBL I-LOSSES FROM TIME CEMENT EXITS SHOE TO TIME CEMENT IS IN PLACE:2.1 BBL Printed 7/14/2015 11:42:56AM North America ALASKA BP 7:111/ : Page 3 of 8 Operation Summary Report Common Well Name 09-31 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/18/2015 End Date:3/22/2015 X3-013XD-C:(4,052,073.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. l UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code ! NPT NPT Depth Phase I Description of Operations (hr) (usft) 12:00 - 13:00 1.00 CASING P RUNPRD SET BAKER FLEX-LOCK HANGER AND ZXP LINER TOP PACKER -INCREASE PRESSURE TO 3500 PSI TO SET HANGER AFTER PLUG BUMP -SET DOWN 70K TO CONFIRM HANGER SET -BLEED OFF PRESSURE AND CONFIRM FLOATS ARE HOLDING L PRESSURE UP TO 4500 PSI TO RELEASE 1 RUNNING TOOL '-P/U TO EXPOSE DOG SUB AND SET DOWN ON LINER TOP 30K TO SET LINER TOP 1PACKER I-BLOW DOWN AND RIG DOWN HOSES G LINE UP TO CIRCULATE THROUGH THE TOP DRIVE FINAL LINER SET DEPTH=15,853'MD LINER TOP AT 11,133'MD 13:00 - 14:30 1.50 CASING P RUNPRD CIRCULATE OUT EXCESS CEMENT -CIRCULATE EXCESS CEMENT OFF LINER TOP P/U RUNNING TOOL ABOVE LINER TOP AND MARK NO-GO.CIRCULATE 2 BU -PUMP AT 16 BPM,3000 PSI --30 BBLS OF EXCESS CEMENT TO SURFACE ON BOTTOMS UP -L/D CEMENT HEAD AND 2 JOINTS OF 4" DRILL PIPE -CIRCULATE BOTTOMS UP 2 TIMES AT 16 BPM,2770 PSI -RECIPROCATE PIPE 60' -MUD WEIGHT IN 8.8 PPG,MUD WEIGHT OUT 8.8 PPG LOSSES FOR DAY=41 BBLS 14:30 - 16:00 1.50 CASING P RUNPRD DISPLACE 8.8 PPG FLO PRO WITH 8.5 PPG SEAWATER -16 BPM,3000 PSI -PUMPED HI-VIS SEAWATER SWEEP I FOLLOWED BY 8.5 PPG SEAWATER -NO ROTATION RPM,RECIPROCATE PIPE 60 IFT !-CLEAN SHAKER BEDS AND TROUGHS 16:00 - 16:301 0.50 CASING P RUNPRD RIG SERVICE -LUBRICATE RIG -SERVICE RIG FLOOR EQUIPMENT -SERVICE TOP DRIVE 16 30 - 00:00 7.50 CASING P RUNPRD POOH WITH LINER RUNNING TOOL -MONITOR WELL FOR 10 MINUTES:STATIC I-POOH WITH LRT ON 4"DRILL PIPE FROM I 11,115'MD TO 3,091'MD LAY DOWN 4"DP I X I IN PIPE SHED MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT PU 170K,SO 145KAT 11,115'MD -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT Printed 7/14/2015 11:42:56AM IIII North America ALASKA-RP' ` f, Operation Summary Report Common Well Name.09-31 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/18/2015 End Date:3/22/2015 X3-013XD-C.(4,052.073.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12.00.00AM Rig Release.3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual r©D67.05usft(above Mean Sea Level) Date 1 From-To Firs Task Code NPT ! NPT Depth Phase Description of Operations (hr) (usft) 3/20/2015 00:00 - 02:30 2.50 CASING P RUNPRD POH WITH LINER RUNNING TOOL POOH WITH LRT ON 4"DRILL PIPE FROM 13,091'MD TO SURFACE 1-LAY DOWN 4"DP 1 X 1 IN PIPE SHED MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 02:30 - 03:30 1.00 CASING P • RUNPRD PJSM LAYDOWN BAKER LINER RUNNING TOOLS. -MONITOR WELL 10 MINS PRIOR TO 1PULLING TOOL THROUGH STACK -BREAK APART AND UD LINER RUNNING TOOLS PER BAKER REP CONFRIM DOG SUB SHEARED NOTICED FILM OF CEMENT STRUNG OUT ACROSS-35-40%OF SLICK STICK AND DOG SUB 03:30 - 06:00 2.50 CASING P RUNPRD PJSM TO RUN IN HOLE WITH 4"DP FROM DERRICK FROM SURFACE TO 4,364'MD REMOVE MANUAL ELEVATORS AND INSTALL BX ELEVATORS RUN IN HOLE AND L/D DP WHILE WAITING ON CEMENT TO SET UP FOR PRESSURE TEST -MAKE UP MULE SHOE ON BOTTOM OF FIRST STAND OF DP -RIH WITH DP FROM DERRICK -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 06:00 - 09:30 3.50 CASING P RUNPRD PULL OUT OF HOLE WITH 4"DRILL PIPE l-REMOVE BX ELEVATORS AND INSTALL MANUAL ELEVATORS -LAYDOWN 4"DRILL PIPE SINGLES FROM 4,364'MD TO SURFACE -PU 92K,SO 85K -MONITOR WELL VIA TRIP TANK PROPER DISPLACEMENT 09:30 - 11:00 1.50 CASING P RUNPRD PRESSURE TEST4-1/2"LINER AND LINER TOP PACKER LINE UP ON KILL LINE -CLOSE BLIND RAMS -PRESSURE TEST TO 250 PSI LOW FOR 5 MINUTES AND 4000 PSI HIGH FOR 30 MIN -PUMP 9 BBL,BLEED BACK 9 BBL -CHART TEST:PASSING -MAKE NOTIFICATIONS AND RECEIVE PERMISSION TO MOVE AHEAD SEE ATTACHED DOCUMENTATION 11:00 - 12:30 1.50 RUNCOM P RUNCMP RIG TO RUN 4-1/2"VAMTOP TUBING -BRING TORQUE TURN EQUIPMENT TO RIG FLOOR -REMOVE BX ELEVATORS AND INSTALL YC ELEVATORS,CONFIRM INSERT OD WTH CALIPERS I-RIG UP TORQUE TURN EQUIPMENT -PULL WEAR RING Printed 7/14/2015 11 42:56AM • North America-ALASKA Operation Summary Report Common Well Name 09-31 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/18/2015 End Date:3/22/2015 1X3-013XD-C:(4,052,073.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual©67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 13:00 0.50 RUNCOM P RUNCMP RIG SERVICE -LUBRICATE RIG 1-SERVICE RIG FLOOR EQUIPMENT SERVICE TOP DRIVE 13:00 - 14:00 1.00 RUNCOM N WAIT RUNCMP BRING BACKUP TONGS TO RIG FLOOR -INCORRECT SIZE INSERTS IN TONGS -PJSM RUN 4-1/2"COMPLETION WITH DOYON AND HES 14:00 - 15:00 1.00 RUNCOM P RUNCMP RUN 4-1/2"COMPLETION WITH DOYON AND HES -PICK UP WLEG,XN NIPPLE WITH RHC-M PLUG,AND FULL JOINT,X-NIPPLE, AND 7"X 4-1/2"HES TNT PACKER TO ' X-NIPPLE BAKER LOCK CONNECTIONS BELOW PACKER 15:00 - 00:00 9.00 RUNCOM P RUNCMP RUN IN HOLE WITH COMPLETION FROM 170' MD TO 5,500'MD -RIH WITH 4-1/2"12.6#13CR-85 VAM TOP TUBING PICK UP SINGLES FROM PIPE SHED MAKE UP WITH TORQUE TURN TO 4,440 FT/LBS -USE JET LUBE SEAL GUARD ON VAM TOP THREADS -MONITOR TRIP VIA TRIP TANK PROPER I DISPLACEMENT 3/21/2015 00:00 - 06:00 6.00 RUNCOM P RUNCMP RUN IN HOLE WITH COMPLETION FROM 6,500'MD TO 11,090'MD RIH WITH 4-1/2"12.6#13CR-85 VAM TOP TUBING PICK UP SINGLES FROM PIPE SHED -MAKE UP WITH TORQUE TURN TO 4,440 FT/LBS -USE JET LUBE SEAL GUARD ON VAM TOP THREADS 1-MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT RUN IN HOLE AT 90 FT/MIN PER HALLIBURTON REP I � -REPLACE 4 JOINTS AND COLLARS DUE TO GALLED THREADS DURING MAKEUP _ 06:00 - 08:00 2.00 RUNCOM P RUNCMP SPACE OUT 4-1/2",12.6#,VAMTOP COMPLETION ASSEMBLY -P/U JT 264 AND BOTTOM OUT ON NO-GO INSIDE TIE BACK RECEPTACLE LAYDOWN JOINTS 264,263,AND 262 MAKE UP 5.82'AND 19.73'PUP,JOINT 262& II HANGER/PUP(CAMERON 13"NOM X 4.5"TCII TOP AND VT BOTTOM THREADS) 1-STOP 12'MD ABOVE LANDING HANGER TO CIRCULATE FREEZE PROTECT -RUN(1)WLEG,(1)XN NIPPLE,(3)X NIPPLES,(1)TNT PACKER,(1)5.82"PUP JOINT,(1)19.73'PP JOINT AND(262)JOINTS VAMTOP TUBING Printed 7/14/2015 11.42:56AM 41, NrthA rica ALASKA BP • Pate 6 of 8 Operation Summary Report Common Well Name.09-31 1 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/18/2015 End Date:3/22/2015 IX3-013XD-C:(4,052,073.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 I Spud Date/Time:7/2/1985 12:00:00AM Rig Release 3/22/2015 Rig Contractor PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 13:00 5.00 RUNCOM P RUNCMP FREEZE PROTECT WELLBORE -CLOSE ANNULAR BAG -LINE UP TO REVERSE CIRCULATE WELLBORE -REVERSE CIRCULATE 171 BBL SEAWATER HEATED TO 120 DEGREES -FOLLOW WITH 205 BBL CORROSION INHIBITOR -CHASE WITH 151 BBL DIESEL -LINE UP TO ALLOW DIESEL IA TO U-TUBE INTO,TUBING -ALLOW DIESEL TO U-TUBE FOR 1 HOUR 13:00 - 15:00 2.00 RUNCOM P RUNCMP LAND 4-1/2",12.6#,VAMTOP COMPLETION ASSEMBLY -RUN IN HOLE ON TCII LANDING JOINT AND LAND STRING ON TUBING HANGER AT 11,136' MD,6'ABOVE NO-GO,AND 5'INSIDE TIE-BACK RECEPTACLE CAMERON.REPS RUN IN LOCKDOWN SCREWS -LOCK DOWN SCREW BACKED OUT LENGTH: 5-1/2" LOCKDOWN SCREW RUN IN LENGTH:3-1/2" -LDS TORQUE:450 FT-LBS,GLANDS:500 FT-LBS -PARKER 273 RKB TO UPPER LOCKDOWN SCREWS=42.55'MD -FINAL PICKUP WEIGHT=139 KLBS, SLACKOFF=118 KLBS,PARKER 273 BLOCKS =35 KLBS 1-DROP BALL AND ROD " -PULL LANDING JOINT,TWO PIECE LANDING JOINT CAME UNTHREADED AT LOWER PUP THREADED INTO HANGER 15 00 - 17:30 2.50 RUNCOM N DPRB RUNCMP PULL 4-1/2"TUBING HANGER -ATTEMPT TO RETHREAD LANDING JOINT TOGETHER AND UNTHREAD FROM TUBING HANGER:FAILED -RETHREAD TWO PIECE LANDING JOINT TOGETHER RIG UP DOUBLE STACK CASING TONGS BACK OUT LOCKDOWN SCREWS PER CAMERON REP I-PULL 4-1/2"TUBING HANGER TO SURFACE -BAKERLOC AND RE-TORQUE LANDING 1 JOINT -ATTEMPT TO BREAK APART TCII TUBING HANGER CONNECTION -PUP JOINT BELOW TUBING HANGER CONNECTION IS SPINNING -CANNOT BREAK APART UPPER TCII CONNECTION AT 4800 FT-LBS LAY DOWN TUBING HANGER,TUBING I HANGER PUP JOINT,AND 6 FT PIECE OF LANDING JOINT THREADED INTO HANGER 17:30 - 21:00 3.50 RUNCOM N WAIT RUNCMP WAIT ON NEW TUBING HANGER R/U DOYON CASING CLEAN AND CLEAR RIG FLOOR Printed 7/14/2015 11:42:56AM nitnAtgOVAiWeal(-„ 1111 North America-ALASKA BP Page 7 of 8 Operation Summary Report'' Common Well Name:09-31 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/18/2015 End Date:3/22/2015 X3-013XD-C:(4,052,073.00) Project:Prudhoe Bay I Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 21:30 0.50 RUNCOM P RUNCMP PJSM DOYON AND CAMERON MAKE UP AND LAND HANGER j-LAND 4-1/2",12.6#VAM TOP COMPLETION -RUN IN HOLE ON TCII LANDING JOINT AND LAND STRING ON TUBING HANGER AT 11,136' !MD,6'ABOVE NO-GO,AND 5'INSIDE TIE-BACK RECEPTACLE -PARKER 273 RKB TO UPPER LOCKDOWN SCREWS=42.55'MD -FINAL PICKUP WEIGHT=139 KLBS, SLACKOFF=118 KLBS,PARKER 273 BLOCKS =35 KLBS -HES TNT 7"X 4-1/2"PERMANENT I PRODUCTION PACKER AT 11.009'MD -'XN'NIPPLE AT 11,118'MD HAS RHC-M PLUG INSTALLED 21:30 - 22:00 0.50 RUNCOM P • RUNCMP CAMERON REP RUN IN LOCKDOWN SCREWS -LOCK DOWN SCREW BACKED OUT LENGTH: 5-1/2" -LOCKDOWN SCREW RUN IN LENGTH:3-1/2" -LDS TORQUE:450 FT-LBS,GLANDS:500 FT-LBS 22:00 - 00:00 2.00 RUNCOM P RUNCMP PJSM SET HES TNT PACKER AND INTEGRITY TEST -PRESSURE UP AND SET PACKER PER HES REP MIT 4-1/2" 12.6#L-80 TUBING PT TO BALL AND ROD AT 11,118'MD CLOSE BLIND RAMS -VERFIY VALVE ALIGNMENT -PUMP 33 STROKES(3.1 BBLS)TO 250 PSI LOW& 4000 PSI FOR 30 CHARTED MINUTES -40 PSI LOST IN FIRST 15 MINUTES -15 PSI LOST IN 2ND 15 MINUTES -MIT MEETS BP STP CRT-AK-10-45 CRITERIA 3/22/2015 00:00 - 02:00 2.00 RUNCOM P RUNCMP -PRESSURE TEST 7 X 4-1/2"INNER ANNULUS AGAINST HES TNT PACKER '-DROP TUBING PRESSURE TO 2500 PSI I-PRESSURE TEST ANNULUS TO 250 PSI LOW FOR 5 MIN,4090 PSI HIGH FOR 30 MIN 0 PSI LOST IN 1ST 15 MINS,0 PSI LOST IN 2ND 15 MINS -TESTS MEET BP STP CRT AK-10-45 CRITERIA RECEIVED APPROVAL FROM WTL TO PROCEED SEE ATTACHED CHART RIG DOWN TEST EQUIPMENT 02 00 - 03:00 1.00 WHSUR P RUNCMP PJSM WITH CAMERON,SET AND TEST TWO WAY CHECK -CAMERON REP DRY ROD IN TWC -LINE UP TO TEST TWC -TEST TWC FROM ABOVE 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINS EACH Printed 7/14/2015 11:42:56AM r®®iii �/ % i' "/ ./i 7'%7" .��' 60�,- .� % // .oig e„/' ,O/, Common Well Name:09-31 AFE No Event Type:COM-ONSHORE(CON) ! Start Date:3/18/2015 End Date:3/22/2015 X3-013XD-C:(4,052,073.00) L— Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 273 Spud Date/Time:7/2/1985 12:00:00AM I Rig Release:3/22/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292139600 Active datum:09-31 D actual @67.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth I Phase Description of Operations 103:00 - 08:00 5.00 BOPSUR P usft) RUNCMP PJSM NIPPLE DOWN BOP I '- RIH WITH TEST JOINT,BLOW DOWN LINES I I-DRAIN STACK -REMOVE PS-21 1 -REMOVE BELL NIPPLE AND TURN BUCKLES I I I-DE-ENERGIZE ACCULULATOR I -NIPPLE DOWN BOP STACK AN SET ON 'STUMP I -REMOVE RISER i *BARRIERS TO N/D:KILL WEIGHT FLUID ON : TOP OF BALLAND ROD IN X NIPPLE,TESTED TUBING,TESTED PRODUCTION PACKER AND ANNULUS,TESTED TWC. 1 08:00 - 10:00 2.00 WHSUR P 1 RUNCMP NIPPLE UP ADAPTER FLANGE ,-CLEAN AND PREP HANGER VOID 1 ,-INSTALLNEWAPIRING I : I-INSTALL AND TORQUE ADAPTER FLANGE 1 I-PRESSURE TEST ADAPTER FLANGE TO 250 II PSI LOW FOR 5 MINUTES AND 5000 PSI HIGH FOR 30 MINUTES,CHARTED TESTS 10:00 - 12:00 2.00 WHSUR P I RUNCMP NIPPLE UP TREE ,-INSTALL NEW API RING '-INSTALL AND TORQUE TREE -RIG UP PRESSURE TESTING EQUIPMENT 1 -PRESSURE TEST TREE TO 250 PSI LOW AND 5000 PSI HIGH FOR 5 MINUTES EACH, LEAK TIGHT TESTS -RIG DOWN PRESSURE TESTING 'EQUIPMENT -SUCK DIESEL OUT OF TREE -APPLY HEET TO TREE VOID I -PLACE 3 QUARTS OF HEET GASOLINE ANTIFREEZE IN TREE AROUND TWC -SECURE WELLHEAD AND CELLAR ' I I **RIG RELEASE FROM 09-31D AT 12:00 HRS ' I 103/22/2015** Printed 7/14/2015 11:42:56AM 09-31 D, Well History (Post-Rig Sidetrack) DATE SUMMARY 6 4 // 'm 9 } -J. / R 4 f/' 1 :.r o i :5' 4 /,,,l'r": } t ry 4 } ' 4.7..�vs %‘441:11":i r. c �,',, ,s a ,r•s /ro i/ti /�� // / , fiC i .u. t. .,w a '., !,4,4,)„,,,,,,�/., ;�/j//zl ///fir%!,-'�' r //, ), ,a"'.. .. /mrr.,c,b�u tin&,.'. ;:,„�// �� %d r /y�:s;. ;e/r � �.:; r �,�,... T/l/Q=TWC/0/0 Installed upper tree. Removed piggybacked IA&OA valves, Tag#32 Pulled 4/20/2015 TWC#258 FWP's 0/0/0. oe�i. .r ! +;,,,gxA o 5 s /° " f� ter„ ' �� /////G'.�.. CTU#9 w/1.75"CT Job Objective: Drift, SCMT, Perforate. MIRU, MtU 3.4"nozzle drift BHA. RIH while pumping 1%KCL w/SL.Tagged down at 11439'ctm. Brought the pump online and was able to jet thru making it down to 11,493'. Unable to make it any deeper. Made four attempts to get thru 6/25/2015 while jetting, but was unsuccessful. POOH. MU motor/mill. REH w/3.70"5-blade'unk mitt. � �. %fir x tin o„y/O//---,k',,,,i;4"•w it%,/'Ilfc/ +r^r //,u/ s�`>r%,eli/ i/r z, �!/ /,,,,!<,,,,, ,,I,,�r� t'a'Y b://�/ , 9 9J i3g' .nR.3 � 3 �!%5" � .},� .�,;% '";+ y. � /%'Y f ' ,;$*/ ;'� ,•.•; ),/, y ; 1' „%4 Geo;',f , �:4'/� s''% r%//% grit/2 ,/ /i r ,Js ..//' 'J // / ,,,,T ,"�.0 , /� /G G / 5i�'..',/� ,1,' ,y���,/`,� , a� ' s/i -�.D '� $1�/. '��,��' ,zJ� '� �l// o � �y/�!/, 'r%/��y.�°r� �frit r. 4,4! ;%4,/,,*yr,4‘,.1,1174,-,Lciitr,„!19,, 51 ..''y/+. �x a .y. i 'm, t y6f'4 %,l.d 0 . E / 3 :el . r, ;./ja } ?„r3 y , ^2 ,74,/,y';''+/ 'r��,'7 .- xxS q' j/ jr #'<�,��titi axai i r/i.,`. . ,� :�' :' � �.r 9,si�ahyY%/1%' ��✓'��,����,� �+^ /r/��<,....,v �/�1.r,!�w/1.75"CT Job Objective: Drift, SCMT, Perforate. Logged up to 10,750'with SLB memory SCMT tools. RBIH to 12000'and displace well to diesel from depth to surface. POOH and MU 30' gun#1. Download log make+12'depth correction. Corrected EQP at flag= 15,525.62'. RIH to flag at 15,553 and correct depth to bottom shot(15,563.66'}. RlH and tag TD, get weight back at 15,755.5'(bottom shot depth). PUH to 15,650'and perforate interval 15,620`-15,650`with 2-7/8"PJ omega HMX 6spf,60 degree phase. POOH all shots Erred. MU 30'gun#2. Perforate interval 6/27/2015 15,590'-15620`. 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Thanx, Victoria On Mar 18,2015,at 6:32 PM, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>wrote: >Thank you for the schematic and interpretation.You have approval to move ahead.A cement evaluation log will be required in the production liner. >Thanx, >Victoria >Sent from my iPhone >>On Mar 18,2015,at 4:12 PM, Nocas, Noel<NoeLNocas@bp.com>wrote: >>Victoria, >>To re-cap our conversation: » I have attached the powerpoint again with the deeper interpretations+the sonic log interpretation across the shoe. »We did not see signs of a wet shoe. I believe the contamination in the shoe track was due to the leaky plug. »• No U-tube(zero flow after drilling out float equipment) »• No signs of 10.2ppg mud >>• No signs of HRZ shales in our returns »• No signs of black products in our production hole mud tests »I have also attached a schematic with formations. For zonal isolation we reference distinct permeable zones(DPZ) 1 and 3 in this area.They are shown on the schematic along with other formations between the two.We believe we have adequate isolation above and between the two DPZs. »Give me a call if you want to discuss! 1 • »Thanks, »Noel »From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] >>Sent:Wednesday, March 18,2015 13:32 »To: Lastufka,Joseph N; Nocas, Noel »Subject: FW:Additional Log 9-31Di »Please provide daily drilling report for the cement job. Was the job over-displaced or did you drill green cement in shoe track? »From: Loepp,Victoria T(DOA) >>Sent:Wednesday, March 18,2015 1:27 PM »To:'Lastufka,Joseph N'; Noel.nocas@bp.com<mailto:Noel.nocas@bp.com> »Subject: RE:Additional Log 9-31Di »Please provide the interpretation of these logs from your log specialist. »Thanx, >>Victoria »From: Lastufka,Joseph N (mailto:Joseph.Lastufka(a bp.com] >>Sent:Wednesday, March 18,2015 1:11 PM »To: Loepp,Victoria T(DOA) »Cc: Nocas, Noel; Endacott,Mary S »Subject: FW:Additional Log 9-31Di »Victoria, »Due to BP requirements an additional log was run on the 09-31Di 7" intermediate liner. »Could you please review and let us know if we can continue per your original approval? »09-31Di Intermediate Cement Job Summary: »(from previous email correspondence): » • 66bbls of cement pumped »o 3 bbls lost during job » • Actual Lift pressure=1089psi(Design lift pressure=1036psi) » • Circulating pressures prior to cement job and during displacement 3-5 times higher than planned due to suspected restriction or tight annulus » • Plug did not bump—when POOH with liner running tool a fin from the wiper dart was found lodged in tool, indicating the plug could not seal effectively when it landed on seat » • 7" liner and liner top packer test to 4000psi »Job performed PER AOGCC 20 MC 25.030.5: 2 • O » • Sufficient cement to cover>500'of open hole above hydrocarbon bearing zone » • No lost returns »• FIT test to 10.55ppg passed indicating good shoe »• No U-tube on drill out of shoe with 8.6ppg mud. >>Please respond at your earliest convenience. »Thank you. »<09-31Di cement interpretation.ppt> »<0397_001.pdf> 3 • • 0 Co 1 W 0 H 0 n r--1- CD 0 0 01 • • co (f) --_-1 , IN, . vt r a a i $ iii 4 ‘. 1i.Lht z • i L. 1 N r = 1I LF, 1 \ 4 W n o — p. i—g 4 24 i 1 I r gra li as $ 4 :1 i ii: lit oR a *i 4 C- v CD 3 CD r—F e s s e a 13t2g g -- Cr c Lf_n c �I 1 48 i ;e fig. u tlE ti } Q I $ $ $ggM R g W $ OF, • • r 8 0 08 CD g 8 WN C, to G No C N O 8 r, N O 2 N z G) N z O 0 ms. 0 U - m f 01 o574tm5O00808ci --A. ,, 73p: , mac -ocx) i 0 . . 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BENDER Customer: BP Exploration Alaska Inc Dispatched To: Makana Bender Well No: 09-31D**REVISION-1** Date Dispatched: 10-Apr-15 APIN: 50-029-21396-05-00 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Delivered To: 10APR15-SPO1 AOGCC Makana Bender N/A Contents on CD N/A Color Log Prints: VISION*Services 2"MD MAD Pass x VISION*Services T MD x VISION*Services 2'TVDSS MAD Pass x VISION*Services 2'TVDSS R EC E 1 VE D x VISION*Services 5•MD MAD Pass Quadrant Density x VISION*Services 5'MD MAD Pass APR 10 2015 x VISION*Services 5'MD Quadrant VISION*Services 5'MD AOGCC x VISION*Services 5•TVDSS MAD Passx VISION*Services 5'TVDSS x Digital Data N/A Contents on CD x Survey 1 Contents on CD ASP Final Survey x x ***REVISION-1 updated APIN*** EOW CD 1 Contents on CD Graphics:PDF x Data:DLIS/ASCII x Survey:PDF,XLS ***REVISION-1 updated APIN*** Please sign and email a copy to: Please sign and email a copy to: AlaskaPTSPrintCenter(cr�slb.com gancpdc(a�bp.com Alaska PTS Print Center ATTN: Merion Kendall Received By: � ✓�� V )3,4.442t • • 4 a W O m]A O O C C yy 7 0 e m-n 2 u 3 ;...: dBaZ2as =cal a - y; : 0 2 o z - O !: m ro idr 33 m a4� g d g a_p o, d i o s z,r 2 o N -0m i l^ vii ' m o vU m NV , a N+ m m V P U A w - s "O Wu aaasa U$UNN Naaaaaa Raaaa 0Na0g Oo,NUo3o 3 o+zzz ;o 0 O�m4 mio® nP oromm2 vd cp oo � _ w on V N n N 1 O N -E,m G u N A D J O m m P ts re m m i No O O ::,4 ,. 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N ...... 5 00000 0,--. +ONO Po 'owwroa4:3 Mw 2:44: A AAA A f POpO++N 0.41410 A W O.N+ 448s3: 4 -•00roN A W Nom+ M0 V V_V V_- i V V m a W A N ++ O S i :446'5 -m : .O POW ro w ��..11 5 -mm:,- N+rofNfJJO Na+O1N Oo V W N a1W.1 Wm W 0 0 0 0 0 '8'488'8 m NAA 1AVkiA.AJN Q WNNU NN+lP r N N w T w v v 0 W W m •t A A A A A AAA A m ro ro ro ro ro m ro m N+ t N N -13 m +A mNV NwN NVAN .0 2. 0 • RECEL(ED / 1 41 97 • 25615 APR 02 SchlumbergerA OGCCTransmittal#: 02APR15-SPO2 Drilling & Measurementst144JJ V DATA LOGGED 44 40/2o1S MWD/LWD Log Product Delivery K BENDER Customer: BP Exploration Alaska Inc Dispatched To: Makana Bender Well No: 09-31D Date Dispatched: 2-Apr-15 APIN: 50-029-21396-05-00 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Delivered To: AOGCC Makana Bender Contents on CD N/A Color Log Prints: 1 PTS ANSWER PRODUCT SonicScope Top of Cement 6827- 11,722 ft MD Digital Data N/A Contents on CD x Survey N/A Contents on CD CD 1 Contents on CD Graphics:pds/pdf x Data:DLIS/ASCII x Please sign and email a copy to: Please sign and email a copy to: Alaska PTSPrintCenter(a�slb.com qancpdcbp.com Alaska PTS Print Center ATTN:Merion Kendall Received By: � 6,eft • Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Friday, April 10, 2015 9:44 AM To: 'Nocas, Noel' Cc: Endacott, Mary S <Mary.Endacott@bp.com> (Mary.Endacott@bp.com) Subject: Packer Placement Variance Request 09-31Di [PTD 214-197] Noel, Due to the geometry of the well, a variance is granted to set the packer up to 250' MD above the intermediate casing shoe per 20 AAC 25.412(b). This packer placement is^'4500' MD(-460'TVD)above the planned top perforation in this horizontal injector. The production liner CBL is required and the log and interpretation must be provided to the AOGCC when acquired.Will the CBL be run across the liner lap? Future requests for this type of variance must be made in the original PTD. Victoria Loepp Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppR ialaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Nocas, Noel [mailto:Noel.Nocas@bp.com] Sent: Friday, April 03, 2015 4:11 PM To: Endacott, Mary S; Loepp, Victoria T(DOA) Subject: RE: Variance Request 09-31Di [PTD 214-197] Victoria, I apologize for missing this in the initial PTD. The PTD should have had the Variance request. Currently there are no perforations in the well. Below is a description of the well as we drilled it and the specific variance description and request. Please do not hesitate to contact me if you need any more information. Well Description: 09-31 Di is planned as an injector in Zone 2 of the authorized injection strata per Area Injection Order 4F corrected. The well was drilled and a completion string was run. Perforations were postponed due to logging requirements in the production interval. Current packer depth is 11,009' MD(8,354' TVDss).The initial planned perforation interval is 15,500'- 15,650' MD(8,811' TVDss). A CBL is planned of the production interval. (This will be done at the request of BP subsurface and AOGCC to confirm isolation). Exact perforation depths will be decided after the production liner has been logged. 09-31Di Variance description and request: 1 . Variance to 20 AAC 25.412(b) is requested. BP wishes to operate 09-31Di as an injection well with the packer set greater than 200' MD above the initial top perforation. If the initial planned perforations are executed,this will place the packer 4,491'MD from(457' TVD above)the top perforation. Engineering Justification: Setting the production packer high is a common variance request for BP injectors in Alaska. (See N-28i PTD 214-127). Construction,geologic and geometric challenges do not allow the packer to be placed within 200'MD of the top perforations. In the interest of maximum reserves accessed,this well design and perforation strategy allows the most responsible recovery due to a wide injection interval. This injection strategy would not be feasible with the packer 200'MD above the perforations. • Construction: Due to a liner overlap of 100-150' and the space out required to set the packer(-400'),the packer is commonly greater than 250'MD away from the shoe of the previous casing/liner string alone. Due to this,the packer cannot be reasonably placed within 200' of the perforations. • Geologic: Unstable overburden shales above the production/injection intervals in combination with depleted pressures in the production/injection intervals do not allow the intermediate shoe to be placed deeper in the injection interval. o The overburden is drilled with high mud weights. These mud weights would cause considerable losses and potential fracturing of the production/injection interval. • Geometric: The overburden cannot be drilled at high angles through the unstable shales. High angles require high mud weight for stability. The mud weight required would increase risk for mud losses,drilling problems, and liner running difficulties. The overburden must be drilled at lower angles,which in turn creates more directional work to be done in the production interval to reach the desired target. This directional work does not allow the packer to be placed within 200' of the perforations. Attached: 09-31 Di Schematic and Wellbore depth profile 2 • • N Ie01ID 111111H 11:H HH iiii ;1111111 ilh I! 1111H-11111 1 WI 1111 Hi! 1111 H1,111111111 iiii H o .. H N 15500 C i i!ii iH1 Hi1 1111 1111 111i i1111!1 P. (131t C 1 1i1 1111 HH 1H1 :11M 111i 11f11 -11 G d a n Z 15000 a 'n y� IiHi d3 Cr11,,in 14999 P r. . a U ('1500 f VW WHHI WI WI 11111 1111 1111 1111 a >n k (� �'�. 110 00 � .„, 12500 Hy Hii ,,,,,i Hi:, iiii !Hi !Hi Hi! id F Hi V IFJ e. ii-H HUM Hil IHI WI 1111 WI WI IP rl, a P _.. Y c.1 a„ p per. d G 1 c w C: O m Inmm rt a °° Will .Z WI Hi! .:.H: Hii rjii it : ..,.' ':', 'Fr ! :4Q. 3 9000 b ,nn u, n d • S ,sun 8.. a a G 1 I. T Q .. .3;;;M � 1000 Ci ,,en 0 Chm 6500 an _ M a 6000 iHi O P 0 1.!1011 C' 4 a01 in.', y ,. .dm •,...i : ,nun II ' It [ 1 ' !lt €':. Itl €1 I ':' '.I I 2500 20 muss TREE= 41/16'CAN SA NOTES:H2S READINGS AVERAGE 125 ppm WF3 LFEAD= fitt BAKE • 09-31D M **' WELL ANGLE>70°@ 11667'***CHROME ACTUATOR= BAKER C TBG 8 LNR "'MAX DOGLEG:15.5•@ 11756' BEB EV = 50' L 'F.F3EV= 23.0' KOP= 4400' 7 I 1993' H4-1/2"HES X N�D=3.812" Max Angle 950 @ 11946' —•COPD' Datum MD= WA —#, Datum ND= 8800'SS D= " 13-3/8"CSG,72#,L-80 BUTT,D=12.347" H 2533' (FIRST 2 JOINTS ARE K-55) TOP OF 7"LNR H 3347' 1--..1 3347' -5/8"X 7"BKR HRD-E ZXPN LIP =' 1 9 w/11"TIEBACK,D=6.170" 9-5/8"GEJ 1 WHPSTOCK(02/26/15)--I 3505' • 9-5/8'CSG,47#,L-80 BTC,D=8.681' H -3506 \ 3362' H9-5/8"X 7'BKR FLEX-LOCK HGR D=6.190" Minimum ID = 3.725" @ 11118' <4 9-5/8'CSG MLLOUT WIJDOW(09-3113) 3505'-3522" 4-112" HES XN NIPPLE TOP OF CEMENT(7"CSG) -I 5600' 1 Po rlD-___ _ ,. , 10978' H4-1/2"HES X NP,D=3.813" 15u li f3S` 7 v 0 o d .. 011009' —17"X 4-1/2"HES TNT PKR,D=3.856" ter ,'a . a-.e h`"Al ' ' 4 ` IN 11046' -+--u2 r x NP,13=3.813" P fAr ,t\ I may` KV t 1n� G,G i ' i5 11118' -14-1/2"I S NP,Di 3.725" 401 11133' 7"X 5"BKR ZXP L '1 TOP OF 41/2"LNR --I 11133' i �. w/11"TACK,D= 330" 41/2'TBG,12.6#,13CR-85 VAM TOP, H 11136' } / 11136' I-I4 112"wLEG,D=3.95 .0152 bpf,ID=3.958" - Ili 9 V 1115T -17'x 5'BKR FLEX-LOCK 04 HGR,D=4.310" ITOP OF 4-1/2"LNR CMr I-I -11155' I `;� Halm Tr LOGGED___/_/____\J r.+ MP3- 3 $/(- ' �+ 11167' 5"X41/2'XO,D=3.900" 11233'71:: t 7"LNR,26#,L-80,VAM TOP HC, -I , ii l-<f) 0 16 5 .0383 bpf,D=6.276" .} f l i 13 f r"wne" f► 13279' HRA TAG ON STOP RING PERFORATION SUNI�MRY C,a .* REF LOG: LOG ON XX/XX/XX c` ANGLE AT TOP PERF:_'a,__-' :* L Note:Refer to Rod uction DB for historical perf data ;* SIZE SPF IMT32VAL Opn/Sqz SHOT SOZ .+ 14564• H TAG ON STOP Rt4G 4 M i 4 f 4 t r PBTD H 15768' 41/2"LNR, 12.6#,13-CR VAM TOP, -I 15853' .0152 bpf,D=3.958" DATE REV BY CONMENTS DTE REV BY COMM3JTS FRUDHOE BAY UNIT 08/07185 RWN 35 IMTIAL COMPLETION 03/27/15 JMD DRLG HO CORRECTIONS WELL: 09-31D 05/28/86 WW1 RECOMPLETION - 04/03/15 NWJMD FINAL ODE APPROVAL PERMT No: 2141970 04/21/93 N2ES SIDETRACK(09-31A) API No: 50-029-21396-05 08/06/94 CTU CTD SIDETRACK(09-31B) SEC 2,T1ON,R15E,1587'FSL&998'FWL 04/28/96 NI353 CTD SIDETRACK(09-31C) 03/22/15 PKR 273 SIDETRACK(09-31D) BP Exploration(Alaska) • • To: Endacott, Mary S [Mary.Endacott@bp.com] Subject: RE:Variance Request 09-31Di [PTD 214-197] Mary, A schematic, proposed packer depths, proposed perforation depths and a clear explanation of the variance request is needed. Please copy this to the appropriate engineer. Thanx, Victoria From: Lastufka, Joseph N [mailto:Joseph.Lastufka@bp.com] Sent:Thursday, April 02, 2015 5:23 PM To: Loepp, Victoria T(DOA) Cc: Endacott, Mary S Subject: Variance Request 09-31Di [PTD 214-197] Victoria, Due to the geometry of the production interval,the production packer must be set outside 200' of the perforated interval. This is a variance from the regulation to set the production packer within 200' MD of the perforations. We are requesting this variance because it was not made clear(in writing)in the initial permit to drill.The schematic did not provide adequate detail on the depth of the perforations,however during the planning phase of this well perforations were planned greater than 200' away from the production packer. We have delayed the perforations until we are able to run a Cement Bond Log at the AOGCC's request. Please let me know if you have any questions or need additional information. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 w , BP Exploration Alaskal900 E.Benson Blvd.lRoom: 788DIAnchorage,AK 4 • I pro 2-14-iq Loepp, Victoria T (DOA) From: Nocas, Noel <Noel.Nocas@bp.com> Sent: Wednesday, March 18, 2015 4:12 PM To: Loepp, Victoria T (DOA) Subject: RE:Additional Log 9-31Di Attachments: 09-31Di cement interpretation.ppt; 0397_001.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, To re-cap our conversation: I have attached the powerpoint again with the deeper interpretations+the sonic log interpretation across the shoe. We did not see signs of a wet shoe. I believe the contamination in the shoe track was due to the leaky plug. • No U-tube(zero flow after drilling out float equipment) • No signs of 10.2ppg mud • No signs of HRZ shales in our returns • No signs of black products in our production hole mud tests I have also attached a schematic with formations. For zonal isolation we reference distinct permeable zones(DPZ) I and 3 in this area. They are shown on the schematic along with other formations between the two. We believe we have adequate isolation above and between the two DPZs. Give me a call if you want to discuss! Thanks, Noel From: Loepp, Victoria T(DOA) [mailto:victoria.loepp( alaska.gov] Sent: Wednesday, March 18, 2015 13:32 To: Lastufka, Joseph N; Nocas, Noel Subject: FW: Additional Log 9-31Di Please provide daily drilling report for the cement job. Was the job over-displaced or did you drill green cement in shoe track? From: Loepp, Victoria T(DOA) Sent: Wednesday, March 18, 2015 1:27 PM To: 'Lastufka, Joseph N'; Noel.nocas@bp.com Subject: RE: Additional Log 9-31Di Please provide the interpretation of these logs from your log specialist. Thanx, Victoria 1 • From: Lastufka,Joseph N [mailto:Joseph.Lastufka@ bp.com] Sent: Wednesday, March 18, 2015 1:11 PM To: Loepp, Victoria T(DOA) Cc: Nocas, Noel; Endacott, Mary S Subject: FW: Additional Log 9-31Di Victoria, Due to BP requirements an additional log was run on the 09-31 Di 7"intermediate liner. Could you please review and let us know if we can continue per your original approval? 09-31Di Intermediate Cement Job Summary: (from previous email correspondence): • 66bbls of cement pumped o 3 bbls lost during job • Actual Lift pressure= 1089psi(Design lift pressure= 1036psi) • Circulating pressures prior to cement job and during displacement 3-5 times higher than planned due to suspected restriction or tight annulus • Plug did not bump—when POOH with liner running tool a fin from the wiper dart was found lodged in tool, indicating the plug could not seal effectively when it landed on seat • 7"liner and liner top packer test to 4000psi Job performed PER AOGCC 20 AAC 25.030.5: • Sufficient cement to cover>500' of open hole above hydrocarbon bearing zone ✓ No lost returns ✓ FIT test to 10.55ppg passed indicating good shoe ✓ No U-tube on drill out of shoe with 8.6ppg mud. Please respond at your earliest convenience. Thank you. 2 P 7—(7 Z1 `"/77— •WELLHEAD= OY CCNV4 118'SK C r3 NOTES:FRS READINGS AVERAGE 125 ppm WHEN ON M WB-L ANGLE>62 @ 11450'—4-1/2" = ACTUATORAX9_LSON 54 Intermediate Section roRCHROME TBG L�1R'"' NT AL Imo.ELE; 54' I ' BF.T3EV= KOP= 3500 GOOD circumferential Max Angle= 90°n 11846' Datum MD= 9527' cement Datum TVD= 8832'SS Fair to Good 13-3/8"CSG,72#,L-80 BUTT,O=12.347" -{ 2533• cement (FIRST 2 JOINTS ARE K-55) TOP OF7"LM H 3350• Patchy cement 2° 9-5/8"WHPSTOOK(_/ /_J H 3600' 1 9-5/8°CSG MLLOUT WINDOW(09-31D) 3500'-3516' 9-5/8"CSG,47#,L-80 BTC,D=8.681" 8400' xr - 7,925' MD - GOOD cement Intervals Top CM3/ Base DPZ 1 - 8734' 9180-9196' GOOD cement 8,728' to 9590' Fair to good 9565-9580' - GOOD cement cement Top CM2 - 9,582, Top CM1 - 10,500' 40° 9,590-10,690' Patchy/contaminate Cement Top HRZ- 10,941'0 `�Qk A 10,940-11,020' Patchy Cement ri bn 11,080-11,090' Patchy Cement DPZ 3 - TSHU 11,229' (8594 TVD) 11,140-11,216' Patchy Cement 7" LNR,26#, L-80 VT TH, _0383 bpfl"11233' Sonic log shows cement around shoe - TSAD - 11,286' could not log to shoe depth with USIT Drill Out: - No U-tube on drill out - Good FIT test to 10.55ppg - No shale returns in production drilling activity - No black products in production mud testing Planned first perforations - Zone 2C 15,500' (8875' TVD) } Y I S LI N 2 4-0 U 0 F 0 0 0 • 20 § ttt. •-• — tE 4 b 7 i IC ,t ..,- .i gil ' i21 ill t 4 C,... 0 4 .r. 0 4° r -.P0E ... tO .. 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IT• , ---... ..._.,-...- . ,....,......., mi .. _ _ _- • k • • pTD 2. 14 -l9 Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, March 16, 2015 11:27 AM To: Lastufka,Joseph N; Loepp,Victoria T(DOA) Cc: Nocas, Noel; Roach, Frank;Tambe,Abhijeet; Endacott, Mary S Subject: RE:09-31D intermediate cement job and log PTD 214-197 Follow Up Flag: Follow up Flag Status: Flagged Joe, Looked at CBL logs. Appears you have adequate cement coverage at the 7"shoe area (>500ft) to continue with —� operations. I didn't see a clear TOC pick and based on the amount of cement you pumped would have expected it below 8500 ft. MD with gauge hole (seems to be some cement at least to 6900 ft. ) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Lastufka, Joseph N [mailto:Joseph.Lastufka@bp.com] • Sent: Monday, March 16, 2015 10:53 AM To: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Cc: Nocas, Noel; Roach, Frank; Tambe, Abhijeet; Endacott, Mary S Subject: 09-31D intermediate cement job and log 09-31Di Intermediate Cement Job Summary: • 66bbls of cement pumped o 3 bbls lost during job • Actual Lift pressure= 1089psi(Design lift pressure= 1036psi) • Circulating pressures prior to cement job and during displacement 3-5 times higher than planned due to suspected restriction or tight annulus • Plug did not bump—when POOH with liner running tool a fin from the wiper dart was found lodged in tool, indicating the plug could not seal effectively when it landed on seat • 7"liner and liner top packer test to 4000psi Job performed PER AOGCC 20 AAC 25.030.5: ✓ Sufficient cement to cover>500' of open hole above hydrocarbon bearing zone ✓ No lost returns ✓ FIT test to 10.55ppg passed indicating good shoe ✓ No U-tube on drill out of shoe with 8.6ppg mud. 1 • r Attached the SLB print for the TOC(the interval was split in 2 parts) Does the state approve of this cement job and logs?We would like to know as soon as possible. Please let me know if you have any questions or need additional information. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 4 BP Exploration Alaska1900 E. Benson Blvd.IRoom: 788D1Anchorage,AK 2 VNELLt EAD= CNV4-1/8"5K CARBMc ON i 09-31 D SAO NOTES:H2S�L ENGLE AVERAGE 125 ppm ACTUATOR= AXELSON 11450'"•"4-112' INMAL KB.ELB 54' Intermediate Section CHROMETBG&LNR'"" BF.ELEV= 23.0' KOP= 3500' Max Angle= 90°@ 11846' 1 —2200' 4-12"HES X NP,D=3.812" Datum MD= 9527' Datum TVD= 8832'SS 13-3/8"CSG,72#,L-80 BUTT,D=12.347" —I 2533' `y ' (FIRST 2 JOINTS ARE K-55) TOP OF 7"LM —I 3350' vv 2° 9-5/8"WHPSTOCK(_//_j --J 3500' 9-5/8"CSG MI.LOUT WINDOW(09-31D) 3500'-3516' 19-5/8"CSG,47#,L-80 BTC,D=8.681" H $400' 7"LNR,26#,L-80 VT TH,.0383 bpf,D=6.276" H 11230' 4u I IL I6-1/8" open hole DATE REV BY COMMENTS DATE REV BY COMVBNTS PRUDHOE BAY UNIT 08/07/85 RWN 35 IMTIAL COMPLETION 06/09/14 JOG Revised for WPO8 WELL 09-311 05/28/86 WW1 RECOMPLETION PERMIT No: 04/21/93 N2ES SIDETRACK(09-31A) API No: 50-029-21396-01 08/06/94 CTU CTD SIDETRACK(09-31B) SEC 2,T1 ON,R15E,1587'FSL&998'FWL 04/28/96 NES3 CTD SIDETRACK(09-31C) 06/03/13 JM D BUILD PROPOSED BP Exploration(Alaska) • PTD 214- 1 (3 � Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Friday, February 13, 2015 11:21 AM To: 'Nocas, Noel' Subject: RE: PBU 09-31Di (PTD 214-197) - Request no Intermediate LOT Noel, Approval is granted to delete the LOT at the 9-5/8" intermediate kick off point. Please include this approval with the approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa7alaska.aov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeon@alaska.gov From: Nocas, Noel [mailto:Noel.Nocas@bp.com) Sent: Monday, February 09, 2015 4:04 PM To: Loepp, Victoria T(DOA) Cc: Endacott, Mary S Subject: PBU 09-31Di (PTD 214-197) - Request no Intermediate LOT Victoria, You have heard from both Josh Tempel (09-03A PTD 214-178)and Jesse Rosenbaum (03-15B PTD 215-005) on the request to withdrawal the step in which a LOT is performed at the 9-5/8" kick off point (window). I am also writing to request a change to the PTD 214-179(which was approved 12/17/14)so that we can abstain from performing a Leak Off Test(LOT)at the 9-5/8" kick off point. In the submitted permit,on step number 14 of the proposed procedure,we stated that a LOT will be performed after the 9-5/8" window is milled.Again, we reviewed BP procedures and AOGCC regulations and policies and did not find any requirement to conduct an LOT unless we drill out of the shoe. Reference-(20 AAC 25.030(f)) 1 i I Instead of performing an LOT at the window,the plan is to drill the intermediate interval using the original surface casing shoe Leak Off Test of(11.2ppg). Engineering Justification: 1) Using the surface casing shoe LOT in a sidetrack correlates to the grassroots standard/regulation of drilling a well and using the surface (13-3/8") shoe LOT.This is further correlated because there is no cement behind casing from the KOP to the surface casing shoe which would likely result in testing the formation integrity from the 9-5/8" TOC to 13-3/8"casing shoe. Performing an LOT at the KOP would be similar to performing a LOT part way through drilling the intermediate section of a grassroots well which is not the goal of a LOT. 2) The original surface casing LOT for 09-31Di is sufficient to drill the intermediate section of the well I appreciate your consideration for this change. Thanks, Noel Noel Nocas IPA Rotary—Drilling Engineer BP Alaska noel.nocas(&,bp.com 0:(907)564-5027 C:(907)229-9532 F:(907)564-5510 2 of T �� \� Iy/ s THE STATE Alaska Oil and Gas of Conservati®n Commission LAsKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *h' Main: 907.279.1433 OF ALAS"-�` Fax: 907.276.7542 www.aogcc.alaska.gov Mary Endacott Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-31D BP Exploration (Alaska), Inc. Permit No: 214-197 Surface Location: 1587' FSL, 998' FEL, Sec. 02, T10N, R15E, UM Bottomhole Location: 307' FNL, 4022' FEL, Sec. 11, T1ON, R15E, UM Dear Ms. Endacott: 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 AOGCC 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 AOGCC 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ‘e), —>" Daniel T. Seamount Commissioner DATED this/7 day of December, 2014. I s STATE OF ALASKA RECEIVED ALAS•IL AND GAS CONSERVATION COMMI•N NOV 2 5 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Typetof work: 1 b.Proposed Well Class: 0 Development Oil 0 Service-Winj ®Single Zone . 1 c.Specify if well is proposed for: ❑Drill 0 Lateral 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates , •®Redrill 0 Reentry 0 Exploratory •®Service-WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 2.Operator Name: 5.Bond ®Blanket 0 Single Well 11.Well Name and Number: BP Exploration(Alaska) Inc. Bond No 6194193 PBU 09-31D 3. Address 6.Proposed Depth: 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 15814' • TVD 8893' Prudhoe Bay/Prudhoe Bay . 4a.Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: ADL 028327&028328 1587 FSL,998' FEL, Sec.02,T1ON, R15E, UM ' 8.Land Use Permit: 13.Approximate Spud Date: Top of Productive Horizon: 2684'FSL, 743' FEL, Sec.03,T10N, R15E, UM February 10,2015 . Total Depth 9.Acres in Property: 14.Distance to Nearest Property: 307'FNL,4022'FEL, Sec. 11,T10N, R15E, UM 2560 16900' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 60.6' . feet 15.Distance to Nearest Well Open Surface: x 717376 • y-5943027 • Zone- ASP4 GL Elevation above MSL: 19.8' J feet to Same Pool: 249' 16.Deviated Wells: Kickoff Depth: 3500' feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3291 .. Surface: 2436 ' 18. Casing Program Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8-1/2" 7" 26# L-80 VamTop HC 7935' •3350' 3350' 11285' 8619' 226 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 Hydril521 4679' .11135' 8504' 15814' 8893' 565 sx Class'G' I VamTop 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 TVD(ft): Junk(measured): 10946' 8824' 9170',9390',9489',10000',10531' 10900' 8825' 10600' Casing Length Size Cement Volume MD TVD Conductor/Structural 111' 20" 1800#Polyurethane 111' 111' Surface 2533' 13-3/8" 2500 sx CS III,400 sx CS ll 2533' 2533' Intermediate 8400' 9-5/8" 500 sx Class'G', 300 sx CS I 8400' 8132' Production Liner 826' 7" 264 cu ft Class'G' 8234'-9060' 7973'-8739' Liner 2129' 2-7/8" 17.5 Bbls Cement 8816'- 10945' 8525'-8824' Perforation Depth MD(ft): 8972'- 10875' Perforation Depth TVD(ft): 8664'-8826' 20.Attachments: 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report IN Drilling Fluid Program 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct: Contact Noel Nocas,564-5027 Printed Name Mary Endacot Title Engineering Team Leader Email Noel.Nocas@bp.com Signature y/j�/S � /6*--hone 564-4388 Date II/24'M Commission Use Only Permit To Drill /G API Number: Permit Approv I Date{: See cover letter for Number: ,�/L` f/ 50-029-21396-05-00 ;"a,1 In( 1 4/ other requirements: Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas Er Other: f U 0 contained shales: P tC5 -to 4 Upsi Samples Req'd: 0 Yes [iNo Mud Log Req'd: 0 Yes [v]No 4/Inv/a,- ,, 5 74' -177 7-'-d 49 P5 ' H2S Measures: [ Yes 0 No Directional Survey Req'd: [ Yes ❑No ,5fu_te w/71,-)c-5 5 rd /1/11T—/<`I• r-e`it"F133/No exception req'd: 0 Yes 'No inclination-only svy Req'd: 0 Yes allo gfter Sta1:21s/,3cd ivIJcci-Id l _ APPROVED BY /� ( APPROVED B i\ COMMISSIONERCOTHE COMMISSION Date I2 ,I 1 16 1 Net!��p�Qt��4 � approval(20 �9)) Form 10-401 Revised 10/2012 This ` i ��11 11--11sLLrom the date of AAC 25.005 Submit Form and Attacents In Duplicate VT1—IL 116/14 / .4L--) (2 °`e./ye ;E. S • by 09-31Di Permit to Drill Application Well Type: Injector Current Status: The well is currently shut-in. Request: Sundry approval has been requested for the P&A of Prudhoe Bay well 09-31C well to sidetrack and complete 09-31 Di well. This PTD request is to drill and complete a new injector on drill site 09. Reason for Sidetrack: The proposed —12314' (footage drilled) horizontal injector will access the base of the Victor interval in Zone 2. Well will provide MIST(Miscible Injection Stimulation Treatment) to 09-29, 09-04A, 09-26 and 03- 27 producers. The play concept is to expend MIST(miscible injection stimulate treatment)to increase MI sweep and capture EOR oil which was not swept by conventional WAG. The interval targeted is the Victor(42P-26P)which is roughly 80 tvdss. The prospect is consistent with the GPB Depletion plan, and drilling will be covered under the Prudhoe Annual Drilling FM. This well needs to be drilled from DS9 since DS 4 and DS11 do not have current MI injection capabilities. Well History: The original production well (09-31) was originally drilled in 1986 prior to a RST in 1993 (the 09-31A well which included a CTD open-hole completion below a 7" drilling liner) and 2 subsequent coil ST's in 1994 (09-31B) and 1996 (09-31 Ci). As the current 09-31 Ci well watered-out the 09-35A well, DS-09 conformance reviews determined shutting in this injector would be the best solution for optimization of the injection pattern. Scope of Work: The sidetrack plan for the 09-31 Di well includes the following: 1. Pre-rig 09-31 C P&A operations, MIT's and a tubing cut as required prior to sidetracking the well as detailed in the 09-31C Sundry request. 2. MIRU Doyon 25 and test BOP's. 3. Pull tubing from the pre-rig cut—4000 MD and make run a clean out run to the top of the tubing stub. 4. Sidetrack the well from the 9-5/8" casing. 5. Drill to the planned TSHU/TSAD casing point and run and cement a 7" drilling liner. 6. Drill the production hole to the planned TD and run and cement a 4-1/2" production liner. 7. Perforate the production liner on drillpipe. 8. Run a 4-1/2" chrome completion. 9. Freeze protect the well prior to RDMO. 09-31 Di PTD Page 1 11/24/2014 . • MASP: 2436 psi (7.4 ppg @ 8555'TVDss) , Estimated Pre-Rig Start Date: 02/10/15 Planned Well Summary Well 09-31 Di Well MI Injector Target Ivishak Type Objective Current Status Shut-In • Estimated Start Date: 02/10/2015 Time to Complete: 49 Days Northing Easting Offsets TRS Surface Location 5,943,027 . 717,376 1588' FSL/999' FEL , 10N 15E sec 2 Northing Easting TVDss Offsets TRS Tie-In (Survey) 5,943,039 717,407 3345' 1599' FSL/967' FEL 10N 15E sec 2 Northing Easting TVDss Offsets TRS Production 5,943,980 712,321 8805' 2684' FSL/743' FEL 10N 15E sec 3 Tgt BHL 5,941,047 714,410 8832' 4973' FSL/4022' FEL 10N 15E sec 11 Planned KOP: 3500' MD/3439' TVDss Planned TD: 15,814' MD/8832' TVDss Rig: Parker 273 • BF-RT: 40.8' RTE (ref MSL): 60.6 09-31Di PTD Page2 11/24/2014 S Directional - Schlumberger P8b KOP: 3500' MD • Maximum Hole Angle: -57.55° in the 8-1/2" intermediate section -89.5° in the 6-1/8" production section Close Approach Wells: 09-05, 09-05A Survey Program: 106.6' -3406.6' MD - BOSS GYRO 3406.6' -3500' MD- BOSS GYRO 3500' -3900' MD- INC+Trend 3900' -5400' MD-MWD 3900' - 11,280' MD- MWD+IFR+MS 11,280' - 12,780' MD MWD 11,280' - 15,814' MD MWD+IFR+MS Nearest Property Line: 16,900' Nearest Well within Pool: 09-05A-248.5' • 09-31Di PTD Page 3 11/24/2014 0 Formation Tops & Pore Pressure Estimate (SOR) Estimated Minimum Most Likely Maximum Depth Fluid Formation Formation Top Pore Pressure Pore Pressure Pore Pressure Uncertainty Type (TVDss) (EMW ppg) (EMW ppg) (EMW ppg) (+/-TVD ft) (for sands) SV4 3,153 8.4 8.4 8.5 SV3 3,703 8.4 8.4 8.5 SV2 3,905 8.4 8.4 8.5 5' SV1 4,319 8.4 8.4 8.5 5' UG4 4,922 8.4 9.3 9.5 5' water UG4A 4,942 8.4 9.3 9.5 20' water UG3 5,120 8.4 9.3 9.5 15' water UG1 5,849 8.4 9.3 9.5 15' water WS2 6,417 8.4 9.2 9.3 20' water WS1 6,602 8.4 9.2 9.5 • 15' water CM3 6,880 8.4 9.3 . 9.5 20' CM2 7,316 9.2 9.8 10.4 . 20' CM 1 7,970 9.8 10.0 10.5 . 20' THRZ 8,318 9.8 10.0 10.5 20' TSHU/LCU 8,520 6.9 7.4 . 9.8 . 20' TSAD 8,555 6.9 7.4 7.6 . 30' oil 42N 8,639 6.9 7.4 7.6 30' oiVw ater 42P 8,664 6.9 7.4 7.6 30' oiVw ater TCGL 8,708 6.9 7.4 7.6 30' oiVw ater BCGL 8,753 6.9 7.4 7.6 30' oiVw ater 25N 8,812 6.9 7.4 7.6 30' oiVw ater 13P 8,955 6.9 7.4 11.6 30' oiVw ater BSAD 9,015 9.3 9.8 10.3 30' oiVw ater Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD/TVDss MD/TVDss 8-1/2" 7" 26# L-80 Va HC op 7935' 3350' /3289' 11,285' /8559' 6-1/8" 4 '/2" 12.6# 13CR Hyd521/ 4679' 11,135' /8443' 15,814' /8832' 85 VamTop . Tubing 4 '/" 12.6# 1 85R VamTop 11,135' Surface 11,130' /8493' 09-31 Di PTD Page 4 11/24/2014 .s is • Mud Program Intermediate Mud Properties: LSND 8-1/2" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH Window Milling 8.5-9.0 10-18 26-30 <8 NA <18 9-10 KOP—TCM2 9.3-9.9 10-18 18-26 <8 NA <20 9-10 TCM2 -THRZ 9.9-10.3 10-18 18-26 <8 NA <20 9-10 THRZ-8-1/2" 10.2-10.4 10-18 18-26 <4 <10 <20 9-10 TD in TSHU *NOTE: MW>_ 10.2 is needed for HRZ Stability Production Mud Properties: Reservoir Drill-In Fluid 6-1/8" hole section Depth Interval Density PV YP LSRV API FL pH MBT (ppg) 7" Csg Shoe to TD 8.5 -9.1 <12 10-20 > 15,000 < 10 9.5-10.5 < 4 Logging Program 8-1/2" Intermediate: Sample Catchers—as required by Geology Drilling: Dir/GR/ Res Open Hole: None Cased Hole: Contingency USIT in cement evaluation mode from the 7"shoe to confirm TOC. 6-1/8" Production: Sample Catchers—as required by Geology Drilling: Dir/GR/Res/ Neu / Den /Sonic . Open Hole: None Cased Hole: None 09-31Di PTD Page 5 11/24/2014 S S Cement Program Casing Size 7" 26#, L-80, Hydril 563 or Vam Top HC, Intermediate Liner Lead: None Basis: Tail: 80' of shoe track + Annular volume from 7" shoe to 1300' MD above with 30% excess. Tail TOC: —1500' above the 7" shoe at—9985' MD Total Cement Volume: Spacer —40 bbls of Viscosified Spacer weighted to —11.0 ppg (Mud Push II) Lead None Tail 47 bbls, 262 cuft, 226 sks 15.8 lb/gal Class G— 1.17 cuft/sk Temp BHST 202° F, BHCT TBD by Schlumberger Casing Size: 41/2", 12.6#, 13Cr-80, Hydril 521 or Vam Top, Production Liner Basis: Lead: None Tail: Volume of open hole +40% +80' shoe track + 150' 4-%"x7" liner lap +200' of 7"x4" DP excess. Tail TOC: Liner Top, excess will be circulated out Total Cement Volume: Spacer 25 bbls of Viscosified, 12.0 ppg weighted Spacer(Mud Push II) Lead N/A Tail 117 bbls, 655 cuft, 565 sks 15.8 lb/gal Class G + adds— 1.17 cuft/sk Temp BHST=202° F, BHCT TBD by Schlumberger Surface and Anti-Collision Issues Surface Shut-in Wells: No surface shut-ins. 09-38 currently offline. Close Approach Shut-in Wells: 09-05 and 09-05A fail Major Risk analysis. A TCR will need to be filled out for each to determine action. 09-31 Di PTD Page 6 11/24/2014 • Loepp, Victoria T (DOA) From: Nocas, Noel <Noel.Nocas@bp.com> Sent: Tuesday, December 16, 2014 10:48 AM To: Loepp,Victoria T (DOA) Subject: RE: PBU 09-31D(PTD 214-197)Anti-collision measures Victoria, 09-05 is plugged and abandoned as it is the parent for 09-05A. 09-05A will be shut in at surface and also secured with a tested downhole plug. Thanks, Noel From: Loepp, Victoria T(DOA) [mailto:victoria.loeDD@alaska.gov] Sent: Tuesday, December 16, 2014 10:02 AM To: Nocas, Noel Subject: PBU 09-31D(PTD 214-197) Anti-collision measures Noel, The anti-collision reports indicate major risk failures for 09-05 and 09-05A. Please outline anti-collision mitigating measures for each failure that allows minor risking these wells. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�alaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 1 • Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction Uncertainty Lost Circ and Magnitude Potential Zone 2 14689' 8823' dtn 20' +1-200' Low Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal / Contact the GPB Environmental Advisors (659-5893) f/guidance. Area of review Wells within Distance(Ft.) Cement Job Information 1/4 mile 9-5/8" casing was set at 10,654'and cemented with 600sxs Class G. Bumped plug 't,, 09-38 . 1,000 and floats held. No losses or issues noted in reports. Drilled out firm cement and v\. FIT to 12.5ppg. Estimated TOC based on gauge hole is 8,432',providing 2,222'of coverage. 9-5/8" casing was cemented in two stages.The first stage was cemented with 09-16 . 850 1000 sxs Class G. Plugs bumped and floats held with no issues or losses were noted during the job. Estimated TOC based on gauge hole is 7,666',providing 3,703'of coverage.(The second stage was initiated through an FOC at 2412'and'"275 sxs were squeezed down the 13-3/8"x 9-5/8" annulus) 9-5/8" casing was cemented in two stages.The first stage was cemented with 800 sxs Class G. Plugs bumped and floats held with no losses or issues noted. 03-10 1,050 Estimated TOC based on gauge hole is 6,104',providing 2,962'of coverage.(The second stage was initiated through and FOC at 2,465'and"'275 sxs were squeezed down the 13-3/8"x 9-5/8"Annulus. ) 9-5/8" casing cemented with 500sxs Class G-1846'gauge hole annular length. ,j( Plugged bumped and floats held. No recorded losses or issues during the job. 03-27 . 790 Estimated TOC based on gauge hole and 500 sxs Class G is 8,319',providing 1,883' of coverage. 09-31Di PTD Page 7 11/24/2014 • 9-5/8"Casing was cemented with 500 sxs class G. Plug was bumped and floats held with no losses or issues noted in the reports.The casing was tested(PASS)and the 09-29 720 shoe track drilled out.A LOT was performed to 11.2 indicating a good cement job and competent formation. Estimated TOC based on gauge hole is 8,195',providing 1,851'of coverage. 09-32i-This well was drilled setting the 9-5/8"production casing at 10,672'MD placing the shoe above the TSAD per the original well plan.Also,per the wellplan, this casing string was cemented with 500 sxs of Class G cement(^'103 bbls) 09-32 • 1,230 providing 1,851'of coverage using a gauge hole calculation.There were no problems associated with this cement job with the plug bumping at 6492 strokes and 3000 psi with no record of any losses. 09-04A-The parent completion on 09-04 is isolated above TSAD to the upper formations by the original cement job on the 9-5/8" production casing which was run on 05-15-76 to a depth of 10,234'. It was cemented with 1000 sxs Class G 09-04A 1145 cement,providing 3700'of planned gauge hole annular coverage to a measured 41, 09-04 855 depth of^'6530'. Reports indicated zero losses during cement job and plug bumping on strokes.The 09-04A RST kicked-off from this well at^'8639' MD, placing this KOP^'2010'below the planned TOC on the original 09-04 9-5/8" cement job. 09-05A-This well is isolated above TSAD to the upper formations by the original cement job on the 09-05 9-5/8"production casing which was run on 6/14/76.This casing was run to a total depth of 11,284' MD(well designed to set this casing string above TSAD)and cemented with full returns with 750 sxs('"155 bbls)of 15.8 09-05A 410 ppg Class G cement with the planned TOC to be 2645'above the casing shoe N`, (gauge hole calculation).The cement job on this casing string was pumped on 09-05 515 6/15/76 and pumped with full returns while showing continued lift pressure to 1250 psi and the plug was"bumped"placing the estimate TOC at^'8639'MD. The 09-05A RST kicked-off from this well at 10,740'MD placing this KOP,"'2101' below the TOC on the original 09-05 9-5/8"cement job. NOTE: For the purpose of this AOR summary,TSAD isolation is considered to be sufficient when a minimum of 50' of good cement can be calculated/estimated/assumed given the details of the actual cement job on the pertinent casing string as detailed in the existing records/files for each well. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500/4000 psi. BOP regular test frequency will be 14 days during drilling phase and 7 days during sundry operations. Intermediate Interval 09-31Di PTD Page 8 11/24/2014 S Maximum anticipated BHP 3291 psi @ TSAD at 8555' TVDss (7.4 ppg EMW) j Maximum surface pressure 2436 psi (.10 psi/ft gas gradient to surface) Kick tolerance 26.1 bbls with 12 ppg frac gradient, assuming an 7.4 ppg pore pressure in the Sag River+ 0.5 ppg Kick intensity and 10.2 ppg MW. Rams test to 4000 psi/250 psi. Planned BOP test pressure Annular test to 3500 psi/250 psi 7" Drilling Liner 4000 psi surface pressure Integrity Test—8-1/2" hole LOT after drilling 20'-50' from middle of window 7" Drilling Liner 7" rams will be used to accommodate the 7" casing string. Production Interval Maximum anticipated BHP 3291 psi @ TSAD at 8555' TVDss (7.4 ppg EMW) Maximum surface pressure 2436 psi (.10 psi/ft gas gradient to surface) Kick tolerance Infinite with 9.0 ppg frac gradient, assuming an 7.4 ppg pore pressure in the Ivishak+ 0.5 ppg Kick intensity and 8.5 ppg MW. Rams test to 4000 psi/250 psi. Planned BOP test pressure Annular test to 3500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20'-50' of new hole Planned completion fluids Seawater/6.8 ppg Diesel Wellplan Addendum Contingency for well control when non-shearable equipment is across the BOPE shear rams This document will provide guidance for rig operations when a well control event arises and there is non-shearable equipment hanging from the derrick across the BOPE shear rams. 09-31 Di PTD Page 9 11/24/2014 • • Prior to picking up or running any equipment or tools in the hole, a PJSM and discussion is required to identify and note any equipment which will be run through the BOPE and is non-shearable. A risk assessment shall be performed for any equipment which is deemed non-shearable. The risk assessment must address the following: 1. Can variable bore rams seal against the equipment? 2. Can an annular preventer seal against the equipment? 3. Is a cross-over readily available to make-up into equipment? 4. Is a single joint or full stand of DP readily available to lower equipment below the BOPE stack? 5. How the equipment can be intentionally dropped down hole. 6. Are weights of equipment known so that hydraulic jacking force of wellbore pressure can be calculated. 7. Accurate and up to date shearing capabilities for the current shear rams installed is available. 8. Has each crew member been versed on individual roles and responsibilities? If there is a well control event happens with non-shearable equipment across the BOPE shear rams,the following procedure should be followed: 1. Based on the risk assessment above, gain control of the well by either: a. Closing the appropriate preventer(pipe ram,VBR, or annular) or b. Placing a sealable piece of equipment across the BOPE and closing the appropriate preventer or c. Dropping equipment and closing the Blind or Blind/Shear rams. 2. If well conditions permit, contact appropriate personnel. If not, proceed with well kill operations. This may include placing shearable equipment(i.e. drillpipe) across the shear rams by stripping in/out of the hole. Pre-rig prep work: 1. MIT-IA to 4000 psi, MIT-OA to 2000 psi. 2. PPPOT-T to 5000 psi, PPPOT-IC to 3500 psi, function LDS. 3. Set CIBP at 8922' MD (50' above top perf) and dump-bail 25' of cement on top of the plug. • 4. Make tubing punch at —8770' MD and place 15.8 ppg G cement on both sides of the tubing to 7700' MD. D&T cement. Test TxIA to 4000 psi. 09-31 Di PTD Page 10 11/24/2014 5. Make tubing cut -4000' MD and circulate the well to clean seawater. Test TxIA to 4000psi after cut. 6. Freeze protect the well to 2200' MD with diesel. 7. Install TWC, NU Dryhole tree and test. Proposed Procedure: 1. MIRU Parker 273 2. Pull TWC. Circulate out freeze protection and circulate well to 8.5 ppg seawater. 3. Set a TWC and test from above to 3500 psi for 5 minutes and from below to 3500 psi for 30 minutes. 4. Nipple down tree. Nipple up and test BOPE to 4000 psi 5. Pull TWC with lubricator. 6. RU and pull the 4-1/2" tubing from the pre-rig jet cut at-4000' MD. 7. RIH with clean out assembly down to top of tubing stub. 8. Rig up E-line and GR/CCL log from tubing stub to surface confirm KOP and casing collar locations for the planned KOP. 9. Set EZSV on E-line at-3500' MD and pressure test to 4000 psi. 10. PU 9-5/8" whipstock and RIH to the top of the EZSV. 11. Shear-off mills and hang-off the drill-string on a storm packer. 12. Change-out the 9-5/8" pack-off and test. 13. Swap the well to the planned milling fluid and mill a window in the 9-5/8" casing plus 20' of formation. 14. Perform a LOT and POOH for drilling BHA. 15. MU an 8-1/2" drilling BHA and RIH. 16. Drill 8-1/2" intermediate hole to planned TD. 17. Circulate well clean, short trip as needed and POH for the 7" drilling liner. 18. Run and cement a 7", 26#, L-80 liner(will log cement per AOGCC injector well requirements). 19. Change out upper 7" rams to 2-7/8" x 5-1/2" VBR and test to 4000 psi. 20. MU a 6-W drilling assembly with directional tools, PDC or insert bit + MWD and LWD tools. RIH to top of the float collar and test well to 4000 psi prior displacing the well to an 8.5 ppg reservoir drilling in fluid. Log 7" TOC with Sonic Tool. 21. Drill out shoe and 20' of new formation and perform a FIT. 22. Drill the 6-1/8" production hole, per directional plan (planned for 1-2 BHA's). 23. Circulate as required at TD prior to a wiper to the shoe and MAD passing as required by - geologist. 24. Trip back to bottom and circulate hole clean and POOH for the production liner. 25. Run and cement a 4-1/2", 12.6#, 13CR production liner from TD to 150' inside the 7" shoe. 26. Set the liner top packer and displace the well to 8.5 ppg seawater. 27. Perforate the well on drillpipe. 09-31Di PTD Page 11 11/24/2014 28. Run the 4-1/2", 12.6#, 13Cr completion tying into the 4-1/2" liner top. 29. Reverse the well to clean fluids. 30. Drop ball & rod and set the production packer and individually test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes each. 31. Shear the shear valve in the GLM and confirm circulation. 32. Set and test a TVVC to 250 psi low/3500 psi high above for 5 minutes each and below to 250 psi low/3500 psi high for 5 min low/30 min high. 33. ND BOPE. NU and test the tree to 5000 psi. 34. Pull TWC. Freeze protect the tubing and IA to —2,200' TVD. 35. Install a BPV. 36. Secure the wellbore and RDMO. Post Rig Work: 1. Pull ball and rod and RHC plug. 2. Pull shear valve from GLM and install dummy valve. 3. Run SBHPS. 4. Perform full-bore injectivity test(150 bbls). 5. Contingency ASRC flowback and/or fullbore HCL treatment. (Flowback attempted only if SBHPS and facility situation allows). 6. Contingency CTU cleanout and/or CT acid treatment. 09-31Di Drilling Critical Issues (POST THIS NOTICE IN THE DOGHOUSE) I. Well Control/ Reservoir Pressures (High GOR Well): A. An off-set injector well review will be performed 2 months prior to spud to determine which wells will need to be SI to drill the production hole on this well. B. Intermediate Hole: Cretaceous pressure is expected to be at a 9.3 ppg EMW. CM2 is expected to be at a 9.8 ppg EMW. CM1 is expected to be at a 10.0 ppg EMW. HRZ will require a 10.2-10.3 ppg mud weight for shale stability. TSAD is expected to be at a 7.4 ppg EMW. C. Production Hole: Ivishak is expected to be at a 7.4 ppg EMW. II. Lost Circulation/Breathing A. Intermediate Hole —There are no expected fault crossings in the intermediate hole section, however, lost circulation and/or wellbore breathing can always be considered a possibility in many areas of GPB. 09-31Di PTD Page 12 11/24/2014 • B. Production Hole— Lost circulation is a risk due to the 1 fault crossing in the production hole, however, lost circulation has not been a significant problem in this area of the field. III. Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction Uncertainty Lost Circ and Magnitude Potential Zone 2 14689' 8823' dtn 20' +/-200' Low IV. Integrity Testing Test Point Test Depth Test type Target EMW(lb/gal) 9-5/8"window 20'-50' from the 8.5" window LOT 12 ppg 7" shoe 20'-50' from the 7" shoe FIT 9.0 ppg VI. Hydrogen Sulfide DS-09 is considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Reading Date Comments Parent Well(if sidetrack) 09-31C 275 PPM 1/4/2011 #1 Closest SHL Well H2S Level 09-30 450 PPM 10/21/2013 #2 Closest SHL Well H2S Level 09-29 500 PPM 4/1/2012 #1 Closest BHL Well H2S Level 03-27 240 PPM 1/28/2012 #2 Closest BHL Well H2S Level 09-28A 725 PPM 3/18/2014 1000 PPM in 2009 #3 Closest BHL Well H2S Level 09-04 550 PPM 1/11/2014 #4 Closest BHL Well H2S Level 09-05A 800 PPM 10/15/2012 Max.Recorded H2S on Pad/Facility 09-29 1200 PPM 7/31/2008 2 wells away... 09-03,05A,09,028A,29 each have samples at or above 900 PPM. The sheer Other Relevant H2S Data volume of water injected at DS9 lends itself to higher H2S concentrations in (H2S alarms from rigs,etc.) the contacted reservoirs. VII. Anti-Collision Issues The 09-05 and 09-05A wells fail Major Risk. A TCR will be done for each well and the well will be secured as required to Minor Risk the wells. CONSULT THE DS-09 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 09-31Di PTD Page 13 11/24/2014 l 09 c f009-3r 09 • ‘ 04-45 �" . pg_ 09} \ \ 04_06 ���`111 f. r%','• 1`- _ 09-14A Pi.,11, 1 i Wells within 14 Mile I,YI ` Dist,Ft. ' ' . ''r i t of 09-3101 '1` q p Illr 316 ;I 033s 1,000 i',1;' ,,,,,,,,/,',14,,,„ A t ` ` 1 ogtl 0378 850 . //+ :- — - t 4..........., 111k, ,\ It, 0310 1.050 0 q41' /fft1. 0327 790 ',., ... 09-29 720k , '• - 0332 1,230 X "' \----- ✓ pq—o� 03 r' ��-- (✓ \0I` • 09 1� __� _. "\ !1 7 -"/"*. \_,_,______._ 03- 8 ' ..;,://y/ \ --'-,-, , 1):: 7''C' *.-.,/iiii/,''''' ') /0// lt g08 ; r1� zs /I 65- 1° ` - ;i''� '7, .3- 1 110 09-03 t _feel r 03 }`. :t e I 1 , , . • • TREF= 5.1/8•AtEVOY 09-31C SAFETY NOTES:MS READINGS AVERAGE 125 ppm V LFFAD=.._. �� WHE10N M— Wal ANGLE>Trra 9210-••'4-1/2- ACTUATOR= AXBSQV CHROME TOG 67-LNR" HEAL KB.ILL% 54' 1 8F.9..E./= 23E/ 3r—I—E5.12•X4-12'XO,D•3.95r I KOP=MaxAngle• • 96,4 9694',S1/2'ABG 1'/i, Mum AO= 952r 1-80,.0232 bpf, 4-36.41.1-V13' 8809 SS 111'4.092 -- -H New 1_[4..lir CA MCO TRCFdA T1i5SSV,ID=3.812 1 I GAS LIFT AMPS 13-Irr CSG.720,L-80 BUTT,D•12.34r —I 2533' ST AD TVD OEV PIPE VLV LATCH FORT DOTE (FIRST 2 JOINTS AIF K-65) , 1 3193 3193 0 TGR) DAA' RK 0 10/27/05 2 4802 4186 18 TOR) MAY IRC 0 10/27/05 Minimum ID©2.387"@ 8822' I 3 5605 5535 23 TCa'1D DAN IRC 0 03/31/96 3-112"X 2-7/8"LNR XO 4 6178 6063 23 TODD C Y IRC 0 05/2395 5 6704 6648 23 TOED GNI' IRC 0 03/31/96 L f 6 7236 7036 22 TGFD CNN RK 0 042293 DKR c-2 7®1AC7(SLV ID 7.50• 13____]-1 ,",„x„,4' K 't 'J' 7 776 5 7530 21 TGR3 DIN/ RK 0 04/22193 I9-516'X r BKR F1 R tl 1198 MG,R,D 6 19til--I. 8241' 8 8059 71106 19 TOP) caw FE 0 04/22/93 9 8202 7942 18 TGR). DMP RK 0 05123195 19-516'CSC,4755 1-80 BTC,D=5 681'-1-1 -- MOO' 1 ._.............. 1 ■ 8762' 4.1/1SUMSHP,D•3813'I 9-518'CSG MLLOUT WNDOW(09-31*) 1140(7-8490' g 8774' H 7'x 4.172"MIR SABL-3 RQR D=3.875• 1 8515• 4-Iir DEPLOY 8Lv,D•3,W (F 8822' 1--13.112'X 2-718•LAR XO,D-2.38r I 1 , t 8832-1-44-1/2-SWS NTP,0=3.813• 4 Ur TBG 12.69,13CR NSCT, --I 8842' I / { 5545' H4-12-WLE{3,3.958'I .0152 Of,D•3.958' I 9850' H awi TT LOGGED 07/05554 I 7'LW MLLOUT W943OW(09-31C)9080'-9088- 7'LNR 292,13CR•60 NSCC, 9060 I.0371bp1, D=6151• 11` 44. R3FRATIDN SUMMARY O4. ♦1111. REF LOG'SPE RY-SLIT AWAD I OG CN 04/27/96 19014 140 is, 411111. ANGLE AT TOP PER:30"148972' 111111111111111 't, 1111111 11111111 No4ar lifer b Rodxton DIt for Irclaa:aTperl dad 11111111 s I_9170• J_12-718'COP I 11111111 SIZE SPE NfH2VAL OpN',gz 6410T 9OZ 1111411111141111 ,' 2' 8 8977-8982 0 1124101 1141•01111. 9390 elrn j_12-7/6"8'CSP{07857001 I 11111111011111 2' 6 8987-8999 0 1124/01 1111111111111111 2' 6 9004-9104 0 10116/01 ��4�����11111111 18a9� 2-718•C9SP(052696)I 2' 6 9100-9114 0 1128/06 r 6 9132-9142 0 112896 /r t l0000chI� 716'C�(02Wg7)) 2.1/8' 4 9236-9226 C 10/16/01 I1p531'e1mi-f2-778.OSP(1032/98)I 7-18' 4 9¢36-9254 C 10118/01 �- 2' 4 9267.9281 C 10/1601 2-1/8' 4 9/10-9785 C 06/28/98 /r ilb [ 10600' FBM-2-119'CSP 2-118' 4 10250-10325 C 02/04/97 (LOST 9-25-96) ,2-1B• 4 10115-10815 C 10/12196 1111. t I �—I 10282' 12.718•LMR B 59,180,0058 bpf,D=2,38r H 10545' •N. DATE FFV BY (JC>M(ITS DATE ' REV BY CEMENTS FRlDHOE BAY MIR i 86/07185 1891435 INTIALCOMPLET)ON 01/1112 TM9JADADDED KIS SAFETY NDW VAH.L:09-31C 116/2871182 WW1 RECOMPLETION 05/23/13 RUC 'FUO1$4AT F136JT Nu.5960540 04/21193 942P.5 90ETRACK(09-31A) AR No:50-029 21396-03 98/01104 CTU CTD SIDETRACK(09-31E9 SEC 2,T1094,R156.1587'FSL 3 998'9WL 04729!15- 11ES3 CTD SIDETRACK(09-31C) 12/07/06 .7+1/27 H ADFHZF(11/28106) BP Bcplorallon(Alaska) 09-31Di PTD Page 14 11/24/2014 i I III TREE= CM'4-11!5K CARBON SAFETY NOTES:FOS READINGS AVERAGE 125 ppm wu€A f O= *EVi PROPOSED 0 9-31 n WREN ONM^ WELL ANGLE,.aro 114S0""4.1n" ACTUATOR= AXELSOI1 CHROME TBG$LHR'"' • FETAL KB aE'r 54' BF.REV= 23 OI KOP= 3500 , `2200' H4-1/7 HES X NP,ID•3.817 IJaaAngle _... _..90'a 11846'. Datum MD• 952T GAS LFT MANORS Datum TVD= 8832'SS I ST MD TVO DEV 1 TYPE VLV LATCH PORT DATE 1 300 3400 13 3M'CSG,)2M.L 80 BUTT,O.12 34r --I 2533' (MST 2 JOINTS ARE K,-It 2 5620 5250 r 3 8509 6800 4 tont 8000 [TOP OF#.fit]-8365 - .1 2° 19-5/8'VIA-IPS TOO((__f_.,J -I 3500' 4 508'CSG MLLOUT WPOOW(01410$ 3500'-3516' *a $ I9cso'1'R' .47o,L.80BTC D.80dI' -{ 8400' ' I I I 11000' J-{4-112"HES XNP,0.31913' Minimum 10 -3.725 @ 11130'1 8 X ( 11030' J-{rx4-irrKis TNT PKRID=3675' I I I I_...M1101W 1--14-1/2•NEB x HP o a 3.013'1 I I L 11130' 1-11-14-174-1FES XN IW.1)=3,725' I TOP Of 4-1fr LNR -{ 11135' I\ 4-tir TDO,12.86.1)CR VT. -{ 11135' 1. i J I 11140' 1-14-1/2*WIEG.3.958'I 0152 bpf.O=3.958' I ' J.-�R L —/- 1 4d 7'LNFt 268,L 80 V1 TH, 0383 NA,0.8.278" J-{ 11286' . k___,______:— _______,. PEAFORATEN Sfl.0 RY REF LOG LOGON XXIXX/XX ANGLE AT TOP P _°12_' Nab:War to R'08m-him DB for hslorcal pert data SIZE SPF M131VAL OprVSqz SEDT 902 ll TBD a S C ro_1-[+i'1 11. .1. 4.14 1 1.1.0.1.1 9d' 4-VY Lhit,12 60,13-CR VT, 0152. bpi,O=3.906' }— 15814' _._DATE tREV, BY_..._._,_,_..� S 4, DATE REV BY CCO ENTS PRUDHOEBAY IINIT 0IA7765 RWN35 INTTIALCOMPLETION 06#01014 JOG Revised forWP06 WELL 09-31D 05(25188 WWI RT3:OMPLETKXV FERMI No 04721,93 NM '_51DETRACK(09-31A) AR No: 50-029-21396-04 08'06+94 CTU CTD Si DET RACK(09-31B) SEC 2,TIM,R15E 158T FSL 6 996 FW 04/28;96 Nf$3 CTO SI On RACK(09-31C) • 015,03713 JM0 BUIL 13 PROPOSED BP Etploralbn(Alaska) 09-31Di PTD Page 15 11/24/2014 • b P0 • • DS09-31D(P8b)Proposal Geodetic Report Schiemherger (Def Plan) Report Date: June 24,2014-09:04 AM Survey/DLS Computation: Minimum Curvature/Lubinski • Client: BP Vertical Section Azimuth: 130.000°(True North) • Field: Prudhoe Bay Unit-EOA Vertical Section Origin: 0.000 ft,0.000 ft Structure/Slot: DS-09/09-31 �'ad/ TVD Reference Datum: Rotary Table Well: 09-31 ��a �'� �J( M' TVD Reference Elevation: 60.600 ft above MSL • Borehole: Plan 09-3112 v tl�V Ground Elevation: 19.8 ft above MSL • API*: 500292139605 .� Magnetic Declination: 10.621° Survey Name: 09-31D(P8b) Total Gravity Field Strength: 1001.9972mgn(9.80865 Based) Survey Date: June 24,2014 Gravity Model: DOX Tort/AHD/DDI/ERD Ratio: 221.318°19998.701 ft/8.595/1.124 Total Magnetic Field Strength: 57624.527 nT / Coordinate Reference System: NAD27 Alaska State Plane,Zone 04,US Feet • Magnetic Dip Angle: 81.015' Location Let/Long: N 70°14'49.21899",W 148°14'37.75213" Declination Date: December 31,2014 Location Grid N/E Y/X: N 5943026,830 ftUS,E 717376.180 ftUS • Magnetic Declination Model: BGGM 2013 CRS Grid Convergence Angle: 1.6529° North Reference: True North Grid Scale Factor: 0.99995388 Grid Convergence Used: 0.0000' Version/Patch: 2.7.1043.3 Total Corr Mag North-'True North:19.6209° Local Coord Referenced To: Well Head • Comments MD Incl Azim True NDSS ND VSEC NS EW TF DLS Directional Northing Basting (ft) el C) (ft) (ft) (ft) (ft) (0) C) ('11008) Difficulty Index (ftUS) (ftUS) 0.00 0,00 0.00 80.60 0,00 0.00 0.00 0.00 OM N/A 0.00 5943026.83 717376.18 660 0.00 0.00 -54.00 6.60 0.00 0.00 0.00 OM 0.00 0.00 5943026.83 717376.18 40.80 0.00 0.00 -19.80 40.80 0.00 0.00 0.00 88.3M 0.00 0.00 5943028.83 717378.18 106.60 0.50 88.30 46.00 106.60 0.21 0.01 0.29 90.2M 0,78 0.00 5943026.85 717376.47 208.60 0.50 90.20 146.00 206.60 0.88 0.02 1,16 92.31M 0.02 0.00 5943026.88 717377.34 306.60 0.47 92.31 245.99 306.59 1.54 0.00 2.01 98,61M 0.03 0.04 5943026,89 717378.18 406.60 0,33 98.81 345.99 406.59 2.11 -0.06 2.70 105.61M 0.15 0.28 5943028.85 717378.88 506.60 0.43 105.61 445.99 506.59 2.89 -0.20 3.35 101.7M 0.11 0.43 5943026.72 717379,53 606.60 0.43 101.70 545.98 606.58 3.37 -0.38 4.08 86.1M 0.03 0.54 5943026.57 717380.26 706.60 0,38 86.10 645.98 708.58 3.93 -0.43 4.77 89.3M 0.12 0.66 5943026.54 717380.96 806.60 0.55 89.30 745.98 806,58 4.54 -0.40 5.58 83M 0.17 0.80 5943026.59 717381.77 906.60 0.68 83.00 845.97 908.57 5.31 -0,33 6.65 70,3M 0.15 0.93 5943026.70 71738284 1006.60 0.55 70.30 945.97 1008.57 5,95 -0.09 7.69 60.3M 0.19 1.06 5943026.96 717383.87 110660 0.60 60,30 1045.96 1106.56 6.38 0.33 8.60 52.1M 0.11 1.14 5943027.41 717384,77 1206.80 0.62 52.10 1145.96 1206.56 6.67 0,92 9,48 52.39M 0.09 1.21 5943028.02 717385.63 1306,80 0.55 52.39 1245.95 1306,55 8.89 1.55 10.29 56.5M 0.07 1.28 5943028.67 717388.42 1406.60 0.70 56,50 1345.95 1406.55 7.16 2.18 11.18 73.3M 0.16 1.35 5943029.33 717387.29 1506.80 0.55 73.30 1445.94 1508.54 7.60 2.65 12.15 52M 0.24 1.44 5943029.83 717388.25 1606.60 0.60 52,00 1545.93 1606.53 7.97 3.11 13.02 64.5M 0.22 1,52 5943030.32 717389.10 1706.60 0.67 64.50 1645.93 1706.53 8.33 3.69 13.96 54.3M 0.15 1.58 5943030.92 71739403 1806.60 0.57 54.30 1745.92 1806.52 8.89 4.23 14.89 56M 0.15 1.63 5943031.48 717390.94 1908.60 0.68 56.00 1845.92 1906.52 8.98 4.85 15.79 59.19M 0.11 1.68 5943032.13 717391,82 2006.60 0.80 59.19 1945.91 2008.51 9.37 5.54 16.88 53.1M 0.13 1.73 5943032.85 71739289 2108.60 0.92 53.10 2045.90 2108.50 9.78 6.38 18.12 50.69M 0.15 1.79 5943033.73 717394.11 2208.60 0.78 50.69 2145,89 2206.49 10.09 7.29 19.29 60.89M 0.14 1.84 5943034,68 717395.25 2306.60 0.77 60.69 2245.88 2306.48 10.45 8.05 20.40 63.1M 0.14 1.88 5943035.47 717388.34 2406.60 0.90 63.10 2345.87 2406.47 11.00 8,74 21.69 63,1M 0.13 1.93 5943036.19 717397.61 2506.60 0.72 63.10 2445.86 2506.46 11.55 9.38 22.95 64.46M 0.18 1.97 5943036.86 717398.85 13-3/8" 2539.60 0.74 64.46 2478.85 2539.45 11.72 9.56 23.33 . 67M 0.08 1.98 5943037.06 717399.22 2606.60 0.78 67.00 2545.85 2606,45 12.11 9.93 24.14 66.39M 0.08 2.00 5943037.45 717400.02 2706.60 0.80 66.39 2645.84 2706.44 12.73 10.47 25.40 63.5M 0.02 203 5943038.03 71740127 2806.60 0.60 6350 2745.83 2806.43 13.25 10.99 26.51 68.8M 0.20 2.07 5943038.57 717402.36 2906.80 0.60 68.80 2845.82 2906.42 13.71 11.41 27.47 77.19M 0.06 2.09 5943039.03 717403.31 3006.60 0.55 77.19 2945.82 3006.42 14.25 11.70 28.42 81.69M 0.10 2.11 5943039.35 717404,25 3106.60 0.55 .81.69 3045.82 3106.42 14.86 11.88 29.37 90.11M 0.04 2.13 5943039,55 717405.19 3206.60 0.47 90.11 3145.81 3206,41 15.49 11.95 30.25 90.76M 0.11 2,15 5943039.65 717406.07 SV4 3213.79 0.48 90.76 3153.00 321360 15.54 11.95 30.31 97.9M 0.11 2.16 5943039.85 717406.13 3306.60 0.55 97.90 3245.81 3306.41 16.22 11.88 31.14 103.61M 0.11 2.18 5943039.60 717408.96 Tie-In Survey 3406.60 0.52 103.61 3345.80 3406.40 17.03 11.71 32.05 84.86M 0.06 2.19 5943039.46 717407.88 Top Whipstock 3500.00 0.57 84,86 3439.20 3499.80 17.74 11.65 32.93 49.43M 0.20 2.22 5943039.43 717408.76 Base Whipstock 3516.00 2.44 49.43 3455.19 3515.79 17.85 11.88 33.27 49.43M 12.50 2.38 5943039.66 717409.09 Cry 3/100 3536.00 2.44 49.43 3475.17 3535.77 17.99 12.43 33.92 3.12M 0.00 2.39 5943040.24 717409.72 3600.00 2.44 3.12 3539.12 3599.72 17.39 14.68 35.03 325.6814 3.00 2.53 594304252 71741477 3700.00 4.56 325.88 3638,94 3699.54 12.29 20.10 32,91 317.18M 3.00 2.72 5943047.87 717408.50 SV3 3764.35 6.31 317.18 3703.00 376360 6.33 24.81 29.08 314.19M 300 2.85 5943052.47 717404.53 3800.00 7.32 314.19 3738.40 3799,00 2.12 27.83 26.12 308.97M 3.00 2.91 5943055,40 717401.48 390000 10.21 308.97 3837.22 3897.82 -13.10 37.85 14.68 12.77L 3,00 3.10 5943065.08 71738474 SV2 3969.10 12.24 306,81 390000 3965.60 -26.54 46.09 4.03 10.65L 3.00 3.22 5943073.02 717378.87 4000.00 13.16 306.06 3935.14 3995.74 -33.32 50.13 -1.44 9.91L 3.00 3,28 5943078.89 71737130 4100.00 4100.00 16.12 304.20 4031.88 4092.48 -58.49 64.63 -22.12 8.11L 3.00 3.44 5943090.79 71735220 4200.00 19.09 302.91 4127.19 4187,79 -88.54 81.32 -47.34 6.88L 3.00 3.59 5943106.75 71732051 4300.00 22.07 301.95 4220.80 4281.40 -123.38 100.16 -77.02 5.98L 3.00 3.73 5943124.72 717298.30 4400.00 25.06 301.21 4312.44 4373.04 -162.93 121.08 -111.09 5.311. 3.00 3.86 5943144.85 717261.65 SV1 4407.24 2528 301.17 4319.00 4379.60 -165.97 122.88 -113.72 5.27L 3.00 387 5943146.17 717258.97 4500.00 28.05 300.62 4401.89 4462.49 -207.07 144.04 -149.44 4.78L 3.00 3.98 5943168.49 71722265 4600.00 31,04 300.14 4488.87 4549.47 -255.68 168.97 -191.98 4.361. 3.00 4,09 5943190.18 717179.42 4700.00 34.03 299.73 4573,17 4633.77 -308.62 195,80 -238.58 4.01L ' 3.00 4.19 5943215.65 71713208 4800.00 37.02 299.38 4654.54 4715.14 -365.76 224.45 -289.13 3.73L 3.00 4.29 5943242.84 717080.71 4900,00 40.02 299.08 4732.77 4793.37 -426.94 254.86 -343.47 3.49L 3.00 4.38 5943271.67 717025.51 5000.00 43.01 298.81 4807.64 4868.24 -491.98 288.93 -401.47 3.291. 3.00 4.46 594330205 716968.62 5100.00 46.01 298.57 4878.95 4939.55 -560.72 320.58 -482.96 3.121. 3.00 4.54 5943333.91 716904.19 UG4 5163.08 4790 29843 4922.00 4982.80 -605.89 342.58 -50347 3.03L 3.00 4.59 5943354.73 71686306 5200.00 49.00 298.36 4946.49 5007,09 832.95 355.72 -527.78 2.98L 3.00 4.61 5943367.16 716838.39 5300.00 52.00 298.16 5010.09 5070.69 -708.49 392.25 -595.74 2.85L 3.00 4.68 5943401.71 716769,40 • 5400.00 5600 297.98 5069.56 5130.16 -787.13 430.06 -666.66 2.741_ 3.00 4.75 594343746 716697.42 End Cry 5485,29 57.55 297.83 5116.91 5177.51 -856.49 463.26 -729.35 HS 3.00 4.81 5943488.84 716633.81 UG3 5491.04 57.55 297.83 512000 5180.60 -861.23 465.52 -73364 HS 0.00 4.81 5943470.98 716829.45 5500.00 57,55 297.83 5124.81 5185.41 -868.62 469.05 -740.32 HS 0.00 4.81 5943474.31 716622.67 5600.00 57.55 297.83 5178.46 5239.06 -951.12 508.45 -814.95 HS 0,00 4.85 5943511,54 716548.94 5700.00 57.55 297.83 5232.11 529271 -1033.61 547.85 -889.58 HS 0.00 4.89 5943548.77 718471.21 5800.00 57.55 297.83 5285.76 5346.38 -111610 58725 -964.20 HS 0.00 4.93 5943588.00 716395.49 5900.00 57.55 297.83 5339.42 5400.02 -1198.59 626.65 -1038.83 HS 0.00 4.96 5943823.23 716319.76 6000.00 57.55 297.83 5393.07 5453.67 -1281.09 668.05 -1113.46 HS 0.00 4,99 5943680.46 718244.03 6100.00 57.55 297.83 5446,72 5507.32 -1363.58 705.45 -1188.08 45 0.00 5.02 5943897.68 716168.30 6200.00 57.55 297.83 5500.37 5560.97 -1446.07 744.85 -1282.71 HS 0.00 5.05 5943734.91 716092.57 6300.00 57.55 297.83 5554,03 561463 -1528.56 784.25 -1337,34 HS 0.00 5.07 5943772.14 716016.85 8400.00 57.55 297.83 5607.68 5668.28 -1611.06 823.65 -1411.96 HS 0.00 5.10 594380937 715941.12 6500.00 57.55 297.83 5661.33 5721,93 -1693.55 883.05 -1486.59 H5 0.00 5.12 5943848.60 715865.39 6600,00 57.55 297,83 5714.98 5775.58 -1776.04 902.45 -1561.21 HS 0.00 5.14 5943883.83 715789.66 6700.00 57.55 297.83 5768.64 5829.24 -1858.53 941.85 -1635.84 HS 0.00 5.16 5943921.06 71571193 B800.00 57.55 297.83 5822.29 5882.89 -1941.03 981.25 -1710.47 HS 0.00 5.19 594395829 715638.21 UG1 6849.79 57.55 297.83 5849.00 5909.60 -1982,10 1000.86 -1747.62 HS 0.00 5.20 5943976.82 715800.50 6900.00 57.55 297.83 5875.94 5936.54 -2023.52 1020.65 -1785.09 HS 0.00 5.21 5943995,51 715562.48 7000.00 57.55 297.83 5929.59 5990.19 -2106.01 1060.05 -1859.72 HS 0.00 5.22 594403274 71548675 7100.00 57.55 297.83 5983.25 6043.85 -2188.50 1099.45 -1934.35 HS 0.00 5.24 5944069.97 715411.02 7200.00 57.55 297.83 6036.90 6097.50 -2271.00 1138.84 -2008.97 HS 0.00 5.26 .5944107.20 715335.29 7300.00 57.55 297.83 6090.55 6151.15 -2353.49 1178.24 -2083.60 HS 0.00 5.28 5944144.43 715258.56 7400.00 57.55 297.83 6144.20 6204.80 -2435.98 1217.64 -2158.23 HS 0.00 5.30 5944181.66 715183.84 7500.00 57.55 297.83 6197.85 6258.45 -2518.48 1257.04 -2232.85 HS 0.00 5.31 5944218.89 715108.11 Drilling Office 2.6.1166.0 Prudhoe Bay Unit-EOA\DS-09\09-31\Plan 09-31D\09-31D(P5c) 11/24/2014 11:09 AM Page 1 of 2 • • 7600.00 57.55 297.83 6251.51 6312.11 -2600.97 1296.44 -2307.48 HS 0.00 5.33 5944256.12 715032.38 7700.00 57.55 29783 6305.16 6365.76 -2683.46 1335.84 -2382.10 HS 0.00 5.34 5944293.34 714956.65 7800.00 57.55 297.83 8358.81 6419.41 -2765.95 1375.24 -2456.73 HS 0.00 5.36 5944330.57 714880.92 7900.00 57.55 297,83 8412.46 6473.06 -2848.45 1414.64 -2531.36 HS 0.00 5.37 5944387.80 714805.20 WS2 7908.45 57.55 297.83 8417.00 6477.60 -285542 1417.97 -2537.67 HS 0.00 537 5944370.95 71479579 8000.00 57,55 297.83 6466.12 6526.72 -2930.94 1454.04 -2605.58 HS 0.00 5.39 5944405.03 714729.47 8100.00 57.55 297.83 8519.77 6580.37 -3013.43 1493.44 -2680.61 HS 0.00 5.40 5544442.26 714653.74 8200.00 57.55 297.83 6573.42 8634.02 -3095.92 1532.84 -2755.24 HS 0.00 5.41 5944479.49 714578.01 51/S1 8253.26 57.55 29783 6602.00 6662.60 3138.86 1553.63 -2794.99 HS 0.00 5.42 5944499.32 714537.68 8300.00 57.55 297.83 6827.07 6687.67 -3178.42 1572.24 -2829.86 HS 0,00 5.43 5944516.72 714502.28 8400.00 57.55 297.83 6680.73 6741.33 -3260.91 1611.64 -2904.49 HS 0.00 5.44 5944553.95 714426.58 8500.00 57.55 297.83 8734.38 6794.98 -3343.40 1851.04 -2979.11 HS 0.00 5.45 5944591.17 714350.83 8600.00 57.55 297.83 6788.03 6848.63 -3425.89 1690.44 -3053.74 HS 0.00 5.46 5944628.40 714275.10 CM3 8622.31 57.55 297.83 6800.00 6860.80 -3444.30 1699.23 -3070.39 HS 0.00 5.47 5944636.71 71425521 8700.00 57.55 297.83 6841.68 6902.28 -3508.39 1729.84 -3128.37 HS 0.00 5.48 5944665.63 714199.37 8800.00 57.55 297.83 6895.34 6955.94 -3590.88 1769.24 3202.99 HS 0.00 5.49 5944702.86 714123.64 8900.00 57.55 297.83 6948.99 7009.59 -3673.37 1808.64 3277.82 HS 0.00 5.50 5944740.09 714047.91 9000.00 57.55 297.83 7002.84 7063.24 -3755.86 1848.04 -3352.25 HS 0.00 5.51 5944777.32 713972.19 9100.00 57.55 297.83 7056.29 7116.89 -3838.36 1887.44 -3428.87 HS 0.00 5.52 5944814.55 713896.48 9200.00 57.55 297.83 7109.95 7170.55 -3920.85 1926.84 3501.50 HS 0.00 5.53 5944851.78 713820.73 9300.00 57.55 297.83 7183.80 7224.20 -4003.34 1986.23 3576.13 HS 0.00 5.54 5944889.00 713745.00 Cry 3/100 9346.36 57.55 297.83 7188.47 7249.07 -4041.59 1984.50 -3610.73 130.941 0.00 5.55 5844906.27 713709.89 9400.00 56.51 296.37 7217.66 7278.26 -4085.45 2005.00 -3850.78 130.141 3.00 5.56 5944925.60 713669.27 9500.00 54.60 293.56 7274.23 7334.83 -4165.09 2039.83 3725.51 128.551 3.00 5.59 5944958.26 713593.56 CM2 9570.97 53.29 291.48 7316.00 7376.60 -4219.81 2061.81 377851 127.33L 300 5.61 5944978.70 713539.96 9600.00 52.77 290.81 7333.46 7394.06 4241.75 2070.14 3800.15 126.811 3.00 5.62 5944986.40 713518.08 9700.00 51.01 287.52 7395.18 7455.78 -4315.23 2095.87 3874.49 124.91 3.00 5.64 5945009.97 713443.04 9800.00 49.34 284.28 7459.23 7518.83 -4385.33 2116.93 -3948.33 122.821 3.00 5.67 5945028.90 713368.63 9900.00 47.76 280.88 7525.43 7586.03 -4451.86 2133.28 -4021.45 120.571 3.00 5.69 5945043.13 713295.06 10000.00 46.29 277.30 7593.61 7654.21 -4514.63 2144.86 4093.67 118.131 3.00 5.72 5945052.62 713222.54 10100.00 44.94 273.55 7663.56 7724.16 -4573.47 2151.64 4184.79 115.511 3.00 5.74 5945057.35 713151.26 10200.00 43.71 269.64 7735.11 7795.71 4628.21 2153.61 -4234.51 112.71 3.00 5.76 5945057.30 713081.42 10300.00 42.63 265.55 7808.06 7868.66 -4678.72 2150.76 -4302.93 109.721 3.00 5.78 5945052.49 713013.21 10400.00 41.69 261.30 7882.20 7942.80 -4724.85 2143.10 -4369.58 106.571 3.00 5.80 5945042.91 712946.81 10500.00 40.92 258.91 7957.34 8017.94 -4766.48 2130.65 4434.37 103.271 3.00 5.82 5945028.59 712882.42 CM1 10516.74 40.81 256.16 7970.00 8030.60 -4773.00 212510 -444502 102.711 3.00 5.82 5945025.73 712871.85 10800.00 40.32 252.39 8033.26 8093.86 -4803.48 2113.44 -4497.11 99.84L 3.00 5.84 5945009.58 712820.20 10700.00 39.90 247.78 8109.77 8170.37 -4835.77 2091.52 -4557.65 96.321 3.00 5.85 5944985.93 712760.32 10800.00 39.66 243.11 8186.64 8247.24 -4863.24 2064.98 -4615.81 92.721 3.00 5.87 5944957.69 712702.95 10900.00 39.61 238.40 8263.87 8324.27 -4885.83 2033.81 4871.43 89.11 3.00 5.89 5944924.96 712648.25 THRZ 10970.56 39.69 235.09 8318.00 837560 -4898.80 2009.13 -4709.07 88.55L 300 5.90 594489920 712611.34 11000.00 39.75 233.71 8340.65 8401.25 -4903.48 1998.17 -4724.37 85.49L 3.00 5.91 5944887.81 712596.37 End Cry 11079.66 40.00 230.00 8401.79 8462.39 -4913.96 1966.64 -4764.52 HS 3.00 5.92 5944855.13 712557.15 11100.00 40.00 230.00 8417.37 8477.97 -491623 1958.23 -4774.53 HS 0.00 5.92 5944846.44 712547.38 11200.00 40.00 230.00 8493.97 8554.57 -4927.39 1916.92 -4823.77 HS 0.00 5.93 5944803.72 712499.36 TSHU/LCU 1123397 40.00 230.00 8520.00 8580.60 -4931.19 1902.68 -4840.50 HS 0.00 5.93 5944769.21 712483.04 Tat TSAD 11279.86 40.00 230.00 8555.00 8615.60 -4936.29 1884.00 -4863.00 HS 0.00 5.93 5944769.69 712461.10 r 11284.66 40.00 230.00 8558.83 8619.43 -4936.84 1881.93 -4865.48 HS 0.00 5.93 5944767.55 712458.70 Cry 11/100 11299.66 40.00 230.00 8570.32 8630.92 -4938.52 1875.74 4872.85 47.481_ 0.00 5.93 5944761.15 712451.49 11300.00 40.03 229.96 8570.58 8631.18 -4938.56 1875.60 4873.01 47.441 11.00 5.93 5944761.00 712451.33 11400.00 48.03 219.08 8642.52 8703.12 -4943.52 1825.89 -4921.21 39.581 11.00 5.97 5944709.93 712404.59 11500.00 58.83 210.71 8703.50 8764.10 -4936.13 1760.84 -496615 34.471 11.00 6.02 5944643.61 712361.55 11600.00 68.09 20393 8751.27 8811.87 -4916.86 1682.83 -5006.18 31.211_ 11.00 6.06 5944564.49 712323.78 11700.00 75.60 198.07 8784.07 8844.67 -4885.82 1594.74 -5039.84 29.28L 11.00 6.10 5944475.47 712292.68 11800.00 85.24 192.69 8800.70 8861.30 -4844.75 1499.80 -5065.89 28.381 11.00 6.14 5944379.82 712269.38 11846.14 89.71 190.28 8802.73 8863.33 -4822.76 1454.64 -5075.07 HS 1100 6.15 5944334.42 712261.51 11864.93 89.71 190.28 8802.83 8863.43 -4813.44 1436.15 -5078.42 90.28L 0.00 6.16 5944315.84 712258.69 11900.00 89.69 186.43 8803.01 8863.81 -4795.04 1401.46 -5083.52 90.261 11.00 6.17 5944281.02 712254.60 12000.00 88.65 175.43 8803.58 8864.18 -4732.11 1301.63 -5085.13 90.21 11.00 6.21 5944181.19 712255.88 12100.00 89.62 164.43 8804.23 8864.83 -4655.54 1203.33 -5067.67 90.131 11.00 6.24 5944083.43 712278.16 12200.00 89.80 153.43 8804.91 886551 -4568.15 1110.16 -5031.77 90.051 11.00 6.27 5943991.34 712314.73 Tat 1 12212.98 89.80 152.00 8805.00 8865.60 4556.20 1098.64 -5025.83 90.31L 11.00 6.28 5943980.00 712321.00 End Cry 12266.15 89.57 146.15 8805.39 8665.99 -4505.96 1053.04 -4998.51 HS 11.00 6.30 5943935.21 712349.62 12300.00 89.57 146.15 880564 8866.24 -4473.44 1024.92 -4979.65 HS 0.00 6.30 5943907.65 712369.28 12400.00 89.57 146.15 880639 8866.99 -4377.39 941.88 -4923.95 HS 0.00 6.31 5943826.25 712427.35 12500.00 89.57 146.15 8807.14 8867.74 -4281.34 858.83 -4868.25 HS 0.00 6.32 5943744.84 712485.42 12600.00 89.57 146.15 8807.89 8868.49 -4185.29 775.78 -4812.55 HS 0.00 6.33 5943663.44 712543.49 12700.00 89.57 146.15 8808.84 8869.24 -4089.24 692.73 -4756.85 HS 0.00 6.34 5943582.04 712601.56 12800.00 89.57 146.15 8809.39 8869.99 3993.19 809.69 -4701.14 HS 0.00 6.35 5943500.64 712659.63 12900.00 89.57 146.15 8810.14 8870.74 -3897.13 526.64 4645.44 HS 0.00 6.36 5943419.24 712717.70 13000.00 89.57 146.15 8810.89 8871.49 3801.08 443.59 -4589.74 HS 0.00 6.37 5843337.83 712775.77 13100.00 89.57 146.15 8811.64 8872.24 -3705.03 360.55 -4534.04 HS 0.00 6.38 5943256.43 712833.84 13200.00 89.57 146.15 8812.39 8872.99 3608.98 277.50 -4478.34 HS 0.00 6.39 5943175.03 712891.91 13300.00 89.57 146,15 8813.14 8873.74 -3512.93 194.45 4422.84 HS 0.00 6.39 5943093.63 712949.98 13400.00 89.57 146.15 8813.89 8874.49 -3416.88 111.40 -4366.94 HS 0.00 6.40 5943012.23 713008.06 13500.00 89.57 146.15 8814.64 8875.24 -3320.83 28.38 -4311.24 HS 0.00 8.41 5542930.82 713066.13 13600.00 89.57 148.15 815.39 8875.99 -3224.78 -54.69 -4255.54 HS 0.00 6.42 5942849.42 713124.20 13700.00 89.57 146.15 816.14 8876.74 -3128.73 -137.74 -4199.84 HS 0.00 6.43 5942768.02 713182.27 13800.00 89.57 148.15 816.89 8877.49 -3032.67 -220.79 -414414 HS 0.00 6.44 5942686.82 713240.34 13900.00 89.57 146.15 817.64 8878.24 -2936.62 -303.83 -4088.44 HS 0.00 6.45 5942605.21 713298.41 14000.00 89.57 146.15 818.39 8878.99 -2840.57 -386.88 -4032.73 HS 0.00 6.46 5942523.81 713356.48 14100.00 89.57 146.15 819.14 8879.74 -2744.52 -489.93 -3977.03 HS 0.00 6.46 5942442.41 713414.55 14200.00 89.57 146.15 819.89 8880.49 -2648.47 -552.97 3921.33 HS 0.00 6.47 5942381.01 713472.62 14300.00 89.57 14615 820.64 8881.24 -2552.42 836.02 -3865.63 HS 0.00 6.48 5942279.61 713530.69 14400.00 89.57 146.15 821.39 8881.99 -2456.37 -719.07 -3809.93 HS 0.00 6.49 5942198.20 713588.76 14500.00 89.57 146.15 822.14 8882.74 -2360.32 -802.12 -375423 HS 0.00 6.50 5942116.80 713646.83 14600.00 89.57 146.15 822.89 8883.49 -2264.27 885.16 -3698.53 HS 0.00 6.50 5942035.40 713704.90 14700.00 89.57 146.15 823.64 888424 -2188.21 -968.21 -3642.83 HS 0.00 8.51 5941954.00 713762.97 14800.00 89.57 146.15 824.39 8884.99 -2072.16 -1051.26 -3587.13 HS 0.00 6.52 5941872.60 713821.04 14900.00 89.57 146.15 825.14 8885.74 -1976.11 -1134.31 -3531.43 HS 0.00 6.53 5841791.19 713879.11 15000.00 89.57 146.15 825.89 8886.49 -1880.06 -1217.35 -3475.73 HS 0.00 6.54 5941709.79 713937.18 15100.00 89.57 148.15 826.64 8887.24 -1784.01 -1300.40 -3420.03 HS 0.00 6.54 5941828.39 713995.25 15200.00 89.57 146.15 827.39 8887.99 -1687.96 -1383.45 -3364.32 HS 0.00 6.55 5941546.99 714053.32 15300.00 89.57 146.15 828.14 8888.74 -1591.91 -1468.49 3308.82 HS 0.00 6.56 5941485.58 714111.39 15400.00 89.57 146.15 828.89 8889.49 -1495.86 -1549.54 -3252.92 HS 0.00 6.57 5941384.18 714169.46 15500.00 89.57 146.15 829.64 8890.24 -1399.81 -1632.59 -3197,22 HS 0.00 6.57 5941302.78 714227.53 15600.00 89.57 146.15 830.39 8890.99 -1303.75 -1715.64 -3141.52 HS 0.00 6.58 5941221.38 714285.80 15700.00 89.57 146.15 831.14 8891.74 -1207.70 -1798.68 -3085.82 HS 0.00 6.59 5941139.98 714343.67 15800.00 89.57 146.15 831.89 8892.49 -1111.65 -1881.73 -3030.12 HS 0.00 6.59 5941058.57 714401.74 TD 15814.22 89.57 146.15 832.00 • 8892.60 -1098.00 -1893.54 -3022.20 • 0.00 6.59 5941047.00 714410.00 Survey Type: Def Plan Drilling Office 2.6.1166.0 Prudhoe Bay Unit-EOA\DS-09\09-31\Plan 09-31D\09-31 D(P5c) 11/24/2014 11:09 AM Page 2 of 2 1 • . BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-31 Project: Prudhoe Bay ND Reference: 09310 plant§60.60usft(025 plan) Reference Site: PB DS 09 MD Reference: 09-31D plan a 60.60uslt(025 plan) Site Error: 0.00usf North Reference: True Reference Weil: 0931 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 100 sigma Reference Wellbore Plan 0931D Database: EDM RSK-Alaska PROD-ANCPI Reference Design Plan#81 09-3)0 Offset TVD Reference: Offset Datum Reference_._.--. Plan#8b 09-31D --._— .—_ , Fitter type: GLOBAL FILTER APPLIED:At weilpaths wither 200'+10011000 of reference lnserpolatlon Method: MD Interval 5.00uslt Error Model: ISCWSA Depth Range: 3,408.80 to 15,914.22us6 Scan Method: Tray.Cylinder North f Results Limited by: Maximum center-center dstance of 1,787.34usft Error Surface: Elliptical Conic I Survey Tod Program Dante 6.2412014 t 1 From To (weft) (unit) Survey(Wellbore) Tool Name Desaip ian 106.60 3,406.60 09-31 Srvy 1 BOSS-GYRO(0931) BOSS-GYRO Sperry-Sun BOSS gyro muttishot 3406.80 3,500.00 Plan#8b 09310(Plan 09-310) BOSS-GYRO Sperry-Sun BOSS gyro multishct 3,500.00 3900.00 Plan#81,09.310(Plan 09-31D) INC+TREND Inclinometer+known as trend 3,900.00 5.400.00 Plan#85 09310(Plan 09-310) MWD MWD-Standard 3,900.00 11,280.00 Plan#8b 09-310(Plan 09-310) MWD+IFR-.MS-WOCA MWD+IFR+Multi Station WAD Crustal 11,280.00 12,780.00 Plan#8b 0a-31D(Plan 09310) MWD MWD-Standard 11,280.00 15,914.22 Plan#Bb 09310(Plan 09-310) MWD+IFR+MS-WOCA MIND+IFR+Multi Stallion IMO Crustal 61242014 1005-56AM Pape 2 of 4 COMPASS 5000 I Bu k 1 6 r • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Wet 09-31 Project: Prudhoe Bay TVD Reference: 09-310 plan @ 60.60usft(025 plan) Reference Site: PB DS 09 MD Reference: 09-31 Dlam p @ 60.60usft(D25 plan) Site Error: 0.00usft North Reference: True Reference Well: 09-31 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1 00 sigma Reference Wellbore Plan 0931D Database: EDM R5K-Alaska PROD-ANCPI Reference Design: Plan loab 09-310 Offset TM Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning 'Site Name Depth Depth Distance (usft from Plan Offset Well-Wellbore-Design (usft) Cush) (usft) (usft) I PB DS 03 03.10-03-10-03.10 Out of range 03.27-03-27-03-.27 14,912.28 10,580.00 803.66 713.02 94.12 Pass-Major Risk PB DS 09 09-04-09.04-09.04 14,274.70 10,225.00 910.22 381.89 541.43 Pass-Major Risk r 09-04-09-04A-09-04A 14.638,15 9.900.00 1.169.65 325.65 946,11 Pass-Maior Risk 09-05-09.05-09-05 11,174.47 11,445.00 391.57 577.43 -12327 FAIL-Major Risk 09-05-09-OSA-09-05A 11,123.12 11,500.00 248.64 554.06 -244.48 FAIL-Major Risk 0914-09.14-09-14 5,098.10 5,685.00 264.44 223.83 173.38 Pass-Major Risk 09-16-09-16-09-16 13,245.89 , 11,690.00 823.18 495.83 350.75 Pass-Major Risk 09-26-09-26-09-26 Out of range 09-29-09-28-09-28 12,100.00 11,485.00 1,441.84 915.96 589.66 Pass-Major Risk 09-28-09-28A-09-28A 12,100.00 11,315.00 1,389.69 853.98 63127 Pass-Major Risk 09-29-09-29-09-29 12,67422 10,435.00 729.32 644.36 9849 Pass-Major Risk 09-30-09-30-09-30 9,700.00 8.590.00 1,508.54 965.34 1,214.90 Pass-Major Risk 09-30-09-30P81-09-30P81 9,700.00 8,590.00 1,508.54 965.34 1,214.90 Pass-Major Risk 09-31-09-31-09-31 3,506.60 3,500.00 0.05 249 -2.43 FAIL-Major Risk 09-31-09-31A-09-31A 3,505.80 3,500.00 0.03 2.63 -2.59 FAIL-Major Risk 09-31-09-318-09-318 3,505.60 3,500.00 0.03 2.30 -226 FAIL-Major Risk 0331-09-31C-09-31C 3,505.80 3,500.00 0.03 2.19 -2.15 FAIL-Major Risk 09-32-09-32-09-32 3,410.17 3,430.00 236.91 48.48 191.76 Pass-Major Risk 09-33-09-33-09-33 3,410.81 3,410.00 157.77 59.08 99.35 Pass-Major Risk 09-33-09-33A-09-33A 3,410.91 3,410.00 157.77 .59.09 99.35 Pass-Major Risk 09-34-09-34-09-34 3,411.06 3,420.00 29821 61.76 240.82 Pass-Major Risk 09-34-09-34A-09-34A 3,408.16 3,410.00 297.36 61.82 239.85 Pass-Major Risk 09-35-09-35-09-35 3,409.00 3,430.00 402.15 48.19 355.09 Pass-Major Risk 09-35-09-35A-09-35A 3,407.16 3,425.00 401.37 48-16 354.33 Pass-Major Risk 09-38-09-38-09-38 12,491.64 10,580.00 970.88 235.33 739.07 Pass-Major Risk 09-39-09-39-09-39 9,641.02 8,575.00 1,297.29 243.09 1,094.74 Pass-Major Risk 09-41-09-41-09-41 Out of range 09-42-09.42-09-42 3,410.51 3,760.00 1,517.69 75.50 1,450.38 Pass-Major Risk 09-42-09-42A-0942A 3,410.51 3,760.00 1,517.69 75.66 1,450.20 Pass-Major Risk 09-42-09-42AP81-09-42AP81 3,410.51 3,760.00 1,517.69 75.50 1,450.36 Pass-Major Risk 09-49-09-49-0949 3,410.83 3,490.00 381.45 73.36 320.01 Pass-Major Risk 6/24/2014 t4:o5.'5uM Page 3 of 4 COMPASS 5900(Build 61 e i • t • . 9 ssgssss10s1§11111 ti II111111111 S i - LL limgisimoggoII -""'1 s m� E-6:1 o oo e Lo,_ c A_ mmm�w 1 a / f a` 30 i� r um E 1'. t 5 a NEL^o f J '. Fa z,,2 / fN a 8�i'.rom® J//f $E $3 / Ru 1 111 illlllii _ ` ` Nr,,,, z. t s,� '1 98 . tom$ , r/ i a - s 2m`irl, I R' y !i 1 1 q` se e aaoaa ll Vair .7 I W N =.L 4 ia iX _-r.. M Si W OE g10 83a f. ' 5 ,— • • w g , � i i i i ggi H1HON 017 H11105 c ti Ct. d«a p a (1U ani. . , 0 • PARKER 273 BOP STACK NAM TVE 3CP DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE UC' 13 5/8"-514 I R. 13 5/8"-94 STUDDED TOP 13 5/8"-521 FLANGED BOTTOM !NW LAR BOP W/(2) 11" JL2 OPERATOR, UPPER CAVITY AND (2) '4" PSLX W/BSTR OPERATOR, 1W-ran ri fil ri'SAWPFPW 3H AFFER DJ 13 5/8"-54/ 13-5/8" 9.4 SlUDGEC TOP LOWER CAVITY o 13-5/8" 521 FLANGED BOTTOM 0 • I r___, DRILLING CROSS: I 1 13 5/8"-SM FLANGED TOP ...tff I 1 )-- )7. E 13 5/8'-SM FLANGED BOTTOM )1 101(2) 3 1/8"-514 SIDE OUTLETS Cr" .6 ":1- 2 _ _ 1 • 1 _ 'a .... II IE ) 3 1A - ' 2J!'''' - 11 I KILL LINE: 2-1/16" 50 FLEX HOSE ' I.; - •... 'AO jk -.------2-/i6 514 X 3-1/8" 5N C.S.A, 3-78- 51.1 FLANGED 4 ANUAL GATE VALVE --- ",-,_ - ---....J 3-ve. 5A. FLANGED 11 YDRALILJC GATE VALVE C -1113 am• .... _a • 3 f I CHOKE LINE: RAM TPE 30?- 3-1/8" 5M FLANGED MANUAL CATE VALVE SHAFFER LXT SINGLE 13 5/8" 5M 3-1/s" am FLANGED HYDRAULIC GATE VALVE 13 5/8"-504 STUDDED TOP 13 5/8"- 511.1 FLANGED BOTTOM .}-1/8" 5W FLEX HOSE w/(2; '4" JL2 OPERATOR 09-31Di PTD Page 16 11/20/2014 • • Loepp, Victoria T (DOA) From: Nocas, Noel <Noel.Nocas@bp.com> Sent: Tuesday, December 16, 2014 10:48 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU 09-31D(PTD 214-197)Anti-collision measures Victoria, 09-05 is plugged and abandoned as it is the parent for 09-05k 09-05A will be shut in at surface and also secured with a tested downhole plug. Thanks, Noel From: Loepp, Victoria T(DOA) [__mailtovictoria.loeppCa alaska.gov] Sent: Tuesday, December 16, 2014 10:02 AM To: Nocas, Noel Subject: PBU 09-31D(PTD 214-197) Anti-collision measures Noel, The anti-collision reports indicate major risk failures for 09-05 and 09-05k Please outline anti-collision mitigating measures for each failure that allows minor risking these wells. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loecoaa.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 1 S Davies, Stephen F (DOA) / /q7 From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Monday, December 08, 2014 1:49 PM To: Davies, Stephen F (DOA) Cc: Nocas, Noel Subject: FW: 09-31D Permit to Drill #213-092 cancellation Steve, Please let me know if you need anything else or have any additional questions.Victoria was out on vacation when I sent the initial request. Thanks! Joe From: Lastufka, Joseph N Sent: Monday, November 24, 2014 11:06 AM To: Victoria.Loepp@alaska.gov Subject: 09-31D Permit to Drill #213-092 cancellation Victoria, We will be submitting a new Permit to Drill for 09-31D due to the sundry expiration for Suspend and a change to the drilling plan. Please cancel PTD#213-092,we will submit a new sundry for Plug for Redrill of 09-31C(PTD#196-064)and new Permit to Drill for 09-31D. Please let me know if you have any questions. Thanks! Joe 1 • • At 7 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, December 04, 2014 10:04 AM To: Noel.nocas@bp.com Subject: FW: PBU 09-31D (PTD#213-092) Noel, I'd like to move this application forward in our review process. Does BP wish to cancel existing Permit#213-092 and replace it with this application? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, December 01, 2014 4:54 PM To: 'noel.nocas@bp.com' Subject: PBU 09-31D (PTD #213-092) Noel, I'm reviewing BP's application for PBU 09-31D that was received by the AOGCC on November 25th. The AOGCC approved a Permit to Drill (PTD#213-092) for that same well on July 26, 2013. Does BP wish to cancel Permit#213-092 and replace it with this application? Or is BP's current application simply considered a revision of that existing Permit? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If 1 • you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(a@alaska.gov. 2 i .:• -4. k \ \ .4\ ? e, , • 0 , „ . 1 , • 1 ' • Oil , . .. t " .. .. , , • ,., A 10 . ' .. i •.4'''.:3?:::' f N. ' ,! .. .4 ' 1 •. •• • ''. N '11 1 '' . ' lit " PISIP'-' < • / . ..... „ . . 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(.0 ..,-- ,-- , ...r.: 116. ,,: • Davies, Stephen F (DOA) From: Nocas, Noel <Noel.Nocas@bp.com> Sent: Tuesday, December 09, 2014 5:26 PM To: Davies, Stephen F (DOA) Subject: Re: PBU 09-31D (PTD#214-197) This well is not planned to be pre produced. There may be a temporary flowback or fill cleanout if needed. At this point no gas lift mandrels are planned to be installed. Thanks, Noel Sent from my iPhone On Dec 9, 2014, at 11:20 AM, Davies, Stephen F (DOA) <steve.davies@alaska.gov>wrote: Noel, One last question: will this injection well be pre-produced for an extended period of time (requires reporting of production to AOGCC), or will the well simply be flowed back for clean up? Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Nocas, Noel [mailto:Noel.Nocas@bp.com] Sent: Tuesday, December 09, 2014 9:55 AM To: Davies, Stephen F (DOA) Subject: RE: PBU 09-31D (PTD #214-197) Mud Weight Contingency Plans Stephen, Thanks for the question. Here is our mud plan for unexpected pressures. Intermediate hole: D Mud engineers and rig pit team should be especially vigilant to pit volumes during drilling operations.The mud will be weighted up just prior the THRZ depth.This minimum mud weight will be held from THRZ until liner is run to bottom, cemented &tested. D If weighting up is required,desired weight will be achieved with barite.To weight up the expected mud volume at TD(intermediate)of 1200 bbls a full pound per gallon would take 1482 sx(50#/sx) or 14 pallets. Mud engineers should have this quantity of weight material on location.To mitigate the risk of barite sag it is MISWACO's recommendation to use a bland spike fluid (no lubricants)to weight up. If Spike fluid mixing at the mud plant is not possible then consideration should be given to mixing this bland spike fluid (no lubes) on the rig. ➢ Although the mud plant will be utilized to mix any significant weighted mud required the mud engineer on the rig will have the required amount of weight up barite on location in case of road closures. 1 Production hole: ➢ If additional weighting up beyond the planned 8.6 ppg mud weight is required, desired weight will be achieved with Sodium Chloride (NaCl) salt up to 9.8 ppg. Beyond this point MI Swaco recommends additions of Calcium Carbonate.To weight up the expected mud volume at TD of 1000 bbls from 8.6 ppg to 9.8ppg would take 2022 sacks(50#/sx)of NaCI salt.To achieve an additional one half pound per gallon weight increase (10.3ppg)with Calcium Carbonate would take "831 sacks(50#/sx). Mud engineers will ensure at least this amount of Salt& Calcium Carbonate is on location during the interval. Barite should be used if further weighting up is required. ➢ The MI Swaco mud plant will be used to supply additional weight material as needed and maintains significant amounts of weight material to cover out of the ordinary weight up events. Let me know if you have any other questions. Thanks, Noel From: Davies, Stephen F (DOA) [mailto:steve.davies@ alaska.gov] Sent: Tuesday, December 09, 2014 9:45 AM To: Nocas, Noel Subject: PBU 09-31D (PTD #214-197) Mud Weight Contingency Plans Noel, If unexpected pressures are encountered while drilling PBU 03-91D, will BP have sufficient materials available at the wellsite to increase the mud weight? Please provide the details of BP's contingency plan. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. 2 • • 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: 7 PTD: 2—/4/ Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: POOL: g4t-i-Oteo-e..... j ( r4 ,Lx— R / `� Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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