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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 03-33C (PTD #2131720) will lapse on AOGCC MIT-IA Date:Tuesday, January 7, 2025 4:04:45 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, December 22, 2024 1:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: NOT OPERABLE: Injector 03-33C (PTD #2131720) will lapse on AOGCC MIT-IA Mr. Wallace, Injector 03-33C (PTD #2131720) is due for its 4-year AOGCC MIT-IA this month. The well is currently offline and will not be online before the end of the month. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate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y Anne Prysunka at 4:04 pm, Oct 04, 2022 'LJLWDOO\VLJQHGE\'DYLG%MRUN '1 FQ 'DYLG%MRUN RX 8VHUV 5HDVRQ ,DPDSSURYLQJWKLV GRFXPHQW 'DWH 'DYLG%MRUN MGR19OCT2022 RBDMS JSB 100622 DSr-10/4/22 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 03-33C Convert WAG to GI Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-172 50-029-21142-03-00 N/A ADL 0028327 14204 Surface Intermediate Liner Liner Liner 8986 2479 9569 7554 545 3712 12450 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 2-7/8" 8980 27 - 2506 25 - 9594 3018 - 10572 10391 - 10936 10488 - 14200 27 - 2505 25 - 8004 3016 - 8722 8589 - 8933 8660 - 8986 None 2670 4760 5410 7500 10530 12450, 13200, 13770 5380 6870 7240 8430 10160 12160 - 12280 4-1/2" 12.6# L-80 L-80 23 - 103958959 - 8971 Conductor 80 20" 29 - 109 29 - 109 1490 470 4-1/2" Baker S-3 Perm Packer 4-1/2" RED SPIDER VALVE SSSV 10338, 2206 8550, 2206 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 1:25 pm, Sep 30, 2021 321-519 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 10:12:50 -08'00' Bo York DSR-9/30/21 X 10-404 DLB 09/30/2021 MGR08OCT2021 dts 10/11/2021 JLC 10/11/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.11 13:31:22 -08'00' RBDMS HEW 10/12/2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:213-172 6.50-029-21142-03-00 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 14204 12450 8980 10338 None 12450, 13200, 13770 8550 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 29 - 109 29 - 109 1490 470 Surface 2477 13-3/8" 29 - 2506 29 - 2505 5380 2670 Intermediate 9567 9-5/8" 27 - 9594 27 - 8004 6870 4760 Liner 7554 7" 3018 - 10572 3016 - 8722 7240 5410 Liner 545 4-1/2" 10391 - 10936 8589 - 8933 8430 7500 Perforation Depth: Measured depth: 12160 - 14135 feet True vertical depth:8959 - 8986 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 25 - 10395 25 - 8591 10338 8550Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 3712 3-1/2" x 2-7/8" 10488 - 14200 8660 - 8986 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 246046800 022485 409 25253 0 2958 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:(406)570-9630 Treatment descriptions including volumes used and final pressure: 13. Sr Operations Manager Operations Performed1. Abandon Plug Perforations 5 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 measured8986 Sundry Number or N/A if C.O. Exempt: 320-490 4-1/2" RED SPIDER VALVE SSSV 2206 2206 Junk Packer Printed and Electronic Fracture Stimulation Data 5 CTU Extended 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 0028327 PBU 03-33C 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 5 By Samantha Carlisle at 11:58 am, Aug 23, 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: 2021.08.23 11:06:34 -08'00' Bo York DSR-8/23/21 SFD 8/24/2021 RBDMS HEW 8/25/2021 MGR01SEP2021 ACTIVITYDATE SUMMARY 5/5/2021 ***WELL INJECTING ON ARRIVAL*** TRAVEL TO LOCATION & R/U. ***WSR CONTINUED ON 5-6-21*** 5/6/2021 ***WSR CONTINUED FROM 5-5-21*** EQUALIZED & PULLED RED SPYDER VALVE (Ser# RS22) FROM 2206' MD. DRIFTED TO DEVIATION AT 11.011' W/ 2.25" CENTRALIZER & SAMPLE BAILER (empty) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 8/9/2021 T/I/O = 2900/1370/260. Temp = 126°. Bleed IAP to 500 psi (UIC). On MI. IA FL @ surface. Bled IAP to BT from 1370 psi to 430 psi in 15 min (Fluid, 1.5 bbls). OAP decreased 60 psi. Monitored for 30 min. IAP increased 40 psi to 470 psi, then decreased 10 psi to 460 psi. Final WHPs = 2900/460/200. SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:10 8/14/2021 CTU#6 1.75" CT Job Objective: Drift/Log, Set CIBP, Ext. Addperf MIRU CTU. MU & RIH with HES 2.20" logging carrier & 2.25" DJN. Log from 12700ft to 12000ft, POH. MU & RIH w/ NS 2-7/8" CIBP. Set CIBP at 12450' (Middle Element). Perform operational assurance MIT on CIBP - 1050psi - pass. POH. MU & RIH w/ HES 2" x 120' Millenium perf gun. ***Continued on 08/15/21*** 8/15/2021 CTU#6 1.75" CT Job Objective: Drift/Log, Set CIBP, Ext. Addperf Continue RIH w/ HES 2" Millenium perf gun. Tag CIBP, correct depth. Perforate 12,160' - 12280' using HES 2" Millennium 6spf perf guns. Pooh. Perform Injectivity Test with 1% kcl. Pumped at 1.0 bpm until 2000 psi reached then slowed to 0.6 bpm. Established injection rate of 0.6 bpm at ~1900 psi. Put 10 bbl meth ap on well. Turn over to Ops to POI. ***Jpb Complete*** 8/18/2021 ***WELL S/I ON ARRIAL***(sssv). RAN BRUSH, 3.79" GAUGE RING TO SSSV NIPPLE @ 2,206' MD. SET 4-1/2" RED SPIDER SSSV (ser # RS14) @ 2,206' MD. PERFORMED PASSING DRAW DOWN TEST. ***WELL LEFT S/I ON DEPARTURE, JOB COMPLETE*** Daily Report of Well Operations PBU 03-33C MEMORANDUM TO: Jim Regg l��Qlj P.I. Supervisor ( 1 FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 13, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 03-33C PRUDHOE BAY UNIT 03-33C Sre: Inspector Reviewed By: P.I. Supr<ff—v— Comm Well Name PRUDHOE BAY UNIT 03-33C API Well Number 50-029-21142-03-00 Inspector Name: Matt Herrera Permit Number: 213-172-0 Inspection Date: 12/7/2020 Insp Num: mitMFH2O1208161247 Rel Insp Num: Packer 03-33C Type Inj G TVD 2131720 Type Test ,1)1 Test psi Pumped: ;..I RBL Returned: vaIT— 4YRI I P/F I Notes: lepth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8550. Tubing 2025 2028. 2028 - 2027 - 2138 - IA 1 2657 - 2611- 2589• 4.1 - OA 25 _ 35 - 37 - 37 P ✓ Wednesday, January 13, 2021 Page 1 of I Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:213-172 6.API Number:50-029-21142-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028327 Property Designation (Lease Number):10. 341F 8. PBU 03-33C 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 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 14204 Effective Depth MD: L-80 11. 1/1/2021 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: 5OtherAlter 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" RED SPIDER VALVE SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8986 Effective Depth TVD:Plugs (MD):Junk (MD): 5Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 10338, 8550 2206, 2206 Date: Liner 3712 3-1/2" x 2-7/8" 10488 - 14200 8660 - 8986 10160 10530 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 29 - 109 27 - 9594 27 - 8004 14. Estimated Date for Commencing Operations: BOP Sketch 29 - 2506 Conductor 7240 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 12800 - 14135 8981 - 8986 4-1/2" 12.6#25 - 10395 Liner 13200 8979 13200, 13770 29 - 2505 2670 9-5/8" 7" Contact Phone:(406)570-9630 Date: 5410 2477 538013-3/8"Surface 4760 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 80 20"29 - 109 470 Intermediate 9567 6870 Liner 7554 3018 - 10572 3016 - 8722 545 4-1/2" 10391 - 10936 8589 - 8933 8430 7500 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst 1490 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 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. 2411 Extended Perf w/CTU, Acid By Samantha Carlisle at 9:11 am, Nov 17, 2020 320-490 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.11.16 18:25:24 -09'00' Bo York X DSR-11/17/2020 10-404 DLB11/17/2020MGR23NOV2020 Yesn Required? Comm 11/24/2020 dts 11/23/2020 JLC 11/24/2020 RBDMS HEW 11/25/2020 Extended Perforating Procedure To:Well Services Foreman Date:11/6/2020 AFE:2054318 From:Torin Roschinger IOR:100 Est. Cost:$160K Subject:03-33C Move MI Bulb, Perforate using Extended Perforating on CT and Contingent Acid Stimulation Revision: Sundry # Pending Job Sequence WBL Steps 1 Slickline Pull MCX, D&T. 2 Coil D&T, set CIBP at 12,450’ Shoot Addperfs from: x 12,160-12,280’ Contingent mud acid stimulation (if injection rates are lower than 2 bpm @ 2000 psi). See detailed program attached for acid job. 3 Slickline Set MCX at 2206’md, sized for 12mmscfd. Current Bottom Hole Pressure:3291 psi @ 8800’ TVD 7.2ppg | SBHPS taken 06/10/2017 Fracture Pressure:5785psi at 8900' TVD or .65psi/ft (12.5ppg EMW) Last SI WHP:1600psi on 01/16/2019 Min ID:2.370” ID 3-1/2”x2-7/8” XO @ 10,902’ MD Max Angle:94 Deg @ 11,060’ Reference Log:PDS Coil Flag June 15, 2015 H2S:No recent data (However MI has been known to be tested at ~150 ppm CT Size:1.75"The safety joint shall be the same OD as CT size referenced here. 03-33C Move MI Bulb, Perforate using Extended Perforating on CT and Contingent Acid Stimulation Well: 03-33C 2 Program Contacts: Contact Work Phone Mobile Phone Operations Engineer Torin Roschinger 406 570 9630 1 Scope of Work and Well Summary 03-33C is a MIST injector completed in 2014. Initially, the well was ready to be put on MI after it was drilled which was the plan. However, there was an issue with MI supply so the team decided to put the well on PWI. The well was on PWI, but it wasn't injecting at target injection rates, the reason for the low water injection rates were unknown. The team decided to get the injection rates up by re-perforating and perforating blank liner then following it up with an acid stimulation. The well was swapped from PWI to MI so it was never put back on PWI to see if the perforating and stimulation increased the injection rates on water. The well was placed on MI in May 2016 with injection rates of ~15mmscf/d. In January 2019, the second MI bulb targets were met and a plug and perf was performed to move up to the next bulb. 03-33C has been injecting MI and water in the current MIST location since early 2019 and it has exceeded the optimum injection volume for MIST wells, and offset producer response indicate it is time to change the MIST injection location. Historically, MIST wells had poor injectivity post perforating, so an injectivity test with a contingent acid stim is proposed for this wellwork. This new bulb should continue to support offset producers 03-30, 03-35, 03-03,09-03 and 09- 01A. Target MI Rate: 12 mmscf/day 2 Sundry Procedure (Approval Required to Proceed): Slickline 1. Pull MCX Coiled Tubing (Reference Coiled Tubing Extended Perforating Recommended Practice) 2. MIRU Coiled Tubing Unit 3. MU and RIH with logging and drift assembly. a. Kill well with 1.5x WBV to top perf. Note: 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. 4. Paint flag, POOH and confirm good data. 5. Set CIBP @ 12450’md and POOH. 6. Monitor WHP to confirm well is dead before MU perf guns. If necessary, re-kill well. 7. Pickup 1.75” 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. 8. Break lubricator connection at QTS and begin MU perf guns per the following table (If at any time pressure is seen or there is flow at surface follow the steps in the Standing Orders Appendix E to secure the well): Table 1: 03-33C Proposed Extended Length Gun Runs Well: 03-33C 3 Gun Run # Perf Top Perf Bottom Perf Length Overall Gun Length Weight of Perf Gun (lbs) 1 12,160 12280 120 120 670 9. RIH with perf gun(s), tie-in and perforate. POOH. a. Note any tubing pressure changes in WSR. b. Perform injectivity test as follows, record in AWGRS and notify OE of results prior to moving forward with acid treatment. Target Inj rate is >2bpm at 2000psi. Fluid Volume (bbls)Rate (bpm)Comments 1% KCL 2.5 0.5 If required, adjust volumes so length of test is 5 minutes. 1% KCL 5 1 If required, adjust volumes so length of test is 5 minutes. 1% KCL 7.5 1.5 If required, adjust volumes so length of test is 5 minutes. 1% KCL 10 2 If required, adjust volumes so length of test is 5 minutes. 1% KCL 12.5 2.5 If required, adjust volumes so length of test is 5 minutes. 1% KCL 15 3 If required, adjust volumes so length of test is 5 minutes. 10. Once at surface, stop to confirm well is dead. 11. Review Standing Orders (Appendix E) prior to breaking lubricator connection and rigging down guns. 12. Pending injectivity rate, perform acid treatment (see acid procedure). 13. FP well. RDMO. Slickline 1. Set MCX at 2206’md. Target MCX for 12mmscfd. Attachments: A. Current Schematic B. Proposed Schematic C. Coiled Tubing BOP Schematic / Tree Diagram D. Equipment Layout Diagram E. Standing Orders for Open Hole Well Control during Perf Gun Deployment F. Minilog / Tie In Log / Perf Sheet Well: 03-33C 4 Appendix A - Current Wellbore Configuration Well: 03-33C 5 Appendix B: Proposed Schematic Well: 03-33C 6 Appendix C: Coiled Tubing BOP Schematic / Tree Diagram Well: 03-33C 7 Appendix D: Extended Perforating Equipment Layout Well: 03-33C 8 Appendix E: Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: 03-33C 9 Appendix F: Minilog / Tie-In Log / Perf Sheet Well: 03-33C 10 Well: 03-33C 11 Well: 03-33C 12 Well: 03-33C 13 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: November 12, 2020Subject: Changes to Approved Sundry Procedure for Well 03-33CSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Farm 10-404 Revised 04/2017 I'&Aw19JWJ- RBDMSN—T LD 02019 Submit Original Only 1. Operations Performed Abandon ❑ Plug Perforations RI Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate a Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Mud Acid - MIST Injector 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 11 Exploratory ❑ 5. Permit to Drill Number: 213-172 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 Stratigrephic ❑ Service ® 1 6. API Number: 50-029-21142-03-00 7. Property Designation (Lease Number): ADL 028327 8. Well Name and Number: PBU 03-33C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 14204 feet Plugs measured 13200, 13770 feet true vertical 8986 feet Junk measured None feet Effective Depth: measured 13200 feet Packer measured 10338 feet true vertical 8979 feet Packer true vertical 8550 fee Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 29-109 29-109 1490 470 Surface 2477 13-3/8" 29-2506 29-2505 5380 2670 Intermediate 9567 9-5/8" 27-9594 27-8004 6870 4760 Liner 9554 7" 3018-10572 3016-8722 7240 5410 Liner 545 4-1/2" 10391 - 10936 8589-8933 8430 7500 Liner 3712 3-1/2" x 2-7/8" 10488 - 14200 8660-8986 10159 110566 10533 / 11165 Perforation Depth: Measured depth: 12800 - 14085 feel True vertical depth: 8981 -8986 feet Tubing (size, glade, measured and true vertical depth) 4-1/2" 12.6# L-80 25-10395 25-8592 Packers and SSSV (type, measured and 4-1/7 Baker S-3 Perm Packer 10338 8550 true vertical depth) 4-1/7 HES Red Spider SSSV 2206 2206 12. Stimulation or cement squeeze summary: Close choke 8 pump Acid Stim per program reciprocating across perfs. Pull above TOL and pumped overflush w/ NH4CL. Pumped at 1.8 bpm at 687 psi. Overflush with 239 bbis NH4CL. Intervals treated (measured): 12800 -12928 Treatment descriptions including volumes used and final pressure: 75 obis 12% HCL Acid, 75 bbls 9:1 Mud Acid Final Pressures: OA = 0 psi, IA = 0 psi, TBG = 3050 psi 13_ Representative Daily Average Production or Injection Data Oil-BbI Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well Operation: 0 21929 0 400 3050 Subsequent to operation: Shut -In 0 3050 14. Attachments: Irenared per 20 nnc 25 070 a 25.2831 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service 0 Stretigraphic ❑ Copies of Logs and Surveys Run O 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG m GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318.323 Authorized Name: Summers, Matthew Contact Name: Summers, Matthew Authorized Title: Production Engineer Contact Email: Matthew.Summers@bp.com Authorized Signature: .-� Date: 9 Contac) Phone: +1 9075845086 Farm 10-404 Revised 04/2017 I'&Aw19JWJ- RBDMSN—T LD 02019 Submit Original Only Daily Report of Well Operations PBU 03-33C ACTIV1TVnATF CI IRARAARV ***WELL INJECTING ON ARRIVAL***(profile mod) EQUALIZED AND PULLED 4-1/2" RED SPIDER SSSV (ser# RP19) FROM 2206' MD. 9/21/2018 ***CONT ON 9-22-18 WSR*** ***CONT FROM 9-21-18 WSR***(Profile Mod) DRIFTED WITH 2.25" CENT AND 1.5" SBLR(empty) TO DEVIATION AT 10,940' SLM. 9/22/2018 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** CTU#8 1.75" CT. Job Scope: Depth Log, Adperf, Mill/Set CIBP. MIRU CTU. Perform Weekly BOP Test. MU & RIH w/ PDS 2.20" Logging Carrier & 2.31" JSN. 1/16/2019 ***Continue Job on 1/17/19 WSR*** CTU#8 1.75" CT. Job Scope: Depth Log, Adperf, Mill/Set CIBP. Resume RIH w/ PDS 2.20" Logging Carrier & 2.31" JSN. Tag at 13434'. Unable to get past. PUH. Log up at 60 fpm from 13200'- 10250'. Flag coil at 13000'. Pooh. Contact APE and change job scope to not mill out existing CIBP Tie in to PDS Coil Flag dated 15 -June -2015., (+13' correction). MU & Rih w/ 2.20" Baker CIBP. Correct depth at flag. Set top of plug at 13200'. Confirm plug set. Pooh. MU & Rlh w/ SLB 2" x 32' PJO Perf Gun #1. Tag CIBP, correct depth. Perforate with gun #1 from 12,896- 12,928'. Pooh. 1/17/2019 "Continued on 1/18/19 WSR** CTU#8 1.75" CT. Job Scope: Depth Log, Adperf, Mill/Set CIBP. Trim 100' of pipe for CR management. Change packoffs. MU & RIH w/ SLB 2" x 32' PJO Perf Gun #2. Tag CIBP, correct depth. Perforate 12864'- 12896'. Pooh. All shots fired, ball recovered. MU & RIH w/ SLB 2" x 32' PJO Perf Gun #3. Tag CIBP, correct depth. Perforate 12832'- 12864'. Pooh. All shots fired, ball recovered. 1/18/2019 **Continued on 1/19/19 WSR** CTU#8 1.75" CT. Job Scope: Depth Log, Adperf, Mill/Set CIBP. MU & RIH w/ SLB 2" x 32' PJO Perf Gun #4. Tag CIBP, correct depth. Perforate 12800'- 12832'. Park above TOL Perform Injectivity Test with 1% kcl w/ safelube. Pump 1.0 bpm until Whp reached 2000 psi then slowed rate to —0.7 bpm. Injectivity criteria not met. Trim 100' of pipe. Change packoffs. MU & Rih w/ 2.0" JSN BHA. Tag plug., circulate NH4CL. 1/19/2019 ***Continue on 1/20/2019 WSR*** CTU#8 1.75" CT. Job Scope: Depth Log, Adperf, Mill/Set CIBP. Close choke & pump Acid Stim per program reciprocating across perfs. Pull above TOL and pumped over8ush w/ NH4CL. Pumped at 1.8 bpm at 687 psi. Overflush with 239 bbls NH4CL. Freeze protect well w/ 60/40 methanol to 2500' tvd. RDMOL 1/20/2019 ***Job Complete*** ***WELL S/I ON ARRIVAL*** (Profile Modification) RAN 3.84" NO-GO & 4-1/2" BRUSH TO X -NIP @ 2,206' MD. SET 4-1/2" RED SPIDER VALVE (RS22) IN X -NIP @ 2,206' MD. RAN 4-1/2" CHECK SET TO TOP OF X -LOCK AT2206' MD (Check set sheared). 1/24/2019 ***JOB COMPLETED, WELL LEFT S/I*** STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations m 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:Set CIBP-Acid Stim l I 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 213-172 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-21142-03-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number PBU 03-33C 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: RE CE EVE E D Total Depth: measured 14204 feet Plugs measured 13770 feet 1 0 q true vertical 8986 feet Junk measured feet N� V 3 201,E Effective Depth: measured 13770 feet Packer measured 10336 feet true vertical 8987 feet Packer true vertical 8549 feet GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 2475 13-3/8"72#L-80 28-2503 28-2503 4930 2670 Intermediate 9565 9-5/8"47#L-80 27-9592 27-8002 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 13368-13464 feet 13985-14010 feet 14010-14035 feet 14035-14060 feet 14060-14085 feet 14085-14135 feet True vertical depth: 8982-8982 feet feet 8985-8985 feet 8985-8985 feet 8985-8985 feet 8985-8985 feet 8985-8986 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-10393 25-8590 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSSV 2204 2204 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED DEC 1 2017 13368'-13464' SCANNED U ! Treatment descriptions including volumes used and final pressure: 163 Bbls Diesel,490 Bbls 3%NH4CL w/F-103&SafeLube,200 Bbls 1%Slick KCL,25 Bbls 60/40 Methanol/Water,100 Bbls Fresh Water,110 Bbls 12%HCL Acid,110 9:1 Mud Acid,527 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -2936 20 3319 Subsequent to operation: -24312 450 3022 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service H 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: 317-444 Authorized Name: Chamansingh,Ann Marie Contact Name: Chamansingh,Ann Marie Authorized Title: Petro um Engineer Contact Email: AnnMarie.Chamansingh@bp.co Authorized Signature:.y�t '/ol PiCietry-ovielDate:i4120 Contact Phone: +1 9075644070 Form 10-404 Revised 04/2017 V*re-- 27 71/,7-- ` !,7-- RBDfiOS Vv ku' 3� r� Submit Original Only 'Lq' //7 2017 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary November 28, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Cast Iron Bridge Plug, Addition of Perforations and Acid Stimulation covered under Sundry Approval # 317-444 for Well 03-33C, PTD # 213-172. 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 1111/ • o 0 0 0 0 0 2 2 0 (13 g? LO r- CD Ln m V v U CD co L 01 O O o ov O o CD 3 d C)) 00 N N 0 0 m V CO N. I� Cn CD CD 00 O M N c- v- M M CO O O O O O N M N 00 CA LO O CD N- C) O) 0) U) N CO CO CO CO CO CO CI I II I I II f- Nr Nr r- O M CA OO N. <- CA 00 CO N LC) N N N O 00 LC) CO CT N 00 N- 00 00 CO iJ CD O CO N O M OO O LO N- M O O CA O s O . Ln CD CA N M N O 0 0 0 0 V' O t 0 U I I I I I Q M O O) co N M CA 00 N- v- "Cr O 00 O O M N N N O Cr O O O N OM CA a- c- r- M co O O L1) O Q. O co O CO OD a0 00 co O J M co N N J J • # # 0, N'sV N V' C\ CU CO COV CO _ O) CO _ U N CA ' co N O +' Ln Ln Ln 00 CO Cp O ti CO M N Ln CA O C 00 CB 'Zr CA CSO c- Ll V M CD J CC W C0 Q W Z. U U Z W W W W W W () pH Z Z Z Z Z D 0 U) z J J J J J F- • S Packers and SSV's Attachment PBU 03-33C SW Name Type MD TVD Depscription 03-33C SSSV 2204 2203.9 4-1/2" MCX I-SSSV 03-33C PACKER 3016.43 3014.06 7" Baker ZXP Top Packer 03-33C PACKER 9441.63 7893.86 7" Baker ZXP Top Packer 03-33C TBG PACKER 10336 8548.84 4-1/2" Baker S-3 Perm Packer 03-33C PACKER 10400.4 8595.69 5" Baker ZXP Top Packer • 0 DUH C Z =-E, O (o o LO - p M ` (D w o = 0 c o -o aa) coo N- .° '0 p O Q. O uc°i p a) a) a o - o = co -§ H C CI- N a) Cr „,° > a 2 �(75 0 Q . NO 0)M V a) Q' p a Lo o Q_ a) a) C M L- a).a) p v m a) Q (a U ,C C aj co 0 L () . 0 L2NQ_ E co N 3 0 O L.L Q O O m ` _>' 11 E E o N ° X - a) E M U `t 5 E •> E a) E Q w c MN2 u) _ O � CT) (n VL >., v) 3 O 2 O ~ (n "ALU 0 ca �O 70 .O > 70 U N CO U U (o (a LL w O y L Lco ~ - U C w U N o Q Q > Q ..- O ori Q - o U Q o N C C O ._ D C C C _ J * O o O �2 2 O 7 .a Q_ o 0 E 0 0 N O a) U 2 D)U 0 N 0) 0 0) Y •� 0 o f U o 03 �' 3 `� t N O O ,t p O a O L a 't -0 '- `t 't LL a) ❑- y p Q Q L O V O Q (A Op p L co QL co d Q= N _ O O. -O o � 15 (.0 coC � L _ (n 0)Q Q g ` -0 Q Q- a) (n Q C Q O @� �+ r• Y [t S m O C 0 L X _ 0) a) c0 c0 -- O C �_ i Q itLQ- aZ p O N amO oN - C Q_ Q0 a Q_ Q. 0Z Q w z), 3 UQQ --O UU a) Q- L -0 0 U 73 .(L) U p 0X — C47 w o &) i • • 0 2 { / ƒ (N H @ \ \ in 0 c Z EL CO csj- E C 73 \ - 2 � \ § D \ E o 3 « m ® R R 0 U0 in / \ e 9 -oO 2 0 el f = m 2 ƒ + § ± Co r = — o = 4� �\ o 0- \ f 0 / a. '— m > E ° @ ,--.1.) § O 0 / CL Q cn R 3 e ) � » > \ ƒ / m m a co _ \ k f ƒ 7 / / \ / f co © i ® \ u a o 2 -/ _ - w , 0 O \ / G < f A e 5 2 '- '- � ƒ ff \ \ \ / \ O• HZ -di c) ! ± < - + a y y@ « m \ 2 ! m CC ! 0 e T- T- 0 $ ± — 6 N- „--- = r v- o 0 0 0 0 0 0 # 2 0 » = o A o o r T- E r & & & = # 11111 TREE= 4-1/16"CNV IP NOTES: WE3.1.WELLHEAD= hit 03-33C DAFETY ES *@ 11060'. HRS REAS ELDINGS AVERAGE ACTUATOR= BAKER C 125 ppm WHEN ON MI**'WELL REQUIRES A SSSV fI W L KB.B_E 62' 1 I WHEN ON MI"'SEE PG.2 FOR PBNIOUS BF.EEV= 27.89 I WELL BORE'**CHROME LNR"'* KOP= 2850' Max Angle= 94°@ 11030' 20'OONDJCTOR 110' Datum MD= 10762' {._._._2206` IH4-1/2"HES X NP,D=3.813', Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" 2506' TOP OF 7"SCAB LNR 3018' 3018' _-19-5/8"X 7"BKR ZXP LTP,D=6.290" .` •" 3036' -19-518"X 7'BKR FLEX-LOCK HGR,D=6.310" Minimum ID =2.370" @ 10902' 3-1/2" X 2-7/8" XO PIN ' '� •� 9444' -9-5/8"X 7'BKR C-2 ZXP LTP& 7'SCAB LW,26#,L-80,BTC-M, - 94553' Ii j� TRACK SEAL ASSY,O=6.151' .0383 bpf,D=6.276" 4�1 4' 9461' -{9-5/8"X7"BKR FMC HGR,D=6280" 9-5/8"WHIPSTOCK(03112/05) - 9594' I. 9-5/8"CSG,47#, L-80,D=8.681" -9594 MI.LOUT WPDOW(03-33B)9594'-9622' 10317' H4-1/2"HES X Pi?D=3.813" '-1 10338' H7"X 4-1/2"BKR S-3 FREYA FKR D=3.875" 10362' -{4-1/2"HES X PP,D=3.813' I10383' -14-1/2"FES XN NIP,D=3.725' -7'X 5"BKR ZXP LTP w MEBK,D=4.450" - 4112"TBG,12.6#,L-80 TC-11,.0152 bpf,0=3.958" 10395' I 10391' 1 i 10395' -4-112"WLEG,D=3.958" 10409' 7"X 5"BKR i-MC HY DRO HGR,D=4.430" 10417' -15"X4-1/2"XO,D=3.980" TOP OF 3-1/2"X 2-7/8'LNR ( 10488' 011 1 10488' H3.70-BKR DEPLOY SLV,D=3.00" 7"LNR,26#,L-80,BTGM1,.0383 bpf,D ...,,,A=6.276" 10572' . 10509' -13.1/2"HES X NP,13=2.813" 3.1/2'LNR,9.2#,13CR-85 STL.0087 bpf,D=2.992' 10902' 411 4-1/2"FKR WHIPSTOCK(02/20/14) H 10935' 4 10902' -3-1/2"X 2-7/8"XO,13=2.370" 4-1/7 LW, 12.60,L-80 BT-M,.0152 bpf,0=3.958" -10936' 4-1/2"CRP(02/04114) --111050 MLLOUT WNDOW(03-33C) 10936'-10946' M' *.:1; PERFORATION SUMMARY 11409' -12-7/8"PUP MICR JT w/TRA TAC(03104114) REF LOG. ON XX/XX/14 ANGLE AT TOP PERF:90'@ 13368' 41.4:0:4124:.: 12655' -j 2-7/8"PUP M'(R JT w/RA TAG(03/04/14) Refer to Production DB for historical perf data PBTD -I 14162' SIZE SPF UffB?1AL Opn/Sqz SHOT SOZ • 7 6 13368-13464 0 11/10/17 2" 6 13985-14010 C 06/19/15 .''„ -;LsP k4 ' i, pv 2' 6 14010- 14035 C 06/17/15 ►!� 2-7/8"WFTCBP(11/09/17) 13770'CTM 2" 6 14035-14135 C 03/07/14 __.____ 2" 6 14035-14060 C 06/16/15 2-7/8'LPR,6.40,13CR 85 STL,.0058 bpf,D=2.441" -L 14200' � 2" 6 14060-14085 C 06/16/15 ..__..........._........_ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT 03/01/86 INITIAL COMPLETION 11/15/17 MSS/JM)SET CBRADPBRFS W8 L: 03-33C 04/30197 SIDETRACK(03-33A) PERMIT No: 2131720 03123/05 WES SIDETRACK(03-338) API Nb: 50-029-21142-03 03/08/14 NORDIC1 CTD SIDETRACK(03-33C) SEC 11,T10N,R15E,214'FSL&827 FWL 04/04/14 TB/JMD FINAL ODE APPROVAL 04/04/14 TB/JM3 FINAL ODE APPROVAL BP Exploration(Alaska) • %,Or Tkr • % ,,�,, THE STATE Alaska Oil and Gas tib. Of LAsKA Conse2vati®n Commission s _ } 333 West Seventh Avenue GOVERN®R BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 SFA 5� Fax: 907.276.7542 www.aogcc.alaska.gov Ann Marie Chamansingh Petroleum Engineer BP Exploration(Alaska), Inc. SCANNED NOV [i b 2118 PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-33C Permit to Drill Number: 213-172 Sundry Number: 317-444 Dear Ms. Chamansingh: 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, Ca3rNr\ Hollis S. French Chair k- DATED this Z�1 day of September, 2017. RBEMS � OCT - 3 2017 • RECEIVED • STATE OF ALASKA SEP 1 g 7017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1. Type of Request: Abandon 0 Plug Perforations p • Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0, Other Stimulate ® Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other a c ic4 S t/ Er- 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 213-172 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic ❑ Service IEI. 6. API Number. 50-029-21142-03-00 • 7. If perforating: 341F • 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 Ed PBU 03-33C • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028327 • 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): 14204 8986 14162 8986 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 2475 13-3/8"72#L-80 28-2503 28-2503 4930 2670 Intermediate 9565 9-5/8"47#L-80 27-9592 27-8002 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): 13985-14135 8985.48-8985.77 4-1/2"12.6#L-80 L-80 25-10393 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"MCX I-SSV 2204, 2204.39 12.Attachments: Proposal Summary 0 Wellbore Schematic Ezf 13.Well Class after proposed work: Detailed Operations Program IRI BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service Iii • 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 Ef ' GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Chamansingh,Ann Marie be deviated from without prior written approval. Contact Email: AnnMarie.Chamansingh@bp.com Authorized Name: Chamansingh,Ann Marie Contact Phone: +1 9075644070 Authorized Title: Petroleum Engineer�� Authorized Signature: ti.e c.in/tioww...„6t. Date: `;r'•te-.2.011 1 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number 31-7-1-fi-fq Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other. / Post Initial Injection MIT Req'd? Yes 0 No E—jf Spacing Exception Required? Yes 0 No Lif Subsequent Form Required: /0 4°4- Approved by: /` - APPROVED BYTHE COMMISSIONER COMMISSION Date: Ilq l 1 v`ri_. 9/ 8"/!9- Ofd . LINAL 5t , C 9),,3 7 2. 20 17 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue RECEIVED Anchorage, AK 99501-3572 SEP 1 9 2017 RE: BP Exploration (Alaska), Inc. AOGCC Application for Sundry Approval (10-403) September 15, 2017 To Whom it May Concern: Attached please find the Sundry Application for Setting of a Plug, Addition of Perforations and Contingent Acid Stimulation for Well 03-33C, PTD # 213-172. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD, EAZ, BPG 10/12/15) General Information Well Name: 03-33C Well Type: WAG Injection Well API Number: 50-029-21142-03 Well Activity Conventional 4 Classification: Activity Description: MIST stage plug/pert Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Ann-Marie Chamansingh Contact numbers: (907)564-4070 (907)297-9510 Well Intervention Engineer: Todd Sidoti Contact numbers: (907)564-5113 (907)632-4113 Lead Engineer: Bernhard Stechauner Contact numbers: (907)564-4594 (907)360-7485 Date Created: September 12, 2017 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Choke Setting Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (%) (Mscf/Day) Y) (Psi) 9/10/2017 0 17,011 3.160 Current Status: Operable , Flowing Inclination>70°at Depth(ft) 10,909'MD Recent H2S (date,ppm) NA 0 ppm Maximum Deviation(Angle and 11.060'MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 44° 11,060'MD Reservoir pressure(date, psig) 6/10/2017 3,291 psi Minimum ID and Depth 2.370" 10,902'MD Reservoir Temp,F 178° F Shut-in Wellhead Pressure Known mech. integrity None problems(specifics) Last downhole operation(date,operation) 11/30/2016 SL pulled MCX Most recent TD tag(date,depth, DRIFT TO DEVIATION AT 10,988'SLM W/2.25"CENT. toolstring OD) 06/202015 10.988'MD SAMPLE BAILER Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, MIST injector completed in 2014 Initially. the well was ready to be put on MI after it was drilled which was background information, the plan. However. there was an issue with MI supply so the team decided to put the well on PWI. The etc: well was on PWI but it wasn't injecting a target injection rates the reason for the low water injection rates were unknown. The team decided to get the injection rates up by re-perforating and perforating blank liner - then following it up with an acid stimulation The well was swapped from PWI to MI so it was never put back on PWI to see if the perforating and stimulation increased the injection rates on water. The well was placed on MI in May 2016 of current injection rates of-15mmscf/d. 03-33C has been injecting MI and water in the current MIST location since 2016 and it is time to move uphole for the next bulb Historically MI wells and this well has had poor injectivity post perforating. so an injectivity test with a contingent acid stim is proposed for this wellwork. This new bulb should continue to support offset producers 03-30, 03-35, 03-03.09-03 and 09-01A. Target MI Rate 20 mmscf/day • • 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%. 3.Does the planned equipment to be installed in the well meet the requirements of the GWO Well Equipment Group Practice,GP 100220(AKA 10-50),by either being documented as Legacy Equipment or having the required design assurance work completed?https://gwo.bpglobal.com/sitesigwo2/GlobalLibrary/100220.pdf Suspected Well Problem: 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: Restrict access to high pressureum in area to p P 9 1 Pumping acid essential personnel only. Notify DSO and any others affected by acid pumping operations prior to moving acid. 2 Unable to reach 2 bpm or greater injectivity at 2000 psi Pump acid stimulation per program as a contingency 3 Perf Gun Optimisation Job assumes gun length of 32ft to be used,if not make 4 runs with 25'guns. Summary Step# Service Line Activity 1 S Pull ISSSV 2 C D&T Set CIBP @ 13770ft MD and add perf as perforating program. Perform Injectivity test. 2.1 C(Contingent) Contingent mud acid stimulation(If injection rates are lower than 2 bpm @ 2000 psi). See detailed program attached for acid job. 3 S Set MCX at 2206'MD 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 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production BOPD: NA MMSCFD: 20 BWPD: NA Rates: FTP(psi): NA Choke setting: NA PI(bfpd/psi dp) Post job POP instructions: Do not put on water injection Place on MI once completed at 20mmscf/d. 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 • • MI Injector N1 In dog .. recni Pee,ee° OS O OS 03 Mimics Ltode*2011 VVeIt: 03-33C a J>rC.F Laurin j.LaMar ,., IlliZ017 $4,k# !i#tii ii , .re.. ..t...; i4i x YirF. ,VP ,4204 , a ;r,a#/?,;,,,,,.. P.0 -sa.s., e1'9} X ..e F3 ._____ i - Et+iR7 ....BE AlSMAL ,ucrss! l PE Info ax OWMM,1 , it ,.At3 r_ I I (/[[al;t[rrY ;rex.fb` 6fST,IkDE€ r ring[[F 1:4000 OO` s- , i 84517 f1 SS75 C 7 OHMM --- r now $ t , . d , x i t L { .., toss ION nos . - -40011=1111. Imo i . L il10 1, 0995 • j 0970 1 11 . lie , w ...-- At . 1: a Vfts lifil Add perf-13,370ft-13466ft t is vim _ - Plug Set @13770ft MD L.,,,,„„„, !PIM i , 3003 t 111 1 i 1 • Schlumberger Company: BP Exploration (Alaska), Inc. FINAL Well: 03-33C Field: Prudhoe Bay Borough: North Slope State: Alaska Memory Cement Bond Log - PSP — GR/CCL/CBL/VOL M y 19—Apr-2014 cs m 214.32'FSL&820.35'FWL Elev.: K.B. a) rs -I z At Surface G.L. o' m co O ei tip Q ; H D.F. 56.39 ft . /. CO X o -- �' - O Permanent Datum: MSL Elev.: 0.00 ft z a - - m - Log Measured From RT 56.39 ft above Perm.Datum _ s = ? Drilling Measured From: RT cri o ti 2 o API Serial No. Section Township Range m Ll. -1 5 C% 50-029-21142-03 11 10N 15E Logging Date 19-Apr-2014 Run Number 1 Depth Driller 14162 ft Schlumberger Depth TD Not Tagged Bottom Log Interval 14052 ft Top Log Interval 10408 ft Casing Fluid Type 3%NI-14C1 Salinity Density 8.6 Ibm/gal Fluid Level BIT/CASING/TUBING STRING Bit Size From To Casing/Tubing Size 2.875 in Weight 6.4 ibmitt Grade 13CR-85 From 10902 ft To 14200 ft Maximum Recorded Temperatures i Logger On Bottom i Time 19-Apr-2014 14:20 Unit Number j Location 7889 1 Prudhoe Bay Recorded ByMontgomery Witnessed By I Atkinson/Roschinger r , _ 1.---i- __ .„_�. i i . • • : 10-1 11 l 1 i i tdiiiiim; , -- .. i Ir ` ffl,. I i linliimM (�� ' :. , , . - ,-7-7: -__f_ Iii ilii. 13700 ! Ii 1 I 3 1 _ : !MIMI!iiiiiii 'n� . t i i� 1J�� -.Ili , ;.. moribp i , ,i i 111 "1"",----7--7.7-, i mo-- ji . 3 ` Set Plug @ aim 13770 ft MD Ij- " - I f21 i 1 t 7....:. ti I ! ; 1 l v 0 • r� -- Ti-4101:4 - - z; �! I_I ME - - - , I ,_— 13300 it -_ - e I. . , „,. ■ _._/- LIM111111,7+._ 7,_____„.. 1_ ��11111111E - ;._;,. ;, Iii 1 V.4, � a einbili -A.1 . ,.,,...i,..k ii ,. . . ..•,. • 7 ig �r_- f ...,..... — ,,,,,,,„.s.,,, ,,,,,,,, , , ,,,,, , !:4,..,.„Iiiiiiiig t A 11111111111111111111 1i11 — i ' '..i.'.., ' ! { '241i': .f w „ , ��1��� .c�fr` a. # =b -,..„.,,,,.,...saqa,”`,,,,..1,...1 I ji 1 JI ■ ■l��M.E 14 „, � milmasm a.�1� �FI ;:.....!®11111 �_ Add pert 1. .. �AMR's_ 13,370ft-13466ft t .:. 111111 :, ,..'f.:ifil,;:::' 1 ,... 1 r , ,,- ..-.4. -----• sum...= iT:,..,7 ,. t ,.____________wi_,,..- EiliIH4,.... .. , ,,,i7..,,, ., r ..z.,..•,,4,...,,itlItt,1 „ , ,.- k • • m Q.000000Oi° o COVr V co CD CD CD CD C3 C3 C) co - O co i- 1 d' O O MO V' C)) co N N m Nr CO N- N- CO cp 00 O 00 N •- co M CO O O 0 0 0 N M N CO C3) CC) O O) N- O O C)) CC) O N- co co 00 O co F- V V N- O 00 CD CO Ns c- C7) 00 CO N LC) N N N O co O CO C7) N CT) N- 00 00 00 4.0 a, Mr- OONOCV) 00 6) O N- Cr) 0 0 0 O CC) CO V CC) CT CA N C) N O 0 0 0 0 O V j U CI I I I I I I I I .100G • MC3) CO N - M rnooN � � ooaooLO 0 N N N O C O O O N O Ch ," • ca CD 111 L O O 00 CO O O CO O ,r 0? Cb CCD D O O _ N J J CO 4# *k O '� 4 N N N • aO ;0 N CO - O CO ` U - N = 00 CV M 6 M N t OD OD CD CaO N- COO CO C C O V CC) 'tCh J N CD CD O rf O W R _0 U W W CO � 0u_cY C a a Z Z W W W W W W O D Z Z Z Z Z D U U) Z J J J J J H • I Packers and SSV's Attachment PBU 03-33C SW Name Type MD TVD Depscription 03-33C SSSV 2204 2203.9 4-1/2" MCX I-SSV 03-33C PACKER 3016.43 3014.06 7" Baker ZXP Top Packer 03-33C PACKER 9441.63 7893.86 7" Baker ZXP Top Packer 03-33C TBG PACKER 10336 8548.84 4-1/2" Baker S-3 Perm Packer 03-33C PACKER 10400.4 8595.69 5" Baker ZXP Top Packer .Tf�L= 41/16'CM/T TE=EAD= /16'ktEC Y NOTES: WELL ANGLE>700 @ 10894'.MAX ACTUATOR= BAKER C 03-33C MS:43-8'g 11060'.• READINGS AVERAGE NTTIAL KB. Et_E 62', 125 ppm WHEN ON MI WELL REQUIRES A SSSV BF ELEV= 27 89'f 1 WHEN ON MI " SEE PG.2 FOR PERVIOUS KOP= 2850WELLBORE"'CHROMELNR'"' P x Angle= 94"@ 11030'1 20'CONDUCTOR 110' Datum M)= 10762 1 , 2206' --141/2"FES X NP,ID=3.813' Datum TVD= 8800'SS 13-3/8'CSG, 72#,L-80,D= 12.34T 250€• TOP OF 7"SCAB LNR 1- 3018' 1 I _. 3018' J--19-5/8'X 7'BKR ZXP LW,D=6.290' o 1 3036' H9-5/8"X 7"BKR FLEX-LOCK HGR,D=6.310" Minimum ID =2.370" @ 10902' i , 3-1/2" X 2-7/8" X© PIN •' • 9444' -19-5/8"X 7"BKR C-2 ZXP LTP& Jr SCAB LHR,26#,L-80,BTC-M, - 9453' TEBACK SEAL ASSY,D=6.151" I 1.0383 bpf,D=6.276' LJ , 9461' ]-19-518"X 7"BKR FMC HGF{D=6280'J 9-5/8'VIMPSTOCK(03/12/05) H 9594' 9-5/8'CSG,47#, L-80,D=8.681" --I --9594 h-- [ MILLOUT WINDOW(03-338)9594'-9622' 10317' 1-14-1/2-FES X NP,D=3.813' 2 C. 10338' --17"X 4-1/2"BKR S-3 PREM PKR,D=3.875' 10362' -14-1/2"FES X NP, D=3.813" 10383' H4-1/2"11C:,XN NP,D=3.725" 4-1/2"TBG, 12.6#,L-80 TC-11,.0152 bpf,D -- =1958' 1 10395' .1; . 10391' --i 7"X 5'BKR ZXP LTP w lTEBK D=4.450" ' " 10395' H4-1/2"WLEG,D=3.958" \ 10409' -I7"X 5'BKR HMC HYDRO HGR,ID=4.430' TOP OF 3-1/2"X 2-7/8"LNR 10488' 10417' H5'X4-1/2"X0,D=3.980- i41 10488' - 3.70'BKR DEPLOY SLV,D=3.00' 10509' 1-13-112'HES X NP,D=2.813' 7"LNR,26#,L-80,BTC-M,.0383 bpf,D=6.276' - 10572' 3-1/2'LNR,9.2#, 13CR-85 SR 0087 bpf,D=2.992' 10902' 4-1/2"PKR WHFSTOCK(02/20/14) 1 10935' 10902' �3 1J2"X 2-7/8"XO,D=2.370" 41/2"LNR 126#,L-80 BT-M, .0152 bpf,D=3.958' -10936' r f MLL OUT WINDOW(03-33C) 10936'- 10946' ;4-1/2"CEP(02/04/14) -11050 PERFORATIONSUi4AARY , ,, 11409' 1-12-7/8"PUP MKR JT w/RA TAG 03/04/14 REF LOG � 1 ( ) ON XX/XX/14 :. 1 12655' 1-2-7/8'PUP MKR JT w/RA TAG(03/04/14) ANGLE A T TOP PERF 91"@ 13985' �4 Note Refer to Production DB for historical perf data ' .� 133 'ham PBTD H 14162' SIZE SPF. INTERVAL IOpn/Sqz SHOT SQZ 411IMNIimm71411k:fr afipr 2" 6 113985- 1401011 0 06/19/15 2" 6 14010- 14035 0 06/17/15 � t . 2" 6 14035- 14135 0 03/07/14 � 2' 6 114035- 14060 0 06/16/15 • 1 2" 6 1 14060- 140851 0 06/16/15 2-7/8'LNR 6.4#, 13CR-85 SR,.0058 bpf,D=2.441' --1 14200' 1 DATE REV BY i COMMENTS DATE REV BY I COMVENTS PRUDFIOE BAY UNIT 1 03/01/86- �1MTIAL COMPLETION 03/27/14 PJC SAFETY NOTE UPDATE WELL. 03-33C 104/30/97. i SIDETRACK(03-33A) 03/31/14 r JNUJMD(UPDATED 13CR-85 LNR PET MT No: `2131720 j 03/23/05 N2ES I SIDETRACK(03-33B) 04/04/14 TB/JMD FINAL ODE APPROVAL , AR No 50-029-21142-03 '03/08/14 NOF IC1 CTD SIDETRACK(03-33C) 05/13/14 PJC •SFTY NO I E-DOGLEG(.DATE SEC 11,T10fy R15E,214'FSL&822' FWL 01/30/14{ TB/PJC I DEPLOY SLV DEPTH UPDATE 07/10/15 I JLS/JMD ADPERFS(06/16-19/15) 03/10/14' JMD DREG FK)CORRECTIONS I BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, December 07, 2016 7:26 AM To: AK, OPS FS2 OSM;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OIL;AK, OPS FS2 DS Ops Lead; G GPB FS2 Drillsites; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; Shrider,James;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA);AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE:Injector 03-33C (PTD#2131720) Passed AOGCC MIT-IA All, Injector 03-33C(PTD#2131720) passed an AOGCC-witnessed MIT-IA on 12/06/16.The well is reclassified as Operable. Thanks, Adrienne McVey A\ 0 �, .n , Well Integrity Superintendent—GWO Alaska t6" (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 BM: AK, GWO SUPT Well Integrity Se • Wednesday, November 30, 2016 2:44 PM To: AK, a'S FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS FS2 DS Ops Lead; G GPB FS2 Drillsites; Cis , ki, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS EOC Specialists; A', •PS Prod Controllers; Shrider, James; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Wel egrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF - Ops Comp Rep; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov); AKIMS App User; Hibbert, Michae, anowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, • ; Worthington, Aras J Subject: UNDER EVALUATION: Injector 0 3C(PTD #2131720) Ready to be Brought Online for AOGCC Testing All, Injector 03-33C(PTD#2131720) underwent tree work and an X injection valve replacement,and will soon be ready to be placed back on injection. Once injection has stabilized,a witn- -d MIT-IA will be performed.The well is reclassified as Under Evaluation. Plan Forward: 1. Downhole Diagnostics:AOGCC MIT-IA to 2200 psi target pressure Please reply if in conflict with proposed plan. Thanks, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,December 07,2016 P.I.Supervisor e1 i I z 7r SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 03-33C FROM: Brian Bixby PRUDHOE BAY UNIT 03-33C Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T ---- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-33C API Well Number 50-029-21142-03-00 Inspector Name: Brian Bixby Permit Number: 213-172-0 Inspection Date: 12/6/2016 Insp Num: mitBDB161206140139 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min wail 03-33C Type Inj W TVD ' 8550 Tubing 2753 2753 - 2753- 2752 - 2753 • r 2131720 SPT 2138 163 3398 • 3383 - 3406 - 3436 PTD; Type Test Test psi IA Interval INITAL PAF P ✓ OA 18 86 98 107 116 Notes: 5.63 BBLS Diesel to fill the IA,and 5.3 BBLS bled back after test was completed. SCANNED APR 0 6 2017 Wednesday,December 07,2016 Page 1 of 1 1 Or Tit • \� % c THE STATE Alaska Oil and Gas b17. -a,►:`s of Conserv. tion Commission .1.1174411•11 ..z = l 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF �,tm*- Q, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov November 30, 2016 Mr. Ryan Daniel Well Integrity Engineering Team Leader BP Exploration(Alaska) Inc. 900 E. Benson Boulevand Anchorage, AK 99508 Re: Docket Number: OTH-16-028 Notice of Violation—Closeout SaittiED DEC 0 6 2016 Missed Mechanical Integrity Tests Prudhoe Bay Unit 03-33C (PTD 2131720) Prudhoe Bay Unit H-09A(PTD 2140500) Dear Mr. Daniel: The Alaska Oil and Gas Conservation Commission(AOGCC)reviewed BP Exploration(Alaska) Inc. (BPXA)'s November 28,2016 explanation regarding the missed mechanical integrity tests on Prudhoe Bay Unit wells 03-33C and H-09A. The corrective actions outlined in your letter address the procedural concerns identified in the notice of violation. The AOGCC does not intend to pursue any further enforcement action regarding these missed mechanical integrity tests. Sincerely, Cathy '. Foerster Chair cc: AOGCC Inspectors(via email) • • by BP Exploration(Alaska)Inc. Ryan Daniel,Well Integrity Engineering Team Leader Post Office Box 196612 Anchorage,Alaska 99519-6612 NOV 29 2 0)6 ()OGG November 28th, 2016 Cathy P. Foerster Commission Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: OTH-16-028 Notice of Violation - Missing initial MIT-IA test post CTD sidetrack on H- 09A (PTD (2140500) and 03-33C (PTD (2131720) Dear Chair Foerster, On November 8th,2016, AOGCC issued a Notice of Violation (NOV) to BP Exploration (Alaska) Inc. (BPXA), as operator on behalf of the Prudhoe Bay Unit (PBU) working interest owners. The NOV letter requested written follow-up in two areas. Reschedule for post CTD MIT-IA BPXA will re-schedule and perform an AOGCC witnessed MIT-IA on the identified injector wells, and update the well records accordingly with the revised MIT-IA anniversary date for the sidetrack. • H-09A (PTD (2140500) last MIT-IA was conducted on 6/2/2014, 3000#, passing test. A new AOGCC witnessed MIT-IA has been scheduled for Nov 29th 2016. • 03-33C (PTD (2131720) last MIT-IA was conducted on 1/1/2015, 3500#, passing test. This well is currently undergoing well work to repair the tree, and also requires an Injection valve replacement. When the planned well work is completed the well will be bought back online and a new AOGCC witnessed MIT-IA scheduled. Estimated time for well work completion and retesting is 1-2 weeks. Corrective Action Plan • • BPXA reply to 0TH-16-028 Notice of Violation missing mechanical Integrity test on H-09A (PTD2140500) and 03-33C (PTD2131720) 28 November 2016 Page 2 The following actions are being undertaken by BPXA to prevent any reoccurrence. • Well handover process and documentation from Drilling to Wells Group will be updated to ensure specific details and hand written notes contained in the PTD are effectively communicated and reviewed prior to placing the well online. Accordingly, any new or relevant information will be added to the ANNCOMM database used to track the operating wells history (post-handover) and the respective compliance testing requirements. • Well Integrity Superintendent (WIS) will ensure all post CTD sidetrack injector wells are rescheduled for an MIT-IA (after placing on initial injection), and resetting the new well bore MIT-IA anniversary date. • Communication and Training by WIS and CTD team, update relevant well engineering and operations reference documentation. In summary, BPXA believe the proposed corrective action plan and reset of MIT-IA anniversary dates for both wells addresses the NOV and requests. Please let me know if you have any questions, Sincerely, Ryan Daniel BPXA Wells Integrity Engineering Team Leader • • Well Bore Schematic and TIO plot for H-09A (PTD2140500) 1 _-Lir,... .„.. C *OE, 1.8b-let CIONFLS 91H13fA0- t H-09A ci 4 MOTES: MIME „ r fit t.: tow flEile 7S t'7” MOOS.SSSW WH13i O6W-tNU O09E191¢ ti® . 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"''.0•47* ... 6 MI6.14015, a .Siinin 1 7 1 I 14035.t4I36, 0 Of(14 r a *was vaaaal 0 01100/13 1 tTral•L.e.,mai..Ili,CCM trgi Di 3.1.F._user_j 2. e wee*east_o miens -. .. .. .....__... . .. .-........ ,-. - 'E1--il-E"1111,--rir -cor-T-Aens OVE NW 61 0:661116s - n1.1110n 0015,MT ,Omni NMI.C01801.171011 gym, ar !WET!NOTE(0006 ' %I. isaic Si0tellha6(63.---raj------ iiEirTr- ---fEr- W.60% I ---; filiAir.313.12. iiWKI41T66.W. 04704fi4jMUM}WV OCENSVOVAL 39 1.1 0-02.12114203 'Weer.Mamma C.010E01/1107105-30C) WM. -a- 26ff KM-00CLEG W $10 11.flax RISE,21.FE,6 tra'Fix ,trii30114 I forric Etii.01,sLVIESTA-A-iiit''Oiffits.ILSAILIDIA0110.10.16-10/0) c -_-_.-- • Or r� • 4110 ,"\\\I//%y .A THE STATE Alaska Oil and Gas � =;s4of Conservation Commissio KO � i '» ` 333 West Seventh Avenue �wR GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p Main: 907.279.1433 ALA 4-`16)' Fax: 907.276.7542 www.aogcc.alaska.gov CERTIFIED MAIL RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7173 November 8, 2016 Ms. Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: OTH-16-028 Notice of Violation Missing Mechanical Integrity Test Prudhoe Bay Unit H-09A (PTD 2140500) Prudhoe Bay Unit 03-33C (PTD 2131720) Dear Ms. Cocklan-Vendl: After review of injection well records for Milne Point Unit (MPU) F-30A revealed a failure to perform required pre- and post-injection tubing-casing annulus mechanical integrity tests (MIT) at a time when BP Exploration (Alaska) Inc. (BPXA) was the operator of the MPU1, the Alaska Oil and Gas Conservation Commission (AOGCC) commenced a review of all injection wells at current and previously BPXA-operated fields in Alaska. That review identified fifteen injection wells that were redrilled and completed between January 2013 and August 2016. On four of the fifteen wells BPXA failed to perform the required initial post-injection MIT: - PBU H-09A (PTD 2140500); well completed August 8, 2014; injection commenced in December 2014;no record of a MIT since restarting injection;pre-and post-initial injection MITs are required under Rule 6, AIO 4F. - PBU 03-33C (PTD 2131720); well completed March 8, 2014; injection commenced in September 2014; no record of a MIT since restarting injection; pre- and post-initial injection MITs are required under Rule 6, AIO 4F; a Permit to Drill (PTD) condition of approval required a"State witnessed MITIA". - MPU F-30A(PTD 2131880); well completed April 28,2014; injection commenced in July 2014; no record of a MIT since restarting injection; well has remained shut in since June 2016; Rule 4 of AIO 10B requires the operator of MPU injection well to develop and coordinate with AOGCC a MIT schedule;the PTD conditions of approval included a"State witnessed MITIA required after stabilized injection". 1 Hilcorp Alaska LLC became operator of Milne Point Unit F-30A effective December 24,2014 . Docket Number: OTH-16-028 41110 Missing MITs—PBU wells November 8,2016 Page 2 of 3 - MPU F-74A(PTD 2131890);well completed May 19,2014;injection commenced in May 2014; Rule 4 of AIO 10B requires the operator of MPU injection well to develop and coordinate with AOGCC a MIT schedule;the initial MIT did not occur until performed by Hilcorp on August 31, 2015; the PTD was silent on a MIT condition of approval.2 An October 22, 2015 email from BPXA raised questions whether the requirement to do a post- initial injection MIT applied to a through-tubing injection well "sidetrack". BPXA's email indicates its normal practice is to retain the MIT anniversary date and therefore not perform the post-injection MIT for the new well, and notes "All things being equal the wellbore above the packer has not changed." BPXA's characterization is incorrect. AOGCC regulation 20 AAC 25.990(63) defines "sidetrack operation" as "a drilling operation conducted for the purpose of straightening the original hole, bypassing junk, or correcting mechanical difficulties in the original hole." The through-tubing wells drilled with coil tubing drilling units are new wells requiring a MIT. AOGCC acknowledges that its PTD's have not consistently included a specific condition of approval requiring a MIT for new wells. However, the absence of a specific requirement in the PTD does not exonerate BPXA from compliance with the requirement to test a new injection well to demonstrate mechanical integrity of the tubing, packer and casing as required by regulations and injection orders. Within 14 days of receipt of this notice of violation,you are requested to provide the AOGCC with the following specific to Prudhoe Bay Unit wells: - a schedule for bringing PBU H-09A and PBU 03-33C into compliance with MIT requirements, and - a written description of the steps that have been or will be taken to prevent recurrence of missed MITs for coil tubing and rotary rig redrills in BPXA-operated fields. The AOGCC reserves the right to pursue enforcement action in connection with the missed MIT's at PBU H-09A and PBU 03-33C as provided by 20 AAC 25.535. Sincerely, Daniel T. Seamount, Jr. Commissioner cc: R. Daniel, BPXA P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE 2 Because Hilcorp as the new MPU operator has conducted an MIT MPU F-74A,and shut in MPU F-30A,the AOGCC is taking no action on BPXA's failure to conduct the MIT's. Docket Number: OTH-16-028• Missing MITs—PBU wells November 8,2016 Page 3 of 3 As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. U.S. Postal Service" S CERTIFIED MAIL® RECEIPT rrt Domestic Mail Only r`- r-1 For delivery information,visit our website at www.usps.com'. Iti r�- Certified Mail Fee $ r"R Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(hardcopy) C ❑Return Receipt(electronic) $_ Postmark 1=1 ❑Certified Mail Restricted Delivery $__— Here 0 ElAdult Signature Required $ _ _. ❑Adult Signature Restricted Delivery$ _ Postage $ ..D Total Posta rg Ms. Mary Cocklan-Vendl s u-) Sent To - Pipeline Compliance and Conformance Manager O Street and• BP Exploration (Alaska), Inc. P.O. Box 196612 Ctt, State, Anchorage,AK 99519-6612 SENDER:COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY • Complete items 1,2, and 3. A. Signatur, • Printyour name and address on the reverse gent �� /-I� ' 0 Addressee so that we can return the card to you. ® Attach this card to the back of the mailpiece, B. Received by(P/ft .N. e) C. Date of Delivery or on the front if space permits. a i1/::4•,Ilea / D. Is delivery address different from item 1? • Yes If YES,enter delivery address below: ❑ No Ms. Mary Cocklan-Vendl Pipeline Compliance and Conformance Manager BP Exploration (Alaska), Inc. NOV 1 4 2U1b P.O. Box 196612 Anchorage,AK 99519-6612 3. Service Type ❑Priority Mail Express® I 111 11111111 I II I1 I II I III I I II I ❑Adult Signature 0 Registered Mar. ❑Adult Signature Restricted Delivery 0 Registered Mail Restricted UrCertified Mail® Delivery 9590 9401 0057 5071 0132 91 0 Certified Mail Restricted Delivery i—Return Receipt for ❑Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery C Signature ConfirmationTo 0000 --•-zd Mail ❑Signature Confirmation 7 015 1660 1487 7173 $5M it Restricted Dehveryy Restrir �i, Delivery 00) PS Form 3811,April 2015 PSN 7530-02-000-9053 Domestic Return Receipt STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM. )N • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate ® Other Stimulate ® Alter Casing El Change Approved Program ID Plug for Rednll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: a CI d.5-71/11.1 "Cr''' 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 213-172 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-21142-03-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number: PBU 03-33C 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY.PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 14204 feet Plugs measured None feet true vertical 8986 feet Junk measured None feet Effective Depth: measured 14162 feet Packer measured See Attachment feet true vertical 8986 feet Packer true vertical See Attachment feet Casing: Length. Size: MD: TVD: Burst: Collapse: Structural Conductor Surface See Attachment ECEID Intermediate s tifIEQ 1 U L 14 2015 Production Liner OG CC' Perforation Depth: Measured depth: 13985-14010 feet 14010-14035 feet 14035-14060 feet 14060 14085 feet 1,,/ 14085-14135 feet True vertical depth: 8985-8985 feet 8985-8985 feet 8985-8985 feet 8985-8985 feet 8985-8986 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-10392 23-8589 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSV 2204 . 2204 12.Stimulation or cement squeeze summary' 13985'-14085' Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25 070 25 071,a 25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service I! Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG H GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-199 Contact Summerhays,Nita M(W-RO Technologies) Email Nita.Summerhays@bp.com Printed Name Summerhays, 'a M IPRO Technologies Title Petrotechnical Data Manager Signature =/ �/ / , //'IJ��i�� Phone +1 907564-4035 Date 07/14/2015 Form 10-404 Revised 5/2015 VT1- / / j 5 // f.2,4,;- onneeeOngmal ly1 7 gnu Daily Report of Well Operations PBU 03-33C ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL*** (profile modification) RIG UP SWCP 4516 TO PULL 4-1/2" HES MCX(s/n = M-002) FROM 2,206' MD. 6/1/2015 ***JOB IN PROGRESS, CONTINUED ON 6/2/15 WSR*** ***CONTINUED FROM 6/1/15 WSR***(profile modification) TAG 4-1/2" MCX AT 2,184'SLM W/3.84" NO-GO CENTRALIZER (No issues). PULL 4-1/2" HES MCX(s/n = M-002- 1.375" bean) FROM 2,184'SLM/2,206' MD. DRIFT TO DEVIATION AT 10,988' SLM W/2.25"CENT, SAMPLE BAILER (No sample). 6/2/2015 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** CTU#9 w/ 1.75"ct Job objective : GR/CCL log perforate acid treatment& SBG MIRU RIH w/PDS GR/CCL logging tools&2.30" DJN. Pump SBG and jet across pert-s 6/15/2015 ***Job continued on WSR 6/16/15*** CTU#9 w/ 1.75"ct Job objective : GR/CCL log perforate acid treatment& SBG Pump SBG and reciprocate across pefs'.Injetivity 0.8 bpm @ 2643 psi POOH Confirmed good DATA+ 8'. MU Gun#1. RIH w/2"Guns-6 SPF-60 deg -2006 PJ HMX and perforate from 14060-14085'. POOH. LD gun. MU Gun#2. RIH w/2" Guns-6 SPF-60 deg -2006 PJ HMX and perforate from 14035-14060'. POOH. LD gun. ****Job Continued on WSR 6/17/15**** 6/16/2015 CTU#9 w/ 1.75"ct Job objective : GR/CCL log perforate acid treatment&SBG ****Continue WSR from 6/16/15**** RIH w/PDS GR/CCL logging tools&nz 2.25"to 14072'. Log up to flag at 14021.6E/14052M. Continue logging at 50fpm to 12424'. POOH. LD logging tools. Good data: +11'correction. Change packoffs. MU Gun#3 & RIH and perforate 14010-14035 6spf, 60 deg, 2006 PJN HMX charges. Pump diesel at min rate CTBS while POOH for pipe displacement. LD Gun#3. MU and RIH with Gun#4. Locking up at 11000'. Pump Safelube down coil, continue RIH. Tagging hard at 11728' CTM. Can't work past. POOH with live gun. 6/17/2015 ****Job continued on WSR 6/18/2015**** CTU#9 w/ 1.75"Coil. Job Objective: GR/CCL log, perforate, acid treatment, SBG***Continue WSR from 6/17/2015*** RIH w/2"venturi made it to 11102' POOH at surface venturi was packed with metal shavings. RIH w/2.25"JSN for FCO. RIH and clean out from 10,884 to 14,083', dry tag at 14,086. Perform final 12 bbl gel sweep and chase out of hole at 80%. Pop off well and stack down for Cr pipe management, do packoffs and chain inspection. 6/18/2015 ***Job Continued on WSR 6/19/15*** CTU#9 w/ 1.75"CT Job Objective: GR/CCL log, Perforate,Acid treatment ***Continued from WSR 6/18/15*** Continue to stack down for Cr pipe management, packoff do, and chain inspection. Cut 50'of pipe, MU BOT MHA and PDS logging tools. RIH with logging string to 14,086', log up to 11,200'. POOH, download data, make 2'correction. RIH with 25'gun run#4, correct top shot at flag, PUH and perforate interval 13,985'- 14,010'with 2" PJ Nova HMX 6 SPF 60 degree phasing. POOH and lay down guns, Stab on well and perform 7 day BOP test. MU nozzle BHA, Open well RIH while pumping 75 bbls of diesel down CTBS 6/19/2015 ****Job continued on WSR 6/20/15**** CTU#9 w/ 1.75" CT CTV=40bbls Job Objective:Acid Treatment ****Continued from WSR 6/19/15**** Continue RIH with nozzle BHA while pumping 75 bbls of diesel in CTBS. Perform initial injectivity test with NH4CL .7 BPM at 2000 psi WHP, 1928 psi CTP. Tag bottom at 14,065, PUH 10'and paint white flag at 14,055'.Pumped 108 bbls of 12% HCL acid& 108 bbls of 9:1 Mud acid/ Injectivity at beginning 1 bpm @ 2156 psi/Finale injectivity test @ 2.5 bpm 951 psi. Blow down reel with N2 for pipe swab. RDMO 6/20/2015 ****Job Complete**** 6/21/2015 ***SPOT IN SWCP 4515 ON EOP FOR MCX C/O** Daily Report of Well Operations PBU 03-33C ***WELL S/I UPON ARRIVAL***(profile modification) RAN 4-1/2" BRUSH &3.50"GAUGE RING TO X-NIPPLE @ 2,206' MD. (no issues) SET 3.813"X-LOCK&4-1/2" MCX(ser#M-21, 1.25"bean) IN X-NIPPLE @ 2,206' MD. CONFIRMED GOOD SET W/4-1/2"CHECK SET.(sheared) 6/22/2015 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** Fluids Summary Bbls Type 219.6 DIESEL 63.7 50/50 METH 11 1% KCL 40 NH4CL 824 SLICK 1% KCL W/SAFELUBE 73 POWERVIS 109 1% KCL W/SAFELUBE 1340.3 Total • w (1) CD O O O O O M 0 O 1atirN up CD � ; "3T- o C Nt up o r- OD T- C.)V 0 0 0 0 E3 E O)0 M N- �f M GO CD N N O• cn op 0 OD O C N N M M CD CD 00 0 0 N M N OD OD O 1.11 O CD I� CD CD CD 0 N OD I"- OD CID OD OD OD a 1 . 11IIIII H CD 0 O) O M CO 0 M r- CO OD CO N M N N N O CO Ln CO CD N M I- co CIO OD 4.0 0 ,rMNCDNON T- N cn CD 0 0 0 CV 0 L V QM00 T- OD N M co 001T- vrnc 00, 0) M N N N O g O O O N C 0 M I— a000 0 00p 0 OD co co co C� NtJJOOCOCD CD JMMJ *k N 4# J J 'N N C[? 4* 4t N N C a0 C0V CV d) CD V - 1 N CA i N M N t _ In OD OD O O I� N- CO N LC/ 0 CD CD C CIO 0 t? Nt V- N M J N CA CD "I M O CC W ~Q CD 15 U W W 80 V 0 u_ CL c[ txcerer Z Z W W W W W W O , H Z Z Z Z Z D U fn Z J J J J J Packers and SSV's Attachment PBU 03-33C SW Name Type MD TVD Depscription 03-33C SSSV 2204 2203.9 4-1/2" MCX I-SSV 03-33C PACKER 3018.39 3015.98 7" Baker ZXP Top Packer 03-33C PACKER 9443.59 7895.27 7" Baker ZXP Top Packer 03-33C PACKER 10334.78 8547.96 4-1/2" Baker S-3 Perm Packer 03-33C PACKER 10402.4 8597.15 5" Baker ZXP Top Packer TREE 4-1/16'CNV 0 3 3 3 C FETY NOTES: WELL ANGLE>70'Q 10894'.MAX WELLFEAACTUATOR= BAKER C RLS:43."a 11080'."'H2S READINGS AVERAGE 125 ppm WHEN ON MI"'WELL REQUIRES A SSSV MlAL KB.H.E 62, BFE_EV= 27.89' I I WHEN ON MI"•38:PG.2 FOR PERVIOUS WELLBORE""CHbM KOP= 2850' Mbx Angle= 94'a 1_0762'1030' 20'COPDUCTOR 110' 2208' H 41/2'FES X NP D=3.813` Datum MD=-- 1 Datum TVD="--- 8i3-00'SS 13-3/8"CSG,728,L-80,D=12.34T H 2606' TOP OF 7'SCAB LNR —{ 3018' I•---1 c. 3018' H9-5/8'X T BKR ZXP LTP,13=8.290' .I 3036' H9-5/8-X 7'BKR FLEX-LOCK HGR,D=6.310' Minimum ID=2.370" @ 10902' 4 • • 3-112"X 2-7/8" XO PIN • • , 9_5/6-x BKR C-2 ZXP LIP 8 7'SCAB LNR,268,L-80,BTC-M, 9453' I �4 � 1TEBACK 7'SEAL ASSY,D=8.151'_ 0383 bpf,D=6276' 0. 9461' -19-5/8"X T BKR HMR D C HG =6280" 9-5/8"WHPSTOCK(03/12/05) -1 9684' 9-5/8'CSG,47#, L-80,13=8.681' -I -9894 MLLOUT WIDOW(03-33B)9594'-9622 10317' H4-1/2"FES XS*?D=3.813' I - 010338' HT x 4-1/2'BKR S-3 RRBN ROi D=3.875' I10382 H4-1n'HES x NP,D=3.813"I I10383' -14-12'HES XN NP,13=3.725" 4-12"113G,12.68,L40 TC-11,.0152 bpf,D-3.958' H 1039v. P 10391' H7'X 5-BKR ZXP LTP w/EBK,D=4.450"6' v 10396' H4-1/2'WL6G,D=3.958' 10409' H7'X 5"BKR HMC HYDRO HGR,D=4.430' TOP OF 3-12'X 2-718"LNR —I 104$8' 10417' H 5'X 412-XO,D=3.980' ► :IN IN 10488• -13.70'BKR DEPLOY SLV,D=3.00" ►4 � ►4 4 10609' 13-1/2-HES X NP,D=2.813' 7'LNR,268,L-80,BIC-M,.0383 bpf,D=6276" H 10672 _1.-41 ► ,� • ►4 �� 4 r4 3-12'LNR 928,13CR-85 STL.0087 bpf,D=2.992' 10902' 0 ►41 10902'1-13-1/2'IX 2-7/8'XO,D=2.370' 4-12B'RVN-PSTOCK(02/20/14) —1 10935' I. •� 4-1/2"LFP12.88,L-80 BT-M,.0152 bpf,D=3.958' -10936' ►4 4� 4 ►t MLLOUT WNDOW(03-33C) 10936'-10946' 4-1/21:13P(02/04/14) —L-11060 04 1 PERFORATION 516,414IJ * ►4 /+4 11409' H2-7/8"RP MICR JT w/RA TAG(03/04/14) REF LOG: ON XXAO(/14 ►� �• 12666' H2-7/8-RP MICR ST w/RA TAG(03/04/14) ANGLE AT TOP PERE:91'a 13985' ►4 ►r. • Note_Refer to Production DB for historical perf data 4• '�,4�4."4•+j�.a+` w MID 14162 SEE SPF INTERVAL 13965-14010 O 061 15 ••*SCIZ moi•'+�•4I•�i�i!��i.#'�•`•;r7�• ��i.., .. 2" 6 14010-14035 0 06117/15 �`4a���.i7.4.4OW��♦_*a=te'. 2' 6 14035-14135 0 03/07/14 2' 6 14035-14060 0 06/16/15 2' 6 14060-14085 0 06/16/15 2-7/8'LI' ,6.48,13CR-85 STL,.0058 bpf,D=2A41" 14200' DATE REV BY C OMENTS DATE REV BY COM/ANTS PRUCHOE BAY UNIT 03/01/88 'INITIAL COMPLETION 03/27/14 PJC SAFETY NOTE UPDATE WELL: 03-33C 04/30/97 SIDETRACK(03-33A) 03/31/14 ALARM UPDATED 13CR4-85 LNR R32 AT No: 12131720 03/21'05 N2E5 SIDETRACK(03-3313) 04/04/14 TB/J10 FNAL ODEAFPROVAL AR No: 50-029-21142-03 03108/14 NORDICI CTD SIDETRACK(03-33C) 05/13/14 PJC SFTY NOTE-DOGLEG MATE SEC 11,T10N R15E,214'FSL&822' FWL 01/30/14 TB/PJC DEPLOY Sly DEM UPDATE 07/10/15 JLS/JMD ADPE RFS(06/16-19/15) 03/10/14 JIM DRLG HO COFFECTTONS BP Ezpbration(Alaska) v OF 77 44, yi�s� THE STATE Alaska Oil and Gas ofALASI�:A Conservation Commission ' iltx___ __ 333 West Seventh Avenue �F - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS ' Fax: 907 276.7542 www.aogcc.alaska.gov Ralph Sinnok Satiii6D Production Engineer 3" 17PBP Exploration(Alaska), Inc. <113- 17)-- P.O. .O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-33C Sundry Number: 315-199 Dear Mr. Sinnok: 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, Cathy P. Foerster Chair DATED this 12 day of April, 2015 Encl. RECEIVED APR 02 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon 1=1 Plug for Redrill❑ Perforate New Pool CI _,,. Repair Well❑ Change Approved Program❑ Suspend': Plug Perforations': Perforate Pull Tubing❑ Time ExtensionE] Operations Shutdown': Re-enter Susp.Well❑ Stimulate❑. Alter Casing': Other HQ�I g✓� 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. 51-1).r' BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 213-172-0 • 3.Address: Stratigraphic ❑ Service 2, 6.API Number. P O.Box 196612,Anchorage,AK 99519-6612 50-029-21142-03-00 ' 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU 03-33C - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028327. PRUDHOE BAY, PRUDHOE OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft). Plugs(measured): Junk(measured). 14204 • 8986 . 14162 8986 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91 5#H-40 25.89-105 89 25.89-105.89 Surface 2475 13-3/8"72#L-80 25.39-2499.99 25 39-2499 87 4930 2670 Intermediate 9571 9-5/8"47#L-80 22.78-9594 22.78-8003.64 6870 4760 Production None None None None None None 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): 14035-14135 8984.62-8985.77 4-1/2"12 6#L-80 L-80 23.39-10391.78 Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 4-1/2"MCX I-SSV 2204',2203.9' 12.Attachments. Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch El Exploratory ❑ Development ❑ Service 0 - 14.Estimated Date for 15 Well Status after proposed work. Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date. WINJ ❑ GINJ ❑ WAG El • Abandoned ❑ Commission Representative. GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ralph Sinnok Email Ralph.Sinnok@BP.Com I Printed Name Ralph Sinnok Title Production Engineer Signature ��� 564-4630 Date Prepared by Garry Catron 564-4424 'i%C o�a2/Z�� s- COMMISSION USE ONLY a Conditions of approval. Notify Commission so that a representative may witness Sundry Number: 31 i "/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No e Subsequent Form Required: /L7 - .4 D 4- APPROVED BY Approved by. COMMISSIONER THE COMMISSION Date: _/7.... /s 16'Vevi._ 41q/15- QlGlNALAi 'RForm 10-403 Revised 10/2012 Approved application is vaor 1Z months from the date of approval. Submit Form and Attachments in Duplicate RBDMSA\ APR 1 8 2015 ..-..,, V ' CD 10 73 O O T O O o O o� = J MUJ _Lim J J J� N Q O O N 0 0CO 0 0 0 co r- COL. ,71_ O , r.0" O U -t-i) CO V Cb = N N O) V a) u) as M N co CO N O O) CO o N O CO CO N O CO O 6) Cr) O) (3) N- LC) Lf) `- O) CO N- co co co N co I- Q o O CO O) CO LO ~ CO M CO .- CO (NI d) LO M (21 N N CO O L0 O) CO N N - > CO CO CO co I-- L I- • N 0 E N co CO O N N CO 0 ( Co Ls, co Cr) ON Ln WoCO O •-c) O cY O N O p E J 0 Q co .-0 N H Co co M CA © Lo co U o N N a 0 0 C v N N M O o L.0 1) O O O co - co do g00UOJUOJJ i - co 4$ N * J CO �$ N _ o �CV O - CV 0, bo o N _ CO (NI -00 _ In N f� --C,\_1 ao Cr? N N Q - P---- M c- () V N Lc) co co L.0 co on O N - CO -‘ CA N N CO C co L() T- V N T V co J O) CO CO N O W CC m F- QI- W W U 03 D Z W W W W W W r m p H z z z z z : D 0 Z J J J J J U) I- Packers and SSV's Attachment ADL0028327 Well Facility Type MD Top Description TVD Top 03-33C SSSV 2204 4-1/2" MCX I-SSV 2204 03-33C PACKER 3018 7" Baker ZXP Top Packer 3016 03-33C PACKER 9444 7" Baker ZXP Top Packer 7895 03-33C PACKER 10335 -4-1/2" Baker S-3 Perm Packer 8548 03-33C - PACKER 10402 `5" Baker ZXP Top Packer 8597 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: 03-33C Well Type: WAG Injection Well API Number: 50-029-21142-03 Well Activity Conventional 4 Classification: Activity Description: Add Perfs/Reperf&Acid Stim Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Ralph Sinnok Contact numbers: (907) 564-4630 (907)304-252 Well Intervention Engineer: Michael Hibbert Contact numbers: (907) 564-4351 (907)903-599 Lead Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907)360-748 Date Created: March 17, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injectic Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) (psi) Cut(%) (Mscf/Day) 3/16/2015 0 0 -6 Current Status: Operable Shut In Inclination>70°at Depth(ft) N/A NA 0 Maximum Deviation(Angle and Recent H2S (date, ppm) ppm Depth) 11,030' MD — Datum depth,ft TVDss None. Dogleg Severity(Angle and Depth) 43° 11,060' MD Reservoir pressure(date, Anticipated 3,300 psi Minimum ID and Depth 2.370" 10,902' MD; 3-1/2x2-7/8 XO psig) Reservoir Temp, F 180° F Shut-in Wellhead Pressure Vacuum Known mech. integrity None. problems(specifics) Last downhole operation(date, operation) 11/19/2014 FB: diesel injectivity test. Most recent TD tag (date,depth, 4/18/2014 14,169' CTM 1.75"CTU RIH with 1.75"x29' JSN &agitator assembly. toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? N/A Comments,well history, Injector completed March 2014. Initially, the well was POI with produced water. The max injection rate background information, was 3,400 bwpd at 1,850 psi WHIP which drastically decreased to 350 bwpd after 25 days of injection. etc: 11/18/14,an injectivity test was performed which showed 0.7 bpm Q 2,000 psi for 10&20 minutes with aiesei. i ne rest or me test results incruae: I.I opm wl L,uou ,, i.o opm i ou psi;t.0 opm a,vuu psi;2.9 bpm @ 3,750 psi;and 3.4 bpm®3,900 psi. The objective of this job is to re-perforate 50' of the original perforations to improve connectivity to the • reservoir in this interval. Perforations of 50'will be added next to the original perforations to increase the wellbore's area connected to the reservoir. An acid stimulation will be performed to improve injectivity of . the perforations. A static will be obtained since this well does not have a SBHPS. Also, an MCX will be installed to return this well to MI injection post well intervention. Well Intervention Details Suspected Well Problem: Low injectivity rate. Specific Intervention or Well Objectives: 1 Re-perf 50' of original perforations. 2 Add 50'of perforations next to original set. 3 Acid stimulate perforations to improve injectivity. 4 Perform SBHPS. 5 Install MCX. Key risks,critical issues: Mitigation plan: 1 Tubing is L-80. Use 13-Cr additive concentrations since liner is 13-Cr. 2 Perforation debris causing RIH issues during pert runs. Potential for performing clean-out and/or bailer runs. Summary Service Line Activity Step# 1 F SBG treatment. 2 C Drift, log/tag, perforate 100', and acid stimulate. 3 S SBHPS and install 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 F Schmoo-B-Gone treatment. Pumping schedule and volumes attached. After successful treatment, fullbore to RDMO. Drift with nozzle and GR/CCL. Obtain jewelry log from PBTD to 10,250' MD and flag pipe for perforation 2 C runs for depth control. Suggestion: paint flag on pipe after coil tags PBTD, may PUH 30'from PBTD and flag pipe. Tie-in Log: See Reference Log titled"MCNL: Lee TNN/TNF/GR/CCL on 06-Mar-2014". 3 Perforate 100' from 13,985-14,085' MD. Perforation form attached. 4 Acid stimulate. Stimulation procedure attached. After successful acid treatment, coil to RDMO. 5 S Perform SBHPS. Survey form attached. 6 Set 4-1/2" MCX @ 2,206' MD. Ensure MCX is set. After successful MCX set, slickline to RDMO. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: POI with MI. 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 Approvals Management Approval: Date: Wells Approval: Date: This procedure accompanies the 03-33Ci_Perf-Aciu-Stim_SOR_3-17-15.xlsm 03-33C Coil Acid Stimulation Procedure Comments: • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • In general, pump job at maximum allowable or achievable rate/pressure. • Attempt to not exceed 2,000 psi while acid is entering the perforations if possible. It is ok to go up to 3,000 psi surface pressure if the diversion is very effective at plugging slots. Increase pressure as needed to allow job to be completed. • Send an electronic copy of the treatment report including digital, ASCII, or an excel copy of pumping rates and pressures to Ralph Sinnok at: ralph.sinnok©bp.com Perforation Details Zone MDT MDB H Status Z2C 13,985 14,135' 150 14,035-14,135' Open; 14,035-14,085' will be re-perf'ed; 13,985-14,035' will be added. Design Details: Wellbore Volume 181 bbls to top of pert at 13,985' MD. Acid Design 30 gpf of 12% HCL and 30 gpf of 9:1 Mud Acid Oilseeker Design 12 bbl per diversion Oilseeker (2 diversions) Pres 09/25/2012: SBHP 3,339 psi at 8800 tvd, SBHT is 177 F Treatment Procedure 1. Ensure the following before starting the job: a. Ensure current MSDS for this job is onsite and acid safe handling procedures are followed b. Ensure that the acid shower trailer is on site and functional c. Keep out all personnel not associated with this job d. Ensure Sundry for performing acid stimulation is on location. e. Well has L-80 liner. Ensure correct additives are used. SBHT 177 F. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +74% for HCI. Fluids should be 90-110 F 2. MU coil tool string with jet swirl nozzle and RIH to top of perforations (diesel should be in the coil at this stage) and displace coil with Ammonium Chloride while taking returns through backside. Displace diesel —500ft away from top of perforations to prevent diesel and acid getting into contact with each other(500 ft — 6.5 bbl). Close in backside and keep on injecting ammonium chloride until steady injection is achieved. If needed to establish injection, go to 3,000 psi WHP, but drop immediately back to 2,000 psi WHP so as to not fracture the well during the acid wash. This procedure accompanies the 03-33Ci_Perf-Aci -Stim_SOR_3-17-15.xlsm 3. Pump fluids per attached pump schedule while reciprocating nozzle across perforated interval (13,985' — 14,135'). When acid is on the perforations, maximum WHP should be 2,000 psi. Before POOH, complete the over flush to ensure that the acid has been pushed away. The acid stimulation should take-9.5 hours to pump. Please record oilseeker rates and total volumes pumped in AWGRS report. 4. POOH with coil and perform another injectivity test with diesel down the backside and make note of stabilized rate and pressure in daily report. 5. RDMO Coil. Cum Cum co d Fluid Fluid = Vol Vol 131 Fluid Type Vol (bbl) (bbl) Vol (gal) , (gal) o _ 3% NH4C1+ F103 684 684 28,716 28,716 12% HCI 107 791 4,500 33,216 ` 15 9:1 Mud Acid 107 898 4,500 37,716 0 ~ Foam (3% NH4CI+F103+N2) 8 906 336 38,052 HCI/Mud Acid Recommended Additive Concentrations Temperature: Medium (175°F to 225°F) Completion metallurgy: 13Cr Total Chem Total Chem Loading for: 12% HCI 9:1 mud acid 12% HCI 9:1 mud acid Product Code: Function: Units: A264 ACI gal/Mgal 6 6 27 27 A201 Inhibitor Aid gal/Mgal 40 40 180 180 A153 Intensifier lb/Mgal 5 5 22.5 22.5 F103 Flowback aid gal/Mgal 2 2 9 9 L058 Iron Control lb/Mgal 20 20 90 90 W054 Antiemulsifier gal/Mgal 5 5 22.5 22.5 U067 Mutual Solvent gal/Mgal 0 50 0 225 This procedure accompanies the 03-33Ci_Perf-Ac1..-Stim_SOR_3-17-15.xlsm Pumping Schedule Stage Cum Fluid Fluid Vol Vol Step Description Fluid bbl bbl 1 Pre-Displacement 3% NH4CI + F103 272 272 2 Acid 12% HCI 36 308 3 Mud Acid 9:1 Mud Acid 36 343 4 Overflush 3% NH4CI + F103 54 397 Foam (3% NH4CI + F103 + 5 Diverter N2) 4 401 6 Spacer 3% NH4CI + F103 20 421 7 Acid 12% HCI 36 457 8 Mud Acid 9:1 Mud Acid 36 492 9 Overflush 3% NH4CI + F103 54 546 Foam (3% NH4CI + F103 + 10 Diverter N2) 4 550 11 Spacer 3% NH4CI + F103 20 570 12 Acid 12% HCI 36 606 13 Mud Acid 9:1 Mud Acid 36 641 14 Overflush 3% NH4CI + F103 54 695 15 Displacement 3% NH4CI + F103 211 906 TREE= 1 VVELLHFAD= MCEVOY 0FETY NOTES: WELL ANGLE>70°a 10894'.MAX 3 3 ut.S:43.8 a 11060'. H2S READINGS AVERAGE , ACTUATOR= BAKER C INITIAL KB.ELE 62 I I 125 ppm WHEN ON MI"'WELL REQUIRES A SSSV WHEN ON MI"'SEE PG.2 FOR PERVIOUS BF.ELEV= 27.8g WELLBORE"'CHROME LNR"" KOP= 2850' ,Max Angle= 94"@ 11030' 20'CONDUCTOR 110' 1 Datum MD= 10762' 2206' H4-1/2"HES X N?D=3.813" Datum TVD= 8800'SS 13-3/8'CSG,72#,L-80,D=12.347" H 2506' TOP OF r SCAB LNR -I 3018' I "•"-'44 3018' -{9-5/8"X 7"BKR ZXP LTP,D=6.290" 3036' --I9-5/8"X 7"BKR FLEX-LOCK HG D=6.310" Minimum ID = 2.370" @ 10902' 3-1/2" X 2-7/8" XO PIN '4 y �� 9444' I-9-5/8"X 7"BKR C-2 ZXP LTP& ►i TEBACK SEAL ASSY,D=6.151" 7"SCAB UR,26#,L-80,BTC-M, - 9453' i, .0383 bpf,D=6.276" d" 9461' H9-5/8"X r BKR MAC HGR,13=6.280" 9-5/8"VVHPSTOCK(03/12/05) -I 9594' 9-5/8"CSG,47#, L-80,D=8.681" ^-9594 i M LLOUT WIDOW(03-33B)9594'-9622' 10317' H4-1/2"HES X NP,D=3.813" -f 010338' H 7"X 4-1/2'BKR S-3 PREM PKR,D=3.875" I10362' -14-1/2'HES X NP,D=3.813" I10383' H 4-1/2"HES XN NP,D=3.725' 4-1/2'TBG,12.6#,L-80 TC-11, 01D= . P 10391' H7'X5"BKR ZXP LTP wfIEBK,D=4.450'I 52 bpi,D 3.958' -1 10395' ... I 10395' H4-1/2"VVLEG,13=3.958' 10409' -17"X 5"BKR MAC HYDRO HGR,D=4.430" 10417' H5"X 4-1/2"XO,D=3.980" TOP OF 3-1/2"X 2-7/8'LNR 10488' 1 10488' -J3.70'BKR DEPLOY SLV,D=3.00" .4 0,11 10509' --13-1/2"HES X NP,D=2.813' 7"LNR,26#,L-80,BTC-M,.0383 bpf,D=6.276" --I 10672' 0.4 il 3-1/2'LNR,9.2#,13CR-85 STL.0087 bpf,D=2.992" -4 10902' 0. 10902' -I3-1/2"X 2-7/8"XO,D=2.370' 4-1/2"PKR VVFPSTOCK(02/20/14) -i 10935' 4Il ►♦4 ►1 4-1/2"LNR,12.6#,L-80 BT M,,0152 bpf,D=3.958" -I -10936' ► R�4 MI.LOUT WINDOW(03-33C) 10936'-10946' 4-1/2'CBP(02/04/14) -I -11050 r 4 d 11409' H 2-7/8"PUP MKR JT w/RA TAG(03/04/14) PET4 ORATDN� � ' Ill 12655' H 2-7/8"PUP MKR JT w/RA TAG(03/04/14) REF LOG: ON XX/XX/14 . N. "i ANGLE AT TOP FERE:90"a 14035' ''`. .•�'i�m:74';'b PBTD H 14162' `- dpi' i♦�i . Note:Refer to Roduction DB for historical perf data �►�+�� ��i SIZE, SPF INTERVAL OpNSgz SHOT SQZ �.i�04►'�4. ..-.1� ��'• . 2" 6 14035-14135 0 03/07/14 :1 • I2-7/8"LM,6.4#,13CR 85 STL,.0058 bpf,D=2.441" -I 14200' DATE REV BY COMMENTS DATE REV BY COMIvENTS PRUDHOE BAY UNIT 03/01/86 INITIAL COMPLETION 03/27/14 PJC SAFETY NOTE UPDATE WELL: 03-33C 04/30/97 SIDETRACK(03-33A) 03/31/14 JNUJWU UPDATED 13CR-85 LW PERMrT No: "2131720 03/23/05 N2ES SIDETRACK(03-33B) 04/04/14 TB/JM) FNAL ODE APPROVAL AR Nb: 50-029-21142-03 03/08/14 NORDIC1 CTD SIDETRACK(03-33C) 05/13/14 PJC SFTY NOTE-DOGLEG URATE SW 11,TI ON,R15E 214'FSL&827 FWL 01/30/14 TB/PJC DEPLOY SLV DEPTH UPDATE 03/10/14 JMD DRLG HO CORRECTIONS BPEnpbration(Alaska)
