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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 9, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 03-07B PRUDHOE BAY UNIT 03-07B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/09/2024 03-07B 50-029-20220-02-00 219-182-0 G SPT 8524 2191820 3000 2603 2611 2608 2611 2 3 3 3 OTHER P Adam Earl 2/24/2024 MIT-IA tested to 3000psi for possible T X IA communication. None noticed. Passing test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 03-07B Inspection Date: Tubing OA Packer Depth 440 3330 3281 3269IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240225144402 BBL Pumped:6.1 BBL Returned:6 Tuesday, April 9, 2024 Page 1 of 1 From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Gas Injector 03-07B (PTD #2191820) AIO 4G.017 approved Date:Tuesday, March 19, 2024 11:49:04 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, March 19, 2024 11:13 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Gas Injector 03-07B (PTD #2191820) AIO 4G.017 approved Mr. Wallace, Gas Injector 03-07 (PTD #2191820) has been approved for continued gas injection with slow TxIA repressurization under AIO 4G.017. The well is now classified as OPERABLE. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 14, 2024 5:53 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>; Bo York <byork@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Gas Injector 03-07B (PTD #2191820) UE period extended while AA is reviewed Mr. Wallace, Gas Injector 03-07 (PTD #2191820) under evaluation clock has been reset per our previous correspondence. Please call with any questions or concerns. 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, March 14, 2024 12:27 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATION: Gas Injector 03-07B (PTD #2191820) AA request submitted Ryan, Your request to continue injection while the AA is processed is approved. I will endeavor to pull back the AA already progressing in our system and change the AA based on your new remote shut-in plan. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 14, 2024 12:12 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>; Bo York <byork@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Gas Injector 03-07B (PTD #2191820) AA request submitted Mr. Wallace, Gas Injector 03-07 (PTD #2191820) AOGCC witnessed MIT-IA passed to 3269 psi on 02/24. An AA request was submitted to AOGCC on 03/13. The 28 day under evaluation period expires on 03/17/24. With permission, we would like to keep the well on injection while the AA is reviewed. Additionally, we have confirmed that there is remote shut in capability for gas supply of 03-07 at DS03 control room. For item 7 in the proposed operating and monitoring plan in the submitted AA, we would like to revise to use the same wording that was used for AA AIO 4G-011 that was approved last year for 17-13. “Hilcorp shall maintain the FS2 plant or Drill Site 03 manifold building remote shut down capability for 03-07B when on gas or miscible injectant (MI) operation;” Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Sunday, February 18, 2024 12:49 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector 03-07B (PTD #2191820) Slow TxIA communication Mr. Wallace, Gas Injector 03-07 (PTD #2191820) has been under observation since operations all liquid IA bleed reported on 02/04/24. IA casing pressure has fluctuated between ~200 psi and ~650 psi during this period in a less than definitive trend factoring rate and temperature changes. However, DHD found IA liquid level near surface on 02/17/24 which is evidence of slow TxIA communication. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Pack off test tubing 2. Well Integrity: AOGCC MIT-IA 3. Well Integrity: Further monitoring / action as required including possible AA application for continued injection Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 4, 2024 12:37 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Gas Injector 03-07B (PTD #2191820) IA bleed Mr. Wallace, Gas Injector 03-07B (PTD #2191820) IA pressure has been fluctuating with recent temperature swings related to the Injection Gas. Recently, CGF lost a compressor causing the plant to go on blend back, further compounding the temperature swings. The IA pressure was recently bled from 1050 psi to 200 psi while during this blend back process. I am notifying you that we are currently monitoring the well. If it appears the well has any pressure communication, we will make it Under Evaluation and specify a plan forward. 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 deletethis 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. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the 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: UNDER EVALUATION: Gas Injector 03-07B (PTD #2191820) Slow TxIA communication Date:Wednesday, February 21, 2024 8:51:58 AM Attachments:03-07.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 18, 2024 12:49 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>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector 03-07B (PTD #2191820) Slow TxIA communication Mr. Wallace, Gas Injector 03-07 (PTD #2191820) has been under observation since operations all liquid IA bleed reported on 02/04/24. IA casing pressure has fluctuated between ~200 psi and ~650 psi during this period in a less than definitive trend factoring rate and temperature changes. However, DHD found IA liquid level near surface on 02/17/24 which is evidence of slow TxIA communication. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Pack off test tubing 2. Well Integrity: AOGCC MIT-IA 3. Well Integrity: Further monitoring / action as required including possible AA application for continued injection Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 4, 2024 12:37 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Gas Injector 03-07B (PTD #2191820) IA bleed Mr. Wallace, Gas Injector 03-07B (PTD #2191820) IA pressure has been fluctuating with recent temperature swings related to the Injection Gas. Recently, CGF lost a compressor causing the plant to go on blend back, further compounding the temperature swings. The IA pressure was recently bled from 1050 psi to 200 psi while during this blend back process. I am notifying you that we are currently monitoring the well. If it appears the well has any pressure communication, we will make it Under Evaluation and specify a plan forward. 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 the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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. 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: Gas Injector 03-07B (PTD #2191820) IA bleed Date:Tuesday, February 6, 2024 9:51:01 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 4, 2024 12:37 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> Subject: Gas Injector 03-07B (PTD #2191820) IA bleed Mr. Wallace, Gas Injector 03-07B (PTD #2191820) IA pressure has been fluctuating with recent temperature swings related to the Injection Gas. Recently, CGF lost a compressor causing the plant to go on blend back, further compounding the temperature swings. The IA pressure was recently bled from 1050 psi to 200 psi while during this blend back process. I am notifying you that we are currently monitoring the well. If it appears the well has any pressure communication, we will make it Under Evaluation and specify a plan forward. 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, please immediately 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. Wdl 03U7 420V 4d 3ECU 3" 34 320E 300V 280E Z SOV 2600 2200 2" 1 &U 1£p 140 1 p 1 U00 ECU ECU 6W 20� 11iC423 1111123 1111E23 11=1 1Z0223 12UW23 1E11623 1Z23fl1 12�WL3 01i 4 01;1324 012024 01,=4 MU24 TIO Plot f Tubing On ■ Bleetl + Operable + Notopet ♦ Under E.1 t MAN IA —� MAN_OA MAN WA MANOOOA MAN_WI 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 and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC 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 AOGCCCOMMISSIONER PBU 03-07B Well Status Update Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 219-182 50-029-20220-02-00 N/A ADL 0028327, 0028328, 0028331 14022 Surface Intermediate Liner Liner Liner 9023 2663 7940 2481 238 3785 14004 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4 x 2-7/8" 9023 30 - 2693 28 - 7968 7798 - 10279 10127 - 10365 10237 - 14022 30 - 2693 28 - 6752 6635 - 8708 8572 - 8782 8670 - 9023 None 2670 4760 5410 7500 10530 None 4930 6870 7240 8430 10160 13660 - 13780 4-1/2" 12.6#L80 26 - 101309024 - 9023 Conductor 80 20" 30 - 110 30 - 110 1530 520 4-1/2" Baker S3 Packer No SSSV Installed 10073, 8524 Date: Bo York Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL 11/18/2021 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 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:09 pm, Nov 04, 2021 321-570 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.11.04 14:55:44 -08'00' Bo York SFD 11/5/2021MGR08NOV2021 DSR-11/8/21 dts 11/9/2021 JLC 11/9/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.09 12:09:16 -09'00' RBDMS HEW 11/12/2021 MEMORANDUM TO: Jim Regg t^ P.I.Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 29, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 03-078 PRUDHOE BAY UNIT 03-07B See: Inspector Reviewed By: P.I. Suprvj97-- Comm Well Name PRUDHOE BAY UNIT 03-07B API Well Number 50-029-20220-02-00 Inspector Name: Austin McLeod Permit Number: 219-182-0 Inspection Date: 4/3/2020 , Insp Num: mitSAM2004040716I3 Rel Insp Num: Packer Depth 03-07B Type Inj a ''TVD 8524 - Tubing 2.191820 Type Test SPT Test psi 2131 IA Pumped: 5.2 BBL Returned: 5 OA Val INITAL PAF P y/ Notes: Pretest Initial 15 Min 30 Min 45 Min 60 Min 19'9 197] 1971 - 1965 113 '_599 2567 ?577 I G IS is Wednesday, April 29, 2020 Page 1 of I DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20220-02-00Well Name/No. PRUDHOE BAY UNIT 03-07BCompletion StatusWAGINCompletion Date3/6/2020Permit to Drill2191820Operator BP Exploration (Alaska) Inc.MD14022TVD9023Current StatusWAGIN4/16/2020UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD/GR/RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC3/18/202010253 14022 Electronic Data Set, Filename: 03-07B_LWD_FINAL_FIELD_COMPOSITE_21FEB2020_BHI_CTK.las32168EDDigital DataC3/18/2020 Electronic File: 03-07B_GR_Res_21FEB2020_MD_FINAL_FIELD_BHI_CTK.cgm32168EDDigital DataC3/18/2020 Electronic File: 03-07B_GR_Res_21FEB2020_TVDSS_FINAL_FIELD_BHI_CTK.cgm32168EDDigital DataC3/18/2020 Electronic File: 03-07B_GR_Res_21FEB2020_MD_FINAL_FIELD_BHI_CTK.pdf32168EDDigital DataC3/18/2020 Electronic File: 03-07B_GR_Res_21FEB2020_TVDSS_FINAL_FIELD_BHI_CTK.pdf32168EDDigital DataC3/18/2020 Electronic File: 03-07B Final Field Surveys.csv32168EDDigital DataC3/18/2020 Electronic File: 03-07B Final Field Surveys.xlsx32168EDDigital DataC3/18/2020 Electronic File: 03-07B Final Survey.pdf32168EDDigital DataC3/18/2020 Electronic File: 03-07B Final Survey.txt32168EDDigital DataC3/18/2020 Electronic File: 03-07B_25_tapescan_BHI_CTK.txt32168EDDigital DataC3/18/2020 Electronic File: 03-07B_5_tapescan_BHI_CTK.txt32168EDDigital DataC3/18/2020 Electronic File: 03-07B_output.tap32168EDDigital DataC3/18/2020 Electronic File: 03-07B_GR_Res_21FEB2020_MD_FINAL_FIELD_BHI_CTK.tif32168EDDigital DataThursday, April 16, 2020AOGCCPage 1 of 303-,07B_LWD_FINAL_FIELD_COMPOSITE_21FEB2__ _020_BHI_CTK.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20220-02-00Well Name/No. PRUDHOE BAY UNIT 03-07BCompletion StatusWAGINCompletion Date3/6/2020Permit to Drill2191820Operator BP Exploration (Alaska) Inc.MD14022TVD9023Current StatusWAGIN4/16/2020UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:3/6/2020Release Date:12/11/2019C3/18/2020 Electronic File: 03-07B_GR_Res_21FEB2020_TVDSS_FINAL_FIELD_BHI_CTK.tif32168EDDigital Data0 0 2191820 PRUDHOE BAY UNIT 03-07B LOG HEADERS32168LogLog Header ScansDF4/9/2020 Electronic File: 03-07B_RBT_01MAR20.dlis32472EDDigital DataDF4/9/2020 Electronic File: 03-07B_RBT_01MAR20.pdf32472EDDigital DataDF4/9/2020 Electronic File: 03-07B_RBT_01MAR20_DLIS.zip32472EDDigital DataDF4/9/2020 Electronic File: 03-07B_RBT_01MAR20_img.tiff32472EDDigital Data0 0 2191820 PRUDHOE BAY UNIT 03-07B LOG HEADERS32472LogLog Header ScansThursday, April 16, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20220-02-00Well Name/No. PRUDHOE BAY UNIT 03-07BCompletion StatusWAGINCompletion Date3/6/2020Permit to Drill2191820Operator BP Exploration (Alaska) Inc.MD14022TVD9023Current StatusWAGIN4/16/2020UICYesCompliance Reviewed By:Date:Thursday, April 16, 2020AOGCCPage 3 of 3M. Guhl4/16/2020 1a. Well Status: GINJ Oil 1b. Well Class: Exploratory Service 5 BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 219-182 2/15/2020 2/20/2020 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 1316' FSL, 812' FWL, Sec. 11, T10N, R15E, UM 1528' FNL, 2295' FEL, Sec. 15, T10N, R15E, UM 1369' FSL, 2924' FEL, Sec. 10, T10N, R15E, UM Surface: x- y- Zone -714073 5937379 ASP 4 11. Gas SPLUG Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG 5 WDSPL No. of Completions: 3/6/2020 15. 50-029-20220-02-00 16. PBU 03-07B Well Name and Number: 14004' / 9023' 25.58 17. TPI:y- Zone -711052 ASP 4x-5934449 Total Depth: x-y-Zone -710337 ASP45937327 14022' / 9023' 2190' / 2190' DNR Approval Number:19. 74-017 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD / GR / RES CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 9-5/8" 7" 4-1/2" 3-1/2"x3-1/ 94# 72# 47# 26# 12.6# 9.3#/6.6 MN-80 RS-95/MN- L-80 L-80 L-80 30' 28' 7798' 10127' 10237' 7968' 10279' 10365' 14022' 30' 28' 6636' 8573' 8670' 8708' 6752' 8782' 9023' 4-1/4" 6-1/8" 8-1/2" 12-1/4" 300 sx PF II 1075 sx Class 'G' 276 sx Class 'G' 444 sx Class 'G' 195 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 4-1/2" 12.6# L-80 10130' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: March 28, 2020 Gas Injection Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: 13660' - 13780' Open to production or injection?Yes 5 No 24. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 13660' - 13690' 9024' - 9024' 13720' - 13750' 9023' - 9023' 13750' - 13780' 9023' - 9023' H-40 110'32"20" 13-3/8"30'2693'17-1/2"5800 sx PF II30'2693' 10073' / 8524' 350 Bbls 3% NH4Cl, 110 Bbls 3% NH4Cl + Musol Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 110' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028327, 028328 & 028331 319-586 Other 12. SSSV Depth (MD/TVD): 2" Gun Diameter, 6 spf 3/5/2020 - 3/6/2020 Ref Elevations BF 27.62 (attached)5 KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 55.50 Water Depth, if Offshore:13. N/A One API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 10365' / 8782' 1900' (Approx.) Submit within 30 days of Completion, Suspension, or Abandonment [ By Samantha Carlisle at 8:15 am, Apr 06, 2020 G DSR-4/6/2020 Completion Date 3/6/2020 HEW RBDMS HEW 4/8/2020 SFD 4/6/2020MGR13APR20 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Hyatt, Trevor Contact Email: Trevor.Hyatt@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 907 564 4627 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 10401' 10527' 10600' 10690' 8813' 8929' 8989' 9042' Sadlerochit - Zone 4B 42SB - Zone 4A CGL - Zone 3 Base of CGL - Zone 2C Zone 2C 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 10690'9042' Top of Productive Interval 10690'9042' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Daily Drilling Reports, Summary of Post-Rig Work, Survey, Cement Report, Wellbore Schematic DiagramList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.04.03 14:50:45 -08'00' 2 6 13690 - 13720 O 03/06/20 mgr !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 (<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 &'(('&& 7! 9:1 !7 ((60 ?79 " %! 1! 39:!110 39:1!! @!@%/ !3 3!110 7!A 9: !9 !% (&0 +0+(&. 7! 7!A 9:1 !7 % ! %%(0+&&(& 7! :% %9 9:! 9:7 ! 9%0 (0+&& &'(&'&& 7! 379 " 9:7!A !% !9 !% *0* 7! 7!A !9 !%%% ( ! % 0 7!A?0 ?79 " 0 7!A3!A % %!0 ! 9 7!%30 9:.0 0((* 9:3 9:3"9 0 "!!3 790 "!!39 ! 90 ! 3,99 BC397 0 3 " 9 -B AA0 &0((( !3 : :!!% 9:" ! AA0 "!!37%90 7!A -9 !0 ":!3 3 7 ":!11% :9D !9 "9? ! : AA- (E &AA " ! C3! 1: !7 AA"9 !9 " !3:" 9: 9 13"!999 "+7!"%1 " "% !37!B0+ (7 % !A 97 3 93 93:7!A9: 9 0 3 % !93: %!9-% 3 ! 9: 0 9: 9:!9: " !3:" ,9 9:" !!791 !D30 " !3 %!%!9 ((0( &'('&& !3 13"!99 "1 " 9: 3 !3 9: 13"3 199 "1 " " !+9 0+ ) &*7*'&'&& **All depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 &<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 !3 ! %!: % %09 9A%B!:B :3B!! ('(.F3 -9%'" -& +'/F9 '9-73%,-& '/FG ('&FA 9-& +'/F 9'9 &+9!'+9"9:" 1! +79" (9 A-!11-6E( % &9%'" - (-(-(-* 3 #& +'/F$- 9H&--&- ( *3 & +'/F9'9- 9H&- &- &- &-(+ +(.- (-(( .A #& +'/F$--6-(- A& ! & +'/F9'9-+-.- /- A( /"!-"! 7!A ?!9 -9 A 3 !7!A ('&F 9! ! 7 63 # ('&F$-(-* ( A # ('&F$-&- *0+/ 9:3 9:%! C397 0 % 9:1!! 0 9 % 99: 9 0 : 0 (06/ 9:3 3 73%370 93 ! A 9 3 0 3 !11(1 !1 !: 93 ! "%!1 0 7!A9? ! !A -7'3 !0 ?71! 379: %0 &0((6 9:3 37+0+7 %9 "(.%: 1 " */9-!7!A7 0 37( " !3:" 0 3 :37A 97-:!3% %!! " 0!7!A7 " %0 "3 %!% 1 139% !39% 390 !!11%""979,9: 3- 997! !3 (1 ":9:!3 0 &0((( 9:3 3773%39 1!!%B1 " +0.7 *90 371! &79-! "9:" %0 3 : 3 3 !9 / #% !AA$!7!A7 0 7!A139% !3%9 !7 !!7 1! (0*H73%0 "97!A9:139% !3%!!11% "9 - 997! 0 &0(+( 9:3 37(0*H 90 9 "(0*H 9 "B !3% 37*0.7 */90!7!A7 0 B373%%!0371! ( 79-!7!A7 0 (0&+(.(+(+ ) &*7*'&'&& **All depths reported in Drillers Depths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ll depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 *<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 9:3 9 !9 39:! ! 9 9: 739? ! %37 1! % 9:37 3 !+0+7 %B 99&793 - 7!A 9? ! %!9 1!3%0 739? ! % 9:37 3 !+07%%37 3 A 97" 9:9 7!A7 " 971! "! 9700 7!A 9? ! %!9 1!3% 739? ! % 9:37 3 !+07%%37 3 A 97" 9:9 7!A7 " 971! "! 970!9 /%39% 3 !9% %37 3 " 9:9 7!A " 3 :!%! (+ 909 !3%99 9 9? ! 0 7!A9? ! %!9 1!3% 739? ! %0!9 / %39% 3 ! *9 %%37 3 " 9:9 7!A " 3 :!%! (+ 91! !3 &!%0 9:9: 373 3 % !9:9 !3%99 9 9? ! 0 7!A9? ! %!9 1!3% ! % &!1" %1 " 739? ! %0!9 / %39% 3 ! *9 %%37 3 " 9:9 7!A " 3 :!%! (+ 91! !3 &!%0 9:9: 373 3 % !9:9 !3%99 9 9? ! 0 7!A9? ! %!9 1!3%0 739? ! %0!9 / %39% 3 ! *9 %%37 3 " 9:9 7!A " 3 :!%! (+ 91! !3 &!%0 9:9: 373 3 % !9:0 !9"!% 3 3 ! 9% "!3"!"9 9379:-" !7!A7 !1 9 0 !9 /%39% 3 ! *9%%37 3 %9% ! " 9 7!A" 3 :!%! 7!A9? ! %! 9 1!3%0 39%9:"9A99 739? ! %37 1! % 9:37 3 !+07 %B 99&793 - 9""9 A99 %B379&+!16 A"9A999 !!9% 7 ! 3 ::99 " /:9" 9: +0++ ) &*7*'&'&& **All depths reported in Drillers Depths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ll depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 .<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 &'(+'&& % 9 3 !9' "% 3 !9%"9A B&I 3 0 : :!!% !91 3 9:/I!1!91! ! !1(/I 3 9:%!"B% 393 0 A% 7!9 9 %%97!9 3 !.+ +0+ !%( % 9 9 "9"%% -:!!%0 "-:!!%0 ! ! -:!!%0 9 ! 9!-:!!%0 &0++ !%( % 9 9 :9 ! -7'39? ! !0 371! % *06 +7'*+9 1! 790 !!11- 7!A:9 ! 0 ""9"%-:!!%0 7'3"H&09? ! ! /*0 AA"!9 ! 0 9 9? ! - % 0 (0+6 !%( % 9 9""H&0 37*0+7 " !3:"!%0 %3%% !9%!% J(0+:0 &0+((6 !%( % 9 (-+*+0 9 9% "1 !7(&6I0! I0 !%0 9" " !3:"9%! 37-(+ -& 1 '790 9:" : (/I0 93&I% % 99:0 (0&H% 9%!0 % 91 !7(//I !(-+*I 73%9:" 9'!3 9/0+'/0/:0 !9( &1 '" &0*'&0/&7 &/ 90 (+&+I37+!'"9A90 % 9 !(+*+I .0&+(*+(( !%( % 9 (-+*+0 9 ' 99 9 !!"?!::9:+I!9%! 3 " !3:"9%!%!% 99 (I0I! 9! 1! 71 !7((I (&/I !% 99 ! (I 9" (0(/*+(*+ !%( % 9 (-60 % 9* ('*K39%(+*+I (6I#39% 9! %$ 1 9&+9-&0/67 &0/679-&0/.7!3 09 3 +L.9 73%9:" /0/:9-/0/.:!3 - 9%!%(0(.: ! .1 '" -!&0+L*0 +0&+(/*+ !%( ) &*7*'&'&& **All depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 <( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 &'(.'&& % 9 (-60 !!" 37+,+!'"9A9 !!" !9%!379: &0&7 79 99: (0( (0&:% 9%!0 ?!:+I 9! !39: " !3:" 9%!-3 " !3:"9%!9 "! 93 !% %99: !60/:139%0 !!" 7!9 ! 3 1 9 "!%?71! ""%9:"9 7!9 ! 9: 0+*+ !%( % 9 (-60 ""% 9? ! !11 *+" 9 (I!9%19%:!3: ((I1 31 !7!9! ! 0 9%B%!39%" (0**+*+ !%( % 9 (-60 13 9! !1 !7% 9 9! :!!% 13 9! 3 -3 E! &+'/F 99 7-&'/F,('&FA 9- 9%-"!E9" 0++(+**+ !%( % 9 (-60 ?71! ""%9:0 7'3"H0 9? ! ! .&+0 (0&+.+(+ !%( % 9 (-60 9""H0 "!"! :9 ! 9 "60/H 73%0 !!7! &70 !%-! 93 9"0 9 9% "-! .I0 9%!% !/0/H 73%0 !%0 9" " !3:"9%! (+ -37-& 1 '79! "9:0 +0((. !%( % 9 (-66+0 % 91 !7(6 !(66+I !9 /1 '" 9 "( %!0 73% 9'!3 9/06'/06:0 37&0/7 + 690 (6&I37+!'"9A9 !3%0 (6*I3(+I9 9- 3%%!0 0+(+(( !%( % 9 (-66+0 (66+! 3 9-! 9 93 3 0 !7 "9:9"3::%!110 !379:&0&*7!3 +90 !:9 9- 3 9 "9:" "B0 3 " !3:"9%!%!%0 9"%? "9 ! B0 37(!'"9A90 !!"37 9:9%! % !3%(0+:0 %9 9%! !60/:139%0 (0&+(.(+(+ !%( ) &*7*'&'&& **All depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 /<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 % 9 (-66+0 !!" 379: 0+7"!%9:(0+% 9%! 7!9 ! 1! 793 9 "!%?7"97!9 ! 9:1! ""%9:0 0&+(6(.(+ !%( % 9 (-66+0 ""% 9? ! !11 (6" 9 (I!9 %!"!!9:1! ! 3 9!0 19%77 "A9:('*F ('&F9 9D99 - !!1:9 ! !!% - !!17! ! "%!7% 9 " !3%! "0 ":!3 7! ! %:9 ! - ""9:" 3 !73% 370 9? ! ! &" C !+9 :!!% 7"9 3 % (0+&((+(6 !%( % 9 (-66+0 9""H* "!"! :9 ! 9 "60/H 73%0 !!7! (0+7; (6*9-&07;+69 !%-! 93 9"0 9 9% "-! .I0 9%!% !/0/H 73%0 &0+&((+ !%( &'('&& % 9 (-66+0 9%!% !/0/H 73%0 !%0 9" " !3:"9%! (+ -37- &1 '79 (0&+((+ !%( % 9 ((-(**0 % 9* ('*K (66+I (((**I 1 9&&9-&0/*7 &0/*79-&0/.7!3 09 3 +L.9 73%9:" /06+:9-/06/:!3 - 9%!%(0: ! .1 '" -!&0+L*0 0*(+((+ !%( % 9 ((-(**0 39! % 9% !(((** !3% 39:"AB 79,9: "3 %!37 9:(0&% "9%!! ! ,-3 &, !6+9 "!7!A7 B9!7! 97"979,9: %9!71 6 9 9 99 :-! @&1 0 &0.(+*(+ !%( % 9 ((-*+0 ! 93% 99:1 !7(((**I !((*+I 73%9:" 9'!3 9/06'60:0 !9* /1 '790 37&067*91 90 ((&6I3(+I9 90 3%%!0 ((**I37+!'"9A9 !3%0 .0&+(&.(+ !%( ) &*7*'&'&& **All depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 6<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 % 9 ((-*+0 !:9 91 !7((*+I0 ?!:!9%!0 3 " !3:"9%!%!%0 ? "9 ! B0 33 !*+I37*0+7 ! : 9!0! 73"%%9 9! 3 9: 3 %0 99! 9!@+0+F !%0 9" " !3:"9%! (+ -37- &1 '79 +0+((& !%( % 9 ((-/(0 % 9* ('*K ((*+I ((/(I 1 9(9-&0/*7 &0/.79-&0/*7!3 09 3 *L.9 73%9:" /06.:9-/06/:!3 - 9%!%(0+: ! .1 '" -!&0+L*0 (+I9 9 ((.I (+I9 9 ((+I .0+( !%( &'(/'&& % 9 ((-/0 % 9* ('*K ((/(I ((/I 1 9+9-&0/7 &0/&79-&067!3 09 3 .L+9 73%9:" 60:9-60+:!3 - 9%!%(0+*: !& 1 '" -!&0+L*0 ! A&999! 3 3 3 !! 7 &+"!3 : 9:%3 AB B ! B ! !7% !! 9: 9:% 3 AB0 (0( !%( % 9 ((-/0 !!"1! 7% !! !!"379: !79 9% !3% (0+: 9%!0 ?!:9"!(I (/I %337 !0+71 !7(++I !9%! 3 " !3:"9%! !%%%9 !60/: 139% !!"%?3 9:37 ! 79 9% !3%(0+: 9%! ! (I-(791!"9:!!%0 *0++( !%( ) &*7*'&'&& **All depths reported in Drillers Depths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ll depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 ((<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 % 9 (&-&.0 9 91 !7(&&.I 3!3 !((/"9: &06 7 ?!:(I ((/ %337 !0+71! "1 !7(++I !9%! 99 ! :! 9!@* 39"! &0&+&(+&( !%( % 9 (&-*0 % 9* ('*K (&&.I (&*I 1 9&69-&0//7 &00//79-&0/(7!3 09 3 &L+9 73%9:" /0/:9-/0/*:!3 - 9%!%(0*: !. /1 '" -!&0L*0 0+&(+ !%( &'(6'&& % 9 (&-(0 % 9* ('*K (&*I (&(I 1 9&69-&0//7 &00//79-&0/(7!3 09 3 +L.&9 73%9:" /0/:9-/0/*:!3 - 9%!%(0+: !. (1 '" -!(0L&0 (+I9 (&*(I (+I9 (&+.I +0+ !%( % 9 (&-(0 !:9 91 !7(&(I0 9%!37+!'"9A9 !3%0 1! 7?!: (.I %337 39: " !3:" "939% 9!0 3 " !3:"9%!-? "9 ! B0 3 !*+I37*0/7 90 0(&+ !%( % 9 (-(.0 % 9* ('*K (&(I ((.I 1 9*.69-&0/.7 &00/.79-&0/(7!3 09 3 +L.&9 73%9:" /06:9-/0/+:!3 - 9%!%(0+.: !. (1 '" -!(0+L&0*+ "9 A B(+I% 9% .0+(/(& !%( % 9 (-(.0 !:9 91 !7((.I0 9%!37(!'"9A9 97% ! %1 39: " !3:"9%! 1! 7?!: (/I %337 39: " !3:" "939% 9!0 3 " !3:"9%!-? "9 ! B0 7 99 (&&I! 9!@&0+I 37!3 !1"! !%!"! !%%! 9 (M " !3:" 9%! 9" *0&&(/ !%( ) &*7*'&'&& **All depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 (&<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 % 9 (-&/0 % 9* ('*K ((.I (&/I 1 9*(9-&0+7 &0+79-&0(7!3 09 3 +L.&9 73%9:" /0/6:9-/06&:!3 - 9%!%(0+.: !. (1 '" -!(0+L&0*+ "9 A B(+I% 9% (0+&& !%( &'&'&& % 9 (-.(0 % 9* ('*K (&/I (.(I 1 9&+9-&0+7 &0+79-&0.7!3 09 3 *L++9 73%9:" /0/6:9-/06&:!3 - 9%!%(0.&: !. (1 '" -!&L "9 A B(+I% 9% *0+**+ !%( % 9 (-.(0 !:9 91 !7(.(I0 ?!:!9%!%3 " !3:" 79 !%9 "9 %-37 7, 1! ! !73"9 99 ! % "@I ! !733 9:9 %% N& O " 9-!%% 9" +0&+(**+ !%( % 9 (-//*0 % 9* ('*K (.(I (//*I 1 9*+*9-&0.7 &0.79-&0/7!3 09 3 *+L++9 73%9:" /0/:9-/06.:!3 - 9%!%(0./: !. (1 '" -!(L "9 A B(+I% 9% !!%%! (I-:77 "!9:7" !73% 0+(( !%( % 9 (*-&0 % 9* ('*K (//*I (*&I 9! %3! % 1 9&/9-&07 &079-&0./7!3 09 3 *+L++9 73%9:" /0:9-/06:!3 - 9%!%(0+*: !. (1 '" -!&0+L* "9 A B(+I% 9% +0+&(+( !%( % 9 (*-&0 9 9 "!3 !1!"! 379: &0.79'&067!3 0+&(+ !%( ) &*7*'&'&& **All depths reported in Drillers Depths** !"! # !$ % &'(('&& )% &'&('&& 2 3 4 '0% & 5)% ' 6'('(6.(&7 4 8 4 ! % 99:90 3!93(/ ) 5;++0+58<# = 7 $ 4 (<( 1 % #58<$ ) 8> % 8 <! 8"8 #$ % 8 &'&('&& % 9 (*-&&0 9 9 "!3 !1!"! 379: &0.79'&067!3 9%!37(!'"9A9 97% ! %1 39: " !3:"9%! 1! 7?!: (/I %337 39: " !3:" "939% 9!0 3 " !3:"9%!-? "9 ! B0 7 99 (&&I! 9!@+I 37!3 !1"!9 !1&O9 " 3 1-9 1! 3 !3% 9" !%%! 9 (M " !3:" 9%! 9" 37(!'"9A9 97% ! 9 %0 : (*&&I %! % 0+*+ !%( % 9 (*-&&0 9 9 ! "!3 !1!"! 379: &0/79'&0+*7!3 ?!:!9%!-3 " !3:" 9%! 79 !%-? B%!!" 379:9 " 93:" " : 9! %3%% +I1 !73 1 1! 7(+I?!:% ! !!" :3- % "% 9"379: 06.79'*0*!3 (6+9 !: 99 (&6I ! % " .0+I-!%% 9" ! %%!% "-3% %B791!" :!!%1!"- 9 9 %! !!"B9:99 99 "% 1!!%B60/1 !!"9 9:!1: 6+0.6I 1! %%.*/0.61! "9%! 1!" 3 1 9 "!%?71! ""%99:%3 9: 1!" (*0+(/(+*+ !%( % 9 (*-&&0 ""%9: 9? ! !11 (/&" 3 "9? ! %9 (I !1!9 % ""-9 P & ! , 9 % (0(6(+(/(+ !%( % 9 (*-&&0 13 9! !1 !7% 9 9! :!!% 13 9! 3 -3 E! & +'/F99 7-&'/F,('&F A 9-9%-"!E9" Q9 " !! ! (( 0&+(6(6(+ !%( ) &*7*'&'&& **All depths reported in Drillers Depths** ! " #$ % & '(')('' *& 3 4 # 5 (1&# ' 6*& ( .()().0)'! # 5# 7 # 5 #𕮕 4 84): * 6;,,1,67<$ = ! % 5 )<0 2 & $67<% * 7> & 7 < 7"7 $% & 7 '(')('' 89 )+/''1 ##2 ## &4 8 8##4 #! ?4@ !4# ?#2# !'(:A ))('A! '(:A /4)B 2' (: &!48B # 84 :1:9@48& #894!4 +10! 4 # 8 "28# "#8! ?89 2 #' &/4!&&8 8 , !84 &C4!&# ! ?! "#&1 ! 224! #:#48/ #:& ! 8 "4!4 +1::! ! ?! "#&1# 28B #&28&)1,D 2 28&88&89" C ).D/ 8& ? "))('A! 8 / 4 "# #8 8 8489 "8891 4 '(: B 8 2 #B 8 2 '(:A 0 8!8 " # ?#8 " "# #8 8 1 #894! +1:!&"# 8! ?892 #+ &/ ! 22 4! #:#4 8/ #:& ! 8 "4! 4 +1::! ! ?! "#&/ # 28B #&28&,,1D 2 2 # 2+D4!& 4 1 !48B #;! +1:!&& "#8 ! ?89/ ! 224! #: #48/ #:& ! 8 "4!4 +1::! ! ?! "#&-'/# 28B # &28&D 22 # 2+D 4!& 4 1 #! ?& " 4 # 8B # &# !498 #8 " EE " ! 2,B 2'(:A 0/!4 8B #;! 1 !&4 "#8! ?89 4 2?8# 8 4#214! 2 #)!84 1,!1 # 28B #&28&)D 2 2 # 2,D4!& 4 ?89 ),D8# C& ,B 8 2 0&# 98 #& EE11 +1,). #4#& * )':!+('('' **All depths reported in Drillers Depths** ! " #$ % & '(')('' *& 3 4 # 5 (1&# ' 6*& ( .()().0)'! # 5# 7 # 5 #𕮕 4 84): * 6;,,1,67<$ = ! % 5 '<0 2 & $67<% * 7> & 7 < 7"7 $% & 7 '(''('' 89 )+/''1 ##2 ## &4 8 8##4 C& ,B 8 2 0&# 98 #& EE11 8 &##8/8B #&# # 98 8 #8 & " 4 # # &8B #1 4 &298#B 8 88 "&8 "#28& "881 !4 89#&4!(:A 2 89 ## &4# +1+ !2 #:1 "#8# # ?#& #4# #. 8/ #.&4! +1+!/#8"'D& "'D2 #:/ ! ?! "#&/ # ?#& 4!)"8?8/ 8 #.#4 8/ #.&4!&&8 8 )"8?8 2 &C::1:9 @48#8# 8'D8 " 1/ # ?#& # 22 EE&"4 8 # !4#8 9 89&9&1 1 8 4"# 4# 4"&1 4!)"8?8/ 8 #.#4 8/ #.&4!&&8 8 )"8?8 1 # #4898" )0D1 2 8 "::1:9 @48 ,1,, #4#& * )':!+('('' **All depths reported in Drillers Depths** ! " #$ % & '(')('' *& 3 4 # 5 (1&# ' 6*& ( .()().0)'! # 5# 7 # 5 #𕮕 4 84): * 6;,,1,67<$ = ! % 5 <0 2 & $67<% * 7> & 7 < 7"7 $% & 7 89 )+/''1 # ?#(:AR 2# !# /4 !4#"C& &841 " C"#& # 892 # 8C#1D #?#8#4 & ! ? "8# !498 #&),B 2' (: 8# #C&! ? "8# 2# 4 " ! ? "!4/#8")D&8# " ?# :10!4& 88 "4! '1! ?8# 8 8 '10!/4" ,D/8## '1.!" #C89&822# # '1.!8"8 899 & 4!&2 #!8C8982# ! ,D )D8 "9 &?8# 8 2# ! "98 # '1.! 94/4 "8B #&# 4 " 28# 82 "8 8 "- 2#8 "4 F & &"?F8 8&4! +1! '.8"8#8" & &"?F8 8&4#9 #4#"8#8" 94/#! ?8B #&" 2 # #8#! ?! #8#! ?! /!4 98 # ),B 28# #8" )D&889 8 .1:2 "#8" "8& C4!# 4 +1', 4!), 2"8?8/#4# #. 8/ #.& 4! +1+!&4! "#), 2"8?81#4# #. 8/ #.&4! +1+! 4!: +! # 2# ! 8/ "89 ? 84!89 '1,+!12 " 2 #)!84 # 228B # &&8 8 88/28& 8 #/ !9 8&28&1# 8 C& ),B 8 2'(:A 8# R # ?#& 2 98 #1 #892 # )1,', #4#& 89 )+/''1 8 8B #&## 98 #24 8 #98E8"&/ "9 4 !# 8B # #! ? # 2# !8"&&"8 #1 &84 8 8 " !1 8 )1' #4#& * )':!+('('' **All depths reported in Drillers Depths** ! " #$ % & '(')('' *& 3 4 # 5 (1&# ' 6*& ( .()().0)'! # 5# 7 # 5 #𕮕 4 84): * 6;,,1,67<$ = ! % 5 +<0 2 & $67<% * 7> & 7 < 7"7 $% & 7 '('('' 89 )+/''1 #?8 ?/ "9 889) #8942 #2 ##4898#1 )1) #4#& 89 )+/''1 #48# " &B!8 "#2 ##489 8# !4" # "2 2828# ,B 8 & "?#C B 8 " &8"8 #889 B 8 '.8 "!8"4"# 4#&$8!4 &%8++ &1 "  #8"8 #889 Q #48#2889?#C B 8 1 8#&# D!4/B!8 "&C # 4 "& C! # #8 ?#18# G'+1 "9 22& C! #84# & #' ,(:A !8D ! ?8B # ?#&!4 " 8 )'1)) #4#& 89 )+/''1 #889 8B #!4/@ &/#8" 88 "4! # &889 8 :1:9!4& 8& 29& ## & ")01)'D )/'0,D 288"&8898#F8& 8 ":1:!4& 4 "8& G0'/#8"8 " 8#" &89+,8" 1:D 22 )D 22 &29 9 & )+'D & )/4D #48& 28#! & )+'D &8 ./:9248& #&4894!# !8 8 !" #4#1 8 ".1:9 ? "8## 2# !9/4#&# 2+8&89" 2/ # "# 8!8 "!#4 1 &84#4 8 " &1 &82# ! 28# .1:9248&1 #2 #!)!84 2 "/ 2 01',).),) #4#& 89 )+/''1 " '!8()1+! 4 1 ! 8 #2 #)!84 2 " &B!2 #""&89"8 ! 8 #89 '1:')').), #4#& 89 )+/''1 C& 8##489" # 228B # ')', 28&)'D 28"989 4 2 4 8&!99#! 28 1 C& 8##489" #892 # )10'')' #4#& * )':!+('('' **All depths reported in Drillers Depths** ! " #$ % & '(')('' *& 3 4 # 5 (1&# ' 6*& ( .()().0)'! # 5# 7 # 5 #𕮕 4 84): * 6;,,1,67<$ = ! % 5 ,<0 2 & $67<% * 7> & 7 < 7"7 $% & 7 #89& )+/''1 2#E# !4 EE" #8" ',D2 #2#E# 1 B!8 "##2 #4!89 &81 )1' '('+('' #89& )+/''1 2#E# B!8 "##2 #4!89 &818 " !89# ##4# 84!, &8 ",! "1 "8 "2#" #2 #4!89 &8 # 9 & 1 4!,&8 4 2 8 " "))1 ??##?8& #1 & "! #??1 & 89# '1,' #89& )+/''1 4!(:AR B!8 "# #! ?8B #& 4 2 2# !2#E# #4/!4 B 89 EE1 !48B # 4!(:A2 89 # # &4# +10!2 #:1 "# 8# B 8 "B 89 EE '1, !1 89" ! #& 8 " # ,81 9 & #! ?8B # #" 8 2 # R # ?#&1 & 88 "8"88 & #&) 2 ! " & ' " &B!8 " #&' # & # # 898 +,8 ,1,:' #89& )+/''1 4 89 8 4 :D 2 8 8228& "8#& & 88 "# 4 :'D 8#& # &88 !& & & #&! 4#- 8 - # /4 !4 89#F EE & 8& "@ " &B! & & #8 "',2 ): 2! "4 & '&& 22 #4# 48B #&4 22 ,1): * )':!+('('' **All depths reported in Drillers Depths** ! " #$ % & '(')('' *& 3 4 # 5 (1&# ' 6*& ( .()().0)'! # 5# 7 # 5 #𕮕 4 84): * 6;,,1,67<$ = ! % 5 0<0 2 & $67<% * 7> & 7 < 7"7 $% & 7 #89& )+/''1 #&! 8 89" & 24"4#288 "2#" #& & !?H'& !?H) 9 & !?H'& 9 & &! & /8 #& ,8 II##89;):II ,1):) * )':!+('('' **All depths reported in Drillers Depths** ACTIVITYDATE SUMMARY 2/26/2020 T/I/O=0/0/0 Removed tapped blind from top of Swab valve, installed tree cap bonnet. R/U lubricator, set 6" CIW "J" TWC #424. Performed LTT... Pass. Shut Master, R/D lubricator. Removed Kill line #02, Test Spool #01 and CDR tree #01. Installed production tree Tag #116. Torqued to API specs. R/U lubricator, PT'd through lubricator against TWC 300/low..5000/high 5 min each... see "Field Charted Tests" Pulled 6" CIW "J" TWC #424. Shut barriers, R/D lubricator. FWP's 0/0/0 see log for details M=O, SSV=C, SV=C. 2/26/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid MIRU CTU. Stand by for weather ***Job Incomplete*** 2/28/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid PT MHA. MU & RIH with memory logging BHA and 2.25" nozzle. Tag PBTD at 14,000'. Circulate 9.8# brine out of well with 1% KCl w/ safelube. Paint RED flag at 13950' CTM. Log from TD to 9900', POOH. Pump 1% KCL w/ Safelube down backside while POOH. Confirm good data, correlated to Liner Tally dated 2/23/2020, +9' correlation. MU & RIH w/ 2.13" Alpha One Trip Cement Retainer. ***Job Continued on 2/29/20 WSR*** 2/29/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid Continue RIH w/ 2.13" Alpha One Trip Cement Retainer. Set retainer at 13989' mid- element. Pump 45 bbls 15.3 ppg cement behind liner. Pump powervis across liner top and displace to 1% KCl to surface. MU 2.25" nozzle and RIH jetting 1% KCl w/ safelube from surface to PBTD. Tag PBTD at 13,990' and POOH jetting 1% KCl. ***Job Continued on 3/1/20 WSR*** 3/1/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid MU & RIH w/ HES RBT cement logging tool. Log up at 30 fpm from 13,956 to 10,000. POOH. Download RBT data. MU & RIH w/ coil memory flag and 2.31" nozzle. While RIH at 10111', Chain peanut found on ground, stop pipe. Stand by for manlift to inspect/repair injector. ***Job Continued on 3/1/20 WSR*** 3/2/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid Pump 30 bbls 60/40 down backside for freeze protect. Continue stand by for manlift. ***Job Incomplete*** 3/3/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid Inspect injector for repair. ***Job Continued on 3/4/20 WSR*** Daily Report of Well Operations PBU 03-07B See Halliburton Radial Bond Tool log for CBL. Daily Report of Well Operations PBU 03-07B 3/4/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid Inspect injector for repair. Replace fork and peanut. POOH. Perform chain inspection. Perform weekly BOP test. MU & RIH w/ HES GR/CCL memory logging tools and 2.31" JSN. Tag TD at 13979' CTM. Log up at 50 fpm to 10100'. Paint YELLOW flag at 13700'. POOH. ***Job Continued on 3/5/20 WSR*** 3/5/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid Finish POOH with logging tools. Confirm good data, correlate to Baker MWD log dated 2/23/2020, +10' correction. Standby for weather. MU & RIH with 2" SLB PJO gun #1. Perforate 13750 - 13780. POOH. MU & RIH with 2" SLB PJO gun #2. Perforate 13720 - 13750. POOH. ***In Progress*** 3/6/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid Continue to POOH. MU & RIH with 2" SLB PJO gun #3. Perforate 13690 - 13720. POOH. MU gun #4 and RIH. Perforate 13660 - 13690. POOH. Injectivity test down BS of 1.9 bpm @ 2000 psi. MU Baker Pressure Indicating Seal Sub. Sting into liner at 10227'. Inject into liner at 3800psi/1.5bpm using slick 1% KCL. Confirm liner lap injectng at 1740psi/0.3bpm. POH. ***In Progress*** 3/7/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid Change packoffs & check chains. MU 2" JSN and RIH for Acid treatment. Load well with 3% NH4Cl and 40 bbl diesel cap. Pump acid treatment down coil. POH, pumping displacement. FP well w/ 50bbls of diesel. Blow reel down. ***In Progress*** 3/8/2020 CTU#8 1.75" CT. Job Scope: Depth Log, Cement Liner, SCMT, Perforate, Cont Acid Continue to blow reel down. RDMO. ***Complete*** 3/15/2020 T/I/O=0/0/0 Removed blind from Flowcross, installed 3" CIW companion valve Tag #97. Torqued to API specs. PT'd through comp. valve against SSV, Wing and Swab, 300/low..5000/high.. 5 min. each. see "Field Charted Tests" Job complete, FWP's 0/0/0 see log for details. **Tie in crew to start re-connect** 3/25/2020 ***WELL S/I ON ARRIVAL***(ctd) SWCP 4517 PARTIAL RIG UP ***MOVE TO WEATHER TICKET, HIGH WINDS*** Daily Report of Well Operations PBU 03-07B 3/26/2020 ***CONTINUE JOB FROM 03/25/2020*** (ctd) RAN 2.30" CENTRALIZER, 1 1/2" SAMPLE BAILER TO DEVIATION @ 10,720' SLM RAN SBHPS PER PROGRAM (good data) **USED +24' CORRECTION FROM 03/18/2004 TUBING TALLY** RAN 3.625" x 3.70" BARBELL CENTRALIZERS, 3.50" LIB TO DEPLOYMENT SLEEVE @ 10,237' MD (impression of clean deployment sleeve) RAN 45 KB, 10' x 2 7/8" PUP JOINT, PTSA DRIFT TO DEPLOYMENT SLEEVE @ 10,237' MD (good marks on brass tattle tells) SET BAKER 45 FLO GARD PACKER, 10' x 2 7/8" PUP JOINT, PTSA (2 7/8" xx plug installed) IN DEPLOYMENT SLEEVE @ 10,237' MD (top of packer @ 10,220' md) ***CONTINUE JOB ON 03/27/2020*** 3/26/2020 STBY for S-Line, No fluids pumped 3/27/2020 ***CONTINUE JOB FROM 03/26/2020*** (ctd) LRS PERFORMED A PASSING PRESSURE TEST ON LINER TOP PACKER (see lrs log) EQUALIZED & PULLED 2 7/8" XX PLUG FROM LINER TOP PACKER @ 10,237' MD SET 4 1/2" MCX (ser# MM-14, 1.12" bean) IN SSSV NIPPLE @ 2,190' MD RAN 4 1/2" CHECK SET TO MCX @ 2,190' MD (sheared) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 3/27/2020 T/I/O=0/0/0 Asssist S-Line (Test LTP) Pumped 7.8 bbls crude down Tbg. to pressure to 2400 PSI, Loss of 76 psi 1st 15 min, Loss of 57 psi 2nd 15 min. 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"+5 ;<"! ;<;!" ;:5"= ;<;5"> ;<!" ;:"; + + + ;<=!"! ;<!" 5>"=! + + + ;<=!"! ;<!" 5>"=! 5 5 5 +<=+="! ++<+" ;!"= 5 5+ 5+ +<=+="! ++<+" ;!"= 5 55 55 +<=+="! ++<+" ;!"= ! ! ! +<=="=+ +<:5!" 5:+"> > > > 5<:+">> 5<;" ;+;"=! > > > 5<:>"5 5<;" ;+;":! > > > 5:"+ ;"! ;+:"+ 4 05 !0 * 4 05 ,%44 46 1+ *4 Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:CTD Liner Blend Yield (Ft3/sack):1.31 Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Tail Slurry Type:N/A Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Fresh Water Density (ppg) Rate (bpm):1.4 Volume:2.3 bbls Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped? Yes X No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Tail Slurry Type: Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No % Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: CEMENTING REPORT 15.3 45.5 BBLS 1.3 0 100 Bump press Volume Pumped (full returns) 8.34 PowerVis 8.34 1.0 NA Coil Pump Remarks: Cemented CTD liner with service CT using a 2-7/8" cement retainerFIRST STAGESECOND STAGE8.34Fresh Water 5.7 bbls 4:34 AM 2/29/2020 10,237 27.6 bbls Liner cement Job I Baker bb v PRINT DISTRIBUTION LIST Hughes COMPANY BP Exploration Alaska Inc. WELL NAME 03-07B FIELD Prudhoe Bav Unit COUNTY PRUDHOE BAY BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.RiderGilbhge.com 21912'2 32168 (Please sign and return one copy of this transmittal form to: 'BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anch, AK 99508 or GANCPDC@bp365.onmicrosoft.com LOG TYPE GR - RES LOG DATE February 21, 2020 TODAYS DATE March 17, 2020 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEx WILL NOT DELIVER TO P.O. Box) PERSON ATTENTION V 1 1 BP North Slope. �EOA, PBOC, PRB40 (Office 109) D&C Wells Project Aides Attn: Benda Glassmalcer & Peggy O'Neil 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99501 3 Katalyst Data Management Attn: ExxonMobil Tapes Operations 10311 Westpark Dr. Houston, TX 77042 41 State of Alaska -AOGCC Attn: Natural Resources Technician D 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR- Division of Oil & Gas *•' Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 1 Anchorage, Alaska 99501 11 ** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: Donald Surles FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES W N M � M TOTALS FOR THIS PAGE: 0 1 4 1 0 Date: 4/9/2020 Transmittal Number: 93742-03-07B BPXA WELL DATA TRANSMITTAL Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Digital zip files for the well log packages listed below are being provided to you via SharePoint. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bp.com. SW Name Log Date Company Description Format 03-07B 3/1/2020 Halliburton Radial Cement Bond Zip File Please Sign and Return one copy of this transmittal to GANCPDC@bp365.onmicrosoft.com Thank you, Mer Merion Kendall SIM Specialist ----------------------------------------------------------------------------------------------- BP Exploration Alaska|900 E. Benson Blvd.|Room: 716B|Anchorage, AK ----------------------------------------------------------------------------------------------- AOGCC https://bp365.sharepoint.com/sites/BPtoAOGCCElectronicPermittingandReporting/ DNR https://drop.state.ak.us/drop/ Received by the AOGCC on 04/09/2020 PTD: 2191820 E-Set: 32472 Baker 5�1 PRINT DISTRIBUTION LIST Hughes COMPANY BP Exploration Alaska Inc. WELL NAME 03-07B FIELD Prudhoe Bay Unit 21 91 `�2 32 16 8 Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, 1_112-1 900 E. Benson Blvd. Anch, AK 99508 or GANCPDC@bp365.onmicrosoft.com to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE GR - RES BHI DISTRICT Alaska --- LOG DATE February 21, 2020 AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a)bhge.com TODAYS DATE March 17, 2020 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aides Attn: Benda Glassmaker & Peggy O'Neil 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99501 3 Katalyst Data Management Attn: ExxonMobil Tapes Operations 10311 Westpark Dr. Houston, TX 77042 4 State of Alaska - AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR -Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: Donald Surles FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) 7_07 PRINTS # OF COPIES # OF COPIES J# OF COPIES 4 4 4 1 1 1 1 TOTALS FOR THIS PAGE: 0 1 4 1 0 THE STATE AMD 94 INC b I mos, GOVERNOR MIKE DUNLEAVY Matthew Summers Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-07B Permit to Drill Number: 219-182 Sundry Number: 319-586 Dear Mr. Summers: Alaska Oil and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 9" > JM .ce C DATED this 11 day of January, 2020. RBDMS LQ JAN 15 2020 SUANNEU JAN 1 61010 STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMISSIr .'PLICATION FOR SUNDRY APPROVAL- 20 PPROVAL20 AAC 25.280 �,r7 pT5 1�1�j/zv ry�i 1. Type of Request: Abandon El Plug Perforations ❑ Fracture Stimulate El Repair Well ❑ -34 ❑ Suspend ❑ Perforate Other Stimulate Q Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 219-182 3, Address: P.O. Box 196612 Anchorage, AK 6. 99519-6612 Stratigraphic El Service Q . API Number: 50-029-20220-02-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No Q ?x;03-078 ,v t IS 9. Property Designation (Lease Number): 1 10. Field/Pools: ADL 028327028328 & 028331 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): -14020' -9025' -13950' -9025 None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 30-110 30-110 1530 520 Surface 2663 13-3/8" 30-2693 30-2693 5380 2670 Intermediate 7940 9-5/8" 28-7968 28-6752 8150/6870 5080/4760 Liner 2481 7" 7798-10279 6636-8708 7240 5410 Liner -240 4-1/2" 10127 - -10367 8573--8783 8430 7500 Liner -3820 3-1/4" x 2-7/8" -10200 - -14020 -8637- -9025 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): -13830 - -13950 -9025 - -9025 4-1/2" 12.6# 1-80 26- 10130 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft) and TVD (ft): 10073/8525 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary Q Wellbore Schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service Q 14. Estimated Date for Commencing Operations: February 1, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG Q GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Summers, Matthew be deviated from without prior written approval. Contact Email: Matthew. Sum mersC5bp. com Authorized Name: Summers, Matthew Contact Phone: +1 9075645066 Authorized Title: Production Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l9 -58 �e Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RB®MS !�� JAN 15 2020 Post Initial Injection MIT Req'd? Yes ElNo ❑ ySpacing Exception Required? ❑ No Q Subsequent Form Required: S/Q APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: U6 1 ORIGINAL Form 10-403 Revised 04/2017 6q 1-6 111312,0 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate To: Coiled Tubing and Testing, Slickline, Eline & Date: February 2020 Pumping Superintendents AFE: H-SD4W015041-EX- D1-RN-02 From: Todd Sidoti Matthew Summers IOR: 100 BOPD Subject: 03-07B Acid Stimulation Est Cost: 1 V Tree Work as needed 2 C PT Liner Lap. Drift. Perforate 120'. Acidize if Injectivity below -2 bpm at 1,800 psi, 3 S SBHPs, Set LTP if needed. Set MCX 4 F PT LTP if set Contacts for this work are: Todd Sidoti 907-564-5113 w / 907-632-4113 c Matthew Summers 907-564-5066 w / 907-952-1682 c Obiectives To stimulate 03-07B's initial perforations if injectivity after perforating is below -2 bpm @ 1,800 psi. Target Intervals The acid job assumes a 120' perforated interval (standard for MIST injectors). Final perf depths will be chosen once drilled. They will likely be in the depth range of: 13,830-13,950' MD. Notes: • Tubing is in good condition, no need to hold pressure on IA. • No GL mandrels so no TIFL is required. MIT -IA passed 3/18. • Do not add friction reducer to stimulation fluids that will enter the perforations. • 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. • Send an electronic copy of the treatment report to Matthew Summers: matthew.summers(cD-bp.com CTU Acidize 1. MU BHA including JSN for acid job. 2. RIH while loading well down backside then CT with 210 bbls of 3% NH4CI. 3. Injectivity should be low enough (pre -acid) where keeping positive WHP is easily achievable. 4. Pump the following fluids per schedule below. o Reciprocate nozzle across perforated interval during treatment. Try to maintain WHP of 2000 psi during acidizing by increasing rate as injectivity increases. Can go up to 3000 psi if diversion locks up formation. Step Description Fluid Comment Stage Fluid Vol, bbl Cum Vol 1 Spear McOH Pump down backside 5 5 2 Pre -flush 3% NH4Cl + F103 Pump down backside 170 175 3 Pre -flush 3% NH4CI + F103 Pump down CT 40 215 4 Acid 12% HCI Swap to pumping down CT & reciprocating 36 251 5 Acid 9:1 Mud Acid 36 287 6 Over -flush 3% NH4Cl + F103 75 362 7 Diversion 7.5% OilSeeker 6 368 8 Shut Down Shut down for 10 minutes once all diversion is into formation 9 Spacer 3% NH4Cl + F103 40 408 10 Acid 12% HCI Continue pumping down CT & reciprocating 36 444 11 Acid 9:1 Mud Acid 36 480 12 Over -flush 1% KCI + F103 + 5% Musol 150 630 5. POOH pumping diesel for CT displacement & RDMO. CTU Acidize Design Details Fluid Requirements Fluid Type Vol, bbl Wellbore Volume 178 bbls to PBTD of 14,000 MD, 3'/4" x 2 7/8" Production Liner. 325 13,650 Volume Across Perls 29 gallons — 120' in 2 7/8" liner 6300 3% NH4CI + 7.5% OilSeekeer Acid Design 12% HCI Acid @ 25 gpf — 72 bbls 9:1 Mud Acid @ 25 gpf — 72 bbls 12% HCI 72 Pres Tres 3259 psi & 173°F @ 8800' Datum SS 72 Fluid Requirements Fluid Type Vol, bbl Vol, gal 3% NH4CI 325 13,650 3% NH4CI + 5% Musol 150 6300 3% NH4CI + 7.5% OilSeekeer 6 252 12% HCI 72 3024 9:1 Mud Acid 72 3024 HCI Loading for: Function: 12% HCI tot chemical 9:1 Mud Acid tot chemical Product Code: Function: per M al in HCI alper M al In 9:1 al A264 ACI 4 12 4 12 A201 Inhibitor Aid 0 0 0 0 A153 Intensifier 0 0 0 0 F103 Flowback aid 2 6 2 6 L058 Iron Control 20 60 20 60 W054 Antiemulsifier 5 15 5 15 U067 Mutual Solvent 0 0 50 151 Loadinq For: 3% NH4CI Product Code: Function: Units: per M al tot chemical F103 Flowback aid al/M al 2 28 Loadinq For: 3% NH4CI + Musol Product Code: Function: Units: per M al tot chemical F103 Flowback aid al/M al 2 13 U067 Mutual Solvent al/M al 50 315 Loadinq For: 3% NH4CI + 7.5% OilSeeker Product Code: Function: Units: M al tot chemical J570 OilSeeker al/M al +�75 19 TREE = WELLHEAD= FMC GEN 1 PROPOSED 03-07B SAFE" NOTES: H2S READINGS AVERAGE 125 ACTLIATOR= . SPF REV Z Ppm . cN ON MI --- WELL REQUIRES A SSSV OKB. ELEV = 61.0' 2' WHEN ON MI--- WELL ANGLE > 70° @ ' 4 - REF ELEV = 55.5' r 1/2" CHROME NIPPLES""" BF. ELEV = 27.62' KOP = 7968' 20" COND, 10T 2190' 4-1/2" HES XNIP, D = 3.813" Max A Ie = 94#, 1+40 Datum MD = D= 19.124"Tt� 2325' 9-5/8" FOC Datum TVD= 8800' SS 2446' 9-5/8_-F-0 C 13-3/8" CSG, 72#, MN -80 BUTT, ID = 12.347" 2699' — TOP OF 7" LNR 7798" 9-5/8" CSG, 47#, MN -80 BTC, D = 8.681" 7968' Minimum ID = I. @ ' ITOPOF4-1/2"LNR--1012T 1/2" TBG, 12.6#, L-80 TC11, .0152 bpf, D = 3.958" 1013W TOP OF LNR 1--1 10200' 7" LNR, 26#, L-80 BTC -M,.0383 bpf, ID = 6.276" 10279' 4-12" BKR PKR WHIPSTOCK (_J_J_}10367' 4-12" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" -10367- ' 3-1/4" LNR, 6.6#, L-80 TC11, .0079 bpf, ID = 2.85" 10650' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: _° @ Note: Refer to Production DB for historical perfdata SIZE SPF INTERVAL Opn/S z SHOT SQZ 2' 6 -13830'--13950' PBTD —� 2-7/8" LNR, 6.5#, L-80 STL, _0058 bpf, D = 2.441" 1402W . - 7798'—{9-0/8"X 7" BKRZXP LTP w/71EBACK ISLV & HGR, ID =6.290" MILLOUT WINDOW (03-07A) 7968' - 7984' 10052'--�4-1/2" HES X NIP, ID = 3.813" 10073' J --j7- X4-1/2- BKR S-3 PERM PKR, K)=3.875- 10097' =3.875" 10097' 1---�4-1/2" HES X NIP. ID =3,813" 10117' 4-12" HES XN NIP, ID =3.725" 10127'��7"X5"BKRZXPLTPwrnEBACK SLV & HGR, ID =4.410" 4-112" 10130' WLEG, D= 3.958" 10148'7' X 4-1/2" XO, D = 3.980" 10200' 3.70" DEPLOY SLV, ID = 3.00" 7�3-1 /2" X ND. ID = 2.813" MILLOUT WINDOW (03-07B) ' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/201/6 ORIGINAL COMPLETION 12/30/19 JNUJMD BUILT PROPOSED REV 2 1991 RWO 04/06/04 KAK RIO SIDETRACK (03-07A) CTD ST (03-07B) 08/06/19 JMD BUILT PROPOSED 08/07/19 RC/JMD BUILT PROPOSED REV 1 PRUDHOE BAY UNIT WELL: 03-07B PERMIT No: API No: 50-029-20220-02 SEC11, T10N, R15E, 1316' FSL & 812' FWL BP Exploration (Alaska) THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-07B BP Exploration (Alaska), Inc. Permit to Drill Number: 219-182 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Surface Location: 1316' FSL, 812' FWL, SEC. 11, TION, R15E, UM Bottomhole Location: 1326' FSL, 2945' FEL, SEC. 10, TION, R15E, UM Dear Mr. Mclaughlin: Enclosed is the approved application for the permit to redrill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, l Jerice Chair DATED this, � day of December, 2019. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMISS � PERMIT TO DRILL 20 AAC 25.005 nrr, )non la. Type of Work:1 b. Proposed Well Class: Exploratory - Gas E]Service - WAG 0 ' Service - Disp El1 c. Specify if ;el I is proposed for: Drill ❑ Lateral C3 Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone RI* Coalb� s.}�ydFates El Redrill p . Reentry E] Exploratory - Oil El Development - Gas ❑ Service - Supply ❑ Multiple Zone 11GeotllerlMl e s ❑ 130 2, Operator Name: 5. Bond Blanket 0' Single Well ❑ 11. Well Name and Number: BP Exploration (Alaska), Inc Bond No. 295105380 , PBU 03-07B Address: 3. 6. Proposed Depth: TVDss: 8970' 12. Field/Pool(s): P 0 Box 196612 Anchoraoe AK 99519-6612 MD: 14020'' TVD: 9025' PRUDHOE BAY, PRUDHOE OIL , 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028327, 028328 & 028331 Surface: 1316' FSL, 812' FWL, Sec. 11, T10N, R15E, UM 8. DNR Approval Number: 13. Approximate spud date: Top of Productive Horizon: 1788' FNL, 2348' FEL, Sec. 15, T10N, R15E, UM 74-017 February 1, 2020 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 1326' FSL, 2945' FEL, Sec. 10, T10N, R15E, UM 19560 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 55.50 ' feet 15. Distance to Nearest Well Open to Same Pool: Surface: x- 714073 ' y- 5937379 Zone - ASP 4 GL Elevation above MSL: 28.00 feet 72 16. Deviated wells: Kickoff Depth: 10367 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3457 Surface: 2554 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/4" 3-1/4"x2-7/8" 6.6#/6.5# L-80 STL/TCII 3820' 10200' 8637' 14020' 9025' 201 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 13841 9052 10749, 11250, 12650, 13025, 13490 10749 9019 12650 Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 300 sx PF II 30-110 30-110 Surface 2663 13-3/8" 5800 sx PF II 30-2693 30-2693 Intermediate 7940 9-5/8" 1075 sx Class'G' 28-7868 28-6752 Liner 2481 7" 276 sx Class'G' 7798-10279 6636- 8708 Liner 3713 4-1/2" 444 sx Class'G' 10127 - 13840 8573-9052 Perforation Depth MD (ft): 10396 - 13750 Perforation Depth TVD (ft): 8807-9049 Hydraulic Fracture planned? Yes ❑ No RI 20. Attachments Property Plat ❑ BOP Sketch Q Drilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21 Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Hvatt. Trevor from without prior written approval. Authorized Name Mclaughlin, Sean M Contact Email Trevor.Hyatto_bp.com Authorized Title En ineering Team Lead - CTD Contact Phone +1 907 564 4627 Authorized Signature Date /I l 2 Commission Use Only Permit to Drill -2 API : 50-029-20220:02-00 Permit Approv See cover letter for other Number: Date: I requirements: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: D l Other: a l% - Y� 3�© �S{ Samples req'd: i Yes El/ No d Mud log req'd: Yes ❑ No 1 vo'-r 1 20 '+'4 e__ 25, rtL(w� H2S measures Yes 0 No ❑�; Directional svy req'd: Yes I� No ❑ aL 14e vWOJe Iv �a.Ceµn.EtI� Spacing exception req'd: Yes ❑ No ® Inclination -only svy req'd: Yes ❑ No O Cs- T i9 t}� / Post initial injection MIT req'd: Yes ❑ No ❑ Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: 1 Form 10-401 Revise 7 This permit is valid for 24 month©. ZJdGJaNP ALC 25.005(g)) Submit Form and I(D I'`I M kMtR4¢ Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission by From: Ryan Ciolkosz - CTD Engineer Date: November 26, 2019 Re: 03-07B PTD Request Approval is requested for a permit to drill a CTD sidetrack lateral from well 03-07A with the Nabors CDR2 Coiled Tubing Drilling around February 2020. Proposed plan for 03-07B The sidetrack will be a 3653' horizontal CST that will kicks -out from the 03-07A parent. The CST will be a MIST injector at the base of the victor interval supporting 5 offset producers. During pre -rig work it is proposed to set a 4-1/2" whipstock at a kickoff depth of 10367' MD and mill a 3.80" window. The rig will move in, test BOPE and kill the well, and drill into Zone 2. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" L-80 solid liner and cemented in place. The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin December 2019) 1. S Drift for whipstock. 2. EL Set CIBP. Set Whipstock 3. F A/EL: Displace well to brine. MIT -T MIT -IA 4. C Mill XN Nipple. Mill Window 5. V Pre -CTD Tree work. Rig Work (scheduled to begin February 2020) _ 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2554 psi). QC C. \ D Iti 2. Drill production section: 4.25" OH 3. Run 3-1/4" x 2-7/8" liner to TD. 4. Pump primary cement job: 41.5 bbls, 15.3 ppg Class G, TOC at TOL (10200' MD)*. 5. Freeze protect well to a min 2,200' TVDss. 7. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(1) Post -Rig Work: 1. V: Valve & tree work 2. SL/FB: Set LTP if needed. PT LTP. Set KO GILD. 3. CT: Perforate —120'. Acid stim if injectivity low Mud Program: 6 Drilling/Completion: a min EMW of 8.4 ppg KCL with Geovis for drilling 5'#►bv- %I 1q -S Li t'o Disposal: • All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. - • Fluids with PH >11 must go to GNI. Hole Size: • 4. 25" for entirety of the production hole section. Liner Program: - • 2-7/8", 6.5#, STL, L-80 solid liner: 10,650' MD — 14,020' MD • 3-1/4", 6.6#, TCII, L-80 solid liner: 10,200' MD — 10,650' MD • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional: • See attached directional plan. Maximum planned hole angle is 90`, inclination at kick off point is 31°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 19560' • Distance to nearest well within pool — 72' Logging: • MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. Perforating: • Perforating: —120' of perforations, 2", 60 deg random phasing, 6 spf, pert guns. • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures: * All wells pass BP Anti -Collison Risk Requirements. The planned 03-07B Trajectory is within 57ft of the the 03-21A wellbore. There is no expected significant reservoir pressure differential between the 03-07B and the 03-21A wellbores. The 03-07B well is being drilled solely within the same reservoir as the 03-21A wellbore. Hazards: • DS 03 is an H2S pad. Estimated H2S levels based on approx. concentration of MI gas in 03-07A: 100 ppm. Max H2S recorded on the pad: 650 ppm. • One planned fault crossing with low probability of lost circulation • Lost circulation risk is considered Low. Reservoir Pressure: • The reservoir pressure on 03-07B is expected to be 3457 psi at 9035' TVDSS (7.36 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2554 psi. • A min EMW of 8.4 ppg for this well will provide 488 psi over -balance to the reservoir. Ryan Ciolkosz CC: Well File CTD Engineer Joseph Lastufka 564-5977 TREE = REF LOG: PROP(--`) ED WELLHEAD= FMC GEN 1 SPF ACTUATOR= OprVSqz REV 1 OKB. ELEV = 61.0' REF ELEV = 55.5' BF. ELEV = 27.62' KOP = 7968' 20" COND, 107' Max Angle = ' 94# H-40 Datum MD = Datum TVD= 8800' SS D- _ 19.124" 13-3/8" CSG, 72#, MN -80 BUTT, D = 12.347" TOP OF 7" LNR 7798' 9-5/8" CSG, 47#, MN -80 BTC, ID = 8.681" 7968' Minimum ID = " @ TOP OF 4-1/2" LNR 1---J__101 2r 52 bpf, D = 3.958" 10130' TOP OF LNR 10200' 03-076 7" LNR, 26#, L-80 BTC -M, .0383 bpf, ID = 6.276" 10279' - 4-1/2" BKR PKR WHIPSTOCK (_!_(_} 10367- 14-1/2- LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" -10367' 3-1/4" LNR, 6.6#, L-80 TC 11, .0079 bpf, D = 2.85" 10650' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for N Tical erf data SIZE SPF INTERVAL OprVSqz SHOT SQZ 08/06/19 JMD BUILT PROPOSED 08/07/19 RC/JMD I BUILT PROPOSED REV 1 PBTD — 2-7/8' LNR, 6.5#, L-80 STL, 0058 bpf, D = 2.441" —14020- SA' Y NOTES: H2S READINGS AVERAGE 125 ppm .THEN ON MI — WELL REQUIRES A SSSV WHEN ON MI -- WELL ANGLE > 70'@ ' •"*4- 1/2" CHROME NIPPLES**" 219 4-1 /2" FES X NP, D = 3.813" 2325' —�-5/8" FOC 2446' 9-5/8" FOC 779$' 9-5/8" X 7" BKR ZXP LTP wfTEBACK SLV & HGR, D = 6.290" MILLOUT WINDOW (03-07A) 7968' - 7984' 10052' 1---�4-1/2" HES X NIP, ID = 3.813" 10073' I--]7" X 4-1/2" BKR S-3 PERM PKR, ID= 3.875" 10097' —14-1/2" HES X NIP, ID = 3.813" 10117' 4-1/2" HES XN NIP, ID = 3.725" 1012T �7" X 5" BKR ZXP LTP w/rEBACK SLV&HGR,11)=4.410" 10130' 4-1/2" WLEG, D = 3.958" 10148' 7" X 4-112" XO, D = 3.980" 10200' 3.70" DEPLOYSLV, D = 3.00" F 3-1/2" X NP, D=2.813" MLLOUT WINDOW (03-07B)' -_' 10650' 3-114'X 2-7/8" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/20176 ORIGINAL COMPLETION 1991 RWO 04/06/04 KAK RIG SIDETRACK (03-07A) _/_I_ CTO ST (03-07B) 08/06/19 JMD BUILT PROPOSED 08/07/19 RC/JMD I BUILT PROPOSED REV 1 PRUDHOE BAYUNrr WELL: 03-07B PERMrr No: API No: 50-029-20220-02 SEC11. T1 ON. R1 5E. 1316' FSL & 812' FWL BP Exploration (Alaska) TREE = 6-3/8° CALICO WELLHEAD= FMC GEN I ACTUATOR= BAKER OKB_ ELEV = 61.0' REF ELEV = 55.5' BF. ELEV = 27.62' KOP = 7968' Max Angle = 93'@11811' Daturn MD = 10456' DatLxnTVD= 8800' SS 20" COND, [-L 107' 94#, H-40 D = 19.124' 13-3/8" CSG, 72#, W80 BUTT, D = 12.347" 2699' TOP OF 7" LNR 7798' Minimum ID = 3.725" @ 10117' 4-1/2" HES XN NIPPLE 9-5/8" CSG, 47#, MN -80 BTC, D = 8.681 " --f 7968- ITOPOF 4-1/2" LNR --L 1012T 1/2" TBG, 12.6#, L-80 TC11, .0152 bpf, D = 3.958" 10130' 7" LNR, 26#, L-80 BTC -M, _0383 bpf, D = 6276" 10279' PERFORATION SUMMARY REF LOG: ANGLEAT TOP PERF: 34° @ 10396' Note: Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sgz SHOT SOZ 2-7/8" 6 10396 - 10426 O 07/13/19 10749- 2-7/8" 6 10436 - 10466 O 07/13/19 11/17/14 JMD 2-7/8" 6 10476 - 10506 O 07/12/19 2-7/8" 6 10528 - 10558 O 07/12/19 2-7/8" 6 10890 -11018 C 07/08/18 2-7/8" 6 11400 - 11500 C 10/15/14 2-7/8" 6 12100 - 12130 C 06/23/13 2-7/8" 6 12130 - 12155 C 06/22/13 2-7/8" 6 12150 -12175 C 06/21/13 2-7/8" 6 12157 - 12162 C 06/23/13 2-7/8" 6 12175 - 12200 C 06/21/13 3-3/8" 6 12750 - 12770 C 02/16/10 3-3/8" 6 12770 - 12830 C 02/13/10 2-7/8" 6 13200 - 13300 C 09/02/06 2-7/8" 6 13650 - 13750 C 04/27/04 4-1/2' LNR, 12.6#, L-80 BT -M, .0152 bpf, D = 3.958" 1384W 03-07A SAr "NOTES: H2S READINGS AVERAGE 125 ppm .. HEN ON MI -- WELL REQUIRES A SSSV WHEN ON MI— WELL ANGLE> 70° @ 10766' ****4-112" CHROME NIPPLES**** 2190- 4-1 /2' HES X NP, D = 3.813" 2325' 9-518' FOC 2"6' 9-518" FOC 7798-9-5/8"XI� 7" BKR ZXP LTP w TFEBACK SLV & HGR, D = 6.290" MILLOUT WWDOW (03-07A) 7%8' - 7984' 10052' 10073' 7" X 4-1/2" BKR S-3 PERM PKP, D = 3.875" 10097' 4-1/2" HES X NP, D=3.813" 10117' 4112" HES XN NP, D = 3.725" 10127- X 7" BKR TIEBACK SLV, D = 525" 10130' 4-1/2° WLEG, D = 3.958" 10135' 7" X 5" BKR ZXP LTP, D = 4.420" 10141' 7° X 5" BKR LNR HGP, D = 4A10- "10749'1125W 07/10/18 JTWJMD MILL® PLUGJSEr FLmADPERFS 04/06/04 KAK 10749- 03/12/12 DD/JMD ADDED OKB, REF, & BF ELEV 1125W 41/2"BKRCBP(07/07/18) 12650' — I FISH: 4-1 /2" CEP MILL® & PUSHED (07/06/18) 12650' 4-1/2" CBP(06/21/13) 13025' 4-1/2"CBP(02/12/10) 13490' �4-1/2° CBP(09/02/06) 137ST PBTD DATE REV BY COMMEWS DATE REV BY COMM8YT5 101201-16 ORIGINAL COMPLETION 04/19/16 JTG/JMD PULLEDXN LOCK w/GAUGES (4/18/16) 1991 RWO 07/10/18 JTWJMD MILL® PLUGJSEr FLmADPERFS 04/06/04 KAK RIG SIDETRACK (03-07A) 03/12/12 DD/JMD ADDED OKB, REF, & BF ELEV 10/15/14 SRD/ PJC SET CBP/ ADFERF 07/15/19 TJS/JMD SET PLUG & ADPBRFS 11/17/14 JMD I CLEANED UP WBS PER TALLES 03/17/16 IJMWJMDI SET FLO THRU SUB w/GAUGES (3/15/16) PRUDHOE BAY UNIT WILL: 03-07A PERMIT No: F2040430 API No: 50-029-20220-01 SEC11, TI ON, R15E, 1316' FSL & 812' FWL BP Exploration (Alaska) 02 Cl) < 0 .j CL C4 A CD 0 A CD E a) 0 Z m A > 0 z Z IL 0 V - V- c`o O U a 0 U d C d co > U J of d m 0 U) 0) c 0) 0) E 7 p E O co N V M r V v d c N O O W C N O = N w d O N � c v ¢ IL Y Y d ¢ ¢ co N N m 65 N a a IL z O O CN CN CN CN ¢ Z Z v E ci d N p N "' o. o a 0 IL i i Z E U O o z N n 0 Q O r O O d a d d J > m Z m N 3 0 ¢ J O m U 0 d nE 10Y A U LO 0 CO d N m 3 C Y H W c ei C O � L 7 d N d � c d O GUi ' d i0 C_ U d c d -co o O w w d U N U d � O 0 d d > 0 0 J 02 U) a E" O Q O oa(n33o a) lyCL m 0 U d in c`o O U a 0 U d C d co > U J of d m 0 U) 0) c 0) 0) E 7 p E O co N V M r V v d c N O O W C N O = N w d O N � c v ¢ IL Y Y d ¢ ¢ co N N m 65 N a a IL z O O CN CN CN CN ¢ Z Z v E ci d N p N "' o. o a 0 IL i i Z 0- O o O 3 N n co V00 r O U) N d J g Vl O (¢p U m O 0 a E o E r) Q O m c v::) O Q O 7 to co Z0 a O O a O d -co c .i m d d > ao c E" O oa(n33o c`o O U a 0 U d C d co > U J of d m 0 U) 0) c 0) 0) E 7 p E O co N V M r V v d c N O O W C N O = N w d O N � c v ¢ IL Y Y d ¢ ¢ co N N m 65 N a a IL z O O CN CN CN CN ¢ Z Z v E ci d N p N "' o. o a 0 IL i i Z z O o O 3 N n co V00 r O U CO N d J M M Vl O d Z W v ai L d J Vl O c Z 07 7 O d -co d d > O + d 7 O Z J J a L J Of � c m F C co a fq ,cam co m M d O CN O N 9 r- N 2 LO Go N p ZZ Cl) LL 0 = c M O O 0 0 0 0 - O c') rn o ` ° o lolo� O 7 3 � Q M N N O O N oo oo O MCO O n � O co r --O a L c m O n M N00 L L LC) n P- co O d d LL N r- V W N N MC O rLO L Q 0 0 o a c d )n o o 0 t m °D o d O 0 0 p ro o a C o O O o O - d _ O + 'a o + N N M d Z O] N ( W C L C 01 a c J t C 07 c 0 Z W m C L R a o m y c o Z W v Vl O p O + Z J a d O CN O N N p ZZ Cl) d pj 0 a � y a L c m L L d LL N W N N L 0 0 o c d )n o 0 0 m °D o O 0 0 ro o a O o (h 0 oE d o Z z ( o M J d m O (h O a Cl) O o U) c W C C r d r d c 0 p c C o - :cc c d d c N a. ° a ° 0 c rn Z 4 v d 'ami « E 'U)cm Q N in ao 3 3 ao 3 2 o¢ O O O m 0) O m r- V M N O O O O O O 0) m Cl) Cl? 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O O u) V c O O m O m O COM O O O N V V M M (`) M (0 (D cD m OD O C r - - w d t%6 V � W c m O � N . c d i7 N y t1 N co OD N O O m r m V M V O OO m O V 0 m '- N 'ct N O m (D r M V (0 m f- (0 m O m (O Q ` jp N M 0 W V r- O N O V M O r-� M O r V O (0 M O w w 0) V N V 0) T w 0) O) OD m m 00 m m n N m (D V M N m co N M V m N (O N m m V (0 m m N (0 (0 m c0 U) cfi M N N m 41 M A c M M v M v V V c0 (0 co n n m m O O N M M V (0 m O G t V v v v v v v v v v .D (ri (ri ui (n (n U) m J 2 h 93 O rn rn rn rn rn rn rn rn rn rn rn M 0) rn rn m rn rn rn rn rn Z 10 c0 (0 c0 (0 N (0 (0 (0 (0 (0 (0 (0 (0 (0 (0 0 0 (0 (0 (0 O Q M NN V V (D N m O (0 n N N _ m _ O M V V V to NN M m f` M m M m (n V N N m V 10 cD m m N M (0 OD CO 00 N co m M V O M c0 M (D V O V O V O m O co C Ot0 C O V O N C O m m m m m m m m O O m m f- m 0 m V m M m M m M M M M M M M M M M N N N N CO N N N N N N m W 7 O U Q O O M N M m O N V M O (D (O O .- O N m M N m N m M O M f- �- M (0 OO m r m m m m rl 00 (0 NO m (0 m M O m (0 M m M N m m (0 r- N N f- (0 N co (0 N O M � N M V N M M (0 V N N M N M M M M O0) co M m N m m M CO O V r- O V m N m N N N N N N N N N N N N N N N N N Z 3 O O (D O N m f- n O M N m m m m M M m 00 M O O (0 O m O O m O V co V M (0 f- O m O (D 00 (o m r- m M c0 10 V V V M M N NO O m m fl N O m M m M m m m m m O C O O O c O O O O O O O O O O O O O o O C O o m m m m m m m m rn Q w o OD OD 0 o T M m m m o o m W CA W W o 00 m o M M OD V V V m M M M M m (0 (0 (0 CD O N CO OR (0 M (0 10 c0 m 0 (D r- f., N N M (0 (D N V N OD (0 r- m N M - m n (O O N V M M V M V M (0 M (0 M .- (0 M (0 M ((7 M r r (0 M Q d Qm Y QO N O M c0 O (0 m 00 O m N f- m m V N N f� V f0 O V O V O O r N M M V V V V V V V m m Q O O V V to (D O n O m O m O m O m O m O m O m O m O m O m O m O m O m O m O m m �QM m O r N d O O c °. > M Q O m ogo 0 r� Zd O 0 O O d (D V O VO (0 O O O O O O O O O O O O O O 0 m m o V o m y o 0 0 0 0 0 0 O O O O O o 0 0 d Z (0 N m N O J O I` m (0 o O J f` (o (D f` 0 O C1 OO 0 O m n (D m 0 O O 0 O 0 O N N CD N o 0 M 0 0 V o 0 (0 0 0 (c I` 0 to O O n 0 O m 0 0 c ? (0 O a C (� 0 C 0 O o O O O (V co LU • m V O c CL o, a Im m C p N r , o _ m c Q4 0tL W 3 a a O M M O LO M m m O O o O O m N m V M (D m r M m O O n O m O m (O In m O r Cl) r OO u) (n m V o) a N m c m m O m m m O D) O O O o o O O O D) O m O mQ1 .- m m m m m m m m m :3 O) Q7 W W O) W W m Y n co 0 2LL. o0 Co 0 N V N m m m m M a r (f) O V M r m r m V m O f` V m r m m m M U m f- m O m O (o M N M M M M M N m V N (O (n Cl) In m V (O M M (O f� N m V U Z Q (D O - O m OD rl m (O V M N r N M U C Go '- < Q 0 > O m d`0 N (Np O O O O O O O O O O O O O O O O O O o O O O O j 2!Q O O O O O O O O O O O O O O O O O O o O O O O J O n U Y co m co co co m co N m m m m m c0 c0 co m OD co m m m co o o (Dri M U ELo dCD o c 0 d m=3 c 0 d Y H W 0 N r V O m O r- M M O_ N N V co N M V m V m CD (O m Cl) N V m m V m m N M n O V N V m O N m co co co O m O c0 (o M c0 (o m O M r- M N O rl� d V .o M m O m N O N O M O M � O m O (n r N O m V M m p) Mr- (o V O O m m N c O C _ _ _ _ N N N N N _ _ _ _ O O O O) a cc N co- r- (O d L ,'A o O O O O O O � w " d c 0 m m• V d C 'O co (D Cl) �_ (D V n V N M m M Cl) V (o V m m Cl) N m n c m D OD N o V V n m m V M o o M m O o V m m m N m 4, d w d O (D m N (D m r- m m m M N V N O m O V M r- O Z,N d V d U N d d T W C co Lo Lo M m O co O m V co V m V h V M V (n M m r- N N V m (D m o O m co M m m N O co co co M V 0 O) L m (o r- (O co (o (n O (n O m r m N m M m V m (o m cO m m m n m P- (D cc m m m m m O n - r- r r r r N t` J Z UiZ O1 "'� Cl) Cl) m Cl) OM) Cl) Cl) m m Cl) Cl) Cl) m DM) m Cl) a DM) m OM) OM) a) OM) to (O (n m (n In N (n to m N (n (n m M m (D m N N (n (n (n t' O Q N N r- rl- r- m N O N m m m m O O V M (O M Cl) m V m M O m I, O OR V m m m N O r` N r- r- M m N O M m Cl) V V O V .- N co O V m m N M r -I Cl) OD m O (O V n m N m m N V m (O Cl) m M V (n O V r- � r m m (D V CD m m M m m cc m m m M m m m O O O O N N N M V CL C N N N N N N N N N N N N N M M M M M M M M M M m w O U Q O (D m N V V (o N m m m o M N O Cl) N M M m (D r- O m O N V N .-- N co O m r- - m r� OD N m O (O m Co V r m LO V V V M V OD m n V N V m V m V N (O o m m r- � ro OD r- Cl) Cl) N m O Q) Cl) O V NL r� m (O (D m m V m (O V CO N N _ O W 0? 1 I- (O to (O M (h N m_ x7 7 a 2 to 3 m In V V O m V m M O m N O O m m N m N m Cl) O D) O O N (O t- V ti (D c0 N D) _ U) Cl) (3) r- m V N O co (D (O V M N O D) W D) D) m O m m M m m m N m co m OD m m m m m m m r- m r- m r- m r- m r- m rlr- m m m m m m m m m (D m m m I - m y � N OD N OD N N OD aD w m w m w co c0 co m c0 m c0 N OO co m O V V V O m m (D (D (O (O m V V O m m m r- r (D V V V N m m m m m m V V N m m m m N m m m N m m V m M )n N m Cl) O V N (D M (o r: O m F M (O M N Cl) N Cl) V Cl) V M Cl) Cl) Cl) Cl) Cl) Cl) V Cl) V Cl) V M M M c', Cl) M M O M O M m N co co Y V m Cl) V V M (O m OD m m m r- (D (O N m (n .- N m m u N N Cl) Cl) M Cl) M N O m m m m OD r D1 N O m OD co m Q m rn W rn m W 01 rn 01 W O m O m O m O m O m O m O m O m O m m m m m m OD m m � o E A Q o m r o Z o zd o o a o ^ o O 0 O o O o o o o o O o O 0 O 0 O 0 O 0 O 0 O o o o O o o o o o o o o o o o o o O o O o o R y,L >, r- o o o n o o o o 0 o N o o r- o o 0 o I- O o o 2 m N O O O r O N V N O Cl) O V O o O m O N O m V m O m O O V O O r o N O M O V m V O N O m O r- (O N N N N N N N N N N N N M M M M M M M M co M CV 7. O Cd N C ol G y O) C N ♦ p N d d N d v n n m O c c M N Oi 01 Oi � 31JRt\l W N OD m m m yr m m m M m m Z n n c ui c m o c v LL.,. m m m oa S r) v u V m � cmo v N c c M N Cl) Cl) m v_ d Q N m n m m � U m m M m m Z n n c ui c m o c v m m m m aci y v O r) v u V m � cmo w d U w W C m coo N N o m � rn y t n t- P- r.- Q 0 v rn U no ar d m 0 rn rn > N Y 0 Z O m O O O O JO n L m 3 Q U Y Q c m m m m o c E y=0 n m m? D _j o d Y � o F W LO m m In n m LOW v m n n tf cO c c c Cl) Cl) m v_ Cl) m m o 0 Q m n N N n n n m � w m m m m u; o O n n c ui c m o c v V N c+) m N m m n n aci y v O r) v u V m � cmo w d U w W C m coo N N co m N N v o S LC t n t- P- r.- J Z N o Z rn rn rn rn U in in N N tf M W O C? Q m n N N m N m N N m m m O n n 0) V N c+) m N m m n n a m w F- 0 '04 0 U ¢ m 0 rn rn co m n m w 0 v2 v Q c rn � E M Z V N m V n m n m O O O m n m m m m m m m Q W m m m m e. x o 0 T O O O N OO r _ CN C 0 cm N 0 d U E io d E m O U _ O C C U G F Y W 0 W n m m 0 N m m m n 0') V N r- CO O c") n V m N L0 n N O N V m m m I- m m m V O N n m m m m m n V n n m m m O W m N m m 07 O mn N m m m m O O O m m m O m O N n 0 N N N N m M m N N N N N M M m y W 3 01 + N 0 O O Q v m m m m 07 n V O O V 0 m m m m O m N m O c") n m m O m 0 ch U0 0 m V N V O mt0 m V O m O N V N m V N m (h J fA ^ m m m m m n m N m m N N Z y N N N N N N N N + N— m O m o m m m V m rt) n 10 m m9 o m V m N m 10 V n (D O m n V �) N v N m l0 n r0 N m m O N v m o o o m m m n n m m G y m n n n n 0 0 o m m m m m M m m 0� m o 0 o m m m m m o o m o m ao m m O 0 o m O O O O O O O O 0 "O n 0 0 0 m o 0 0 0 0 0 0 0 0 o ui r- r- cv co r- r- r- n r,� r,� n n o V m m c+) m m m O N V V V m N w O. y c m M m v n m N m m N occ V O O O O O O O O N N M 07 V O � O c Q a Q N m 0 N M W W C? m n N N m N m N Q a m U) '04 0 ¢ m 0 rn rn m o n o � Q c E M ¢ o m to Z)0 Q O O mm M J A O O z m O o a. O o 0 0 0 O O O O N d O O O N r O O c m O c m c o m m s m c�arn33o a x o 0 T O O O N OO r _ CN C 0 cm N 0 d U E io d E m O U _ O C C U G F Y W 0 W n m m 0 N m m m n 0') V N r- CO O c") n V m N L0 n N O N V m m m I- m m m V O N n m m m m m n V n n m m m O W m N m m 07 O mn N m m m m O O O m m m O m O N n 0 N N N N m M m N N N N N M M m y W 3 01 + N 0 O O Q v m m m m 07 n V O O V 0 m m m m O m N m O c") n m m O m 0 ch U0 0 m V N V O mt0 m V O m O N V N m V N m (h J fA ^ m m m m m n m N m m N N Z y N N N N N N N N + N— m O m o m m m V m rt) n 10 m m9 o m V m N m 10 V n (D O m n V �) N v N m l0 n r0 N m m O N v m o o o m m m n n m m G y m n n n n 0 0 o m m m m m M m m 0� m o 0 o m m m m m o o m o m ao m m O 0 o m O O O O O O O O 0 "O n 0 0 0 m o 0 0 0 0 0 0 0 0 o ui r- r- cv co r- r- r- n r,� r,� n n o V m m c+) m m m O N V V V m N w O. y c m M m v n m N m m N occ V O O O O O O O O N N M 07 V O � O c Q a Q N m 0 N North America - ALASKA - BP PBU 03 03-07 PLAN 03-07B 03-07B WP04 Anticollision Summary Report 11 November, 2019 Baker Hughes �•tiS. 03-07B WP04 "00,,04` by GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Company: North America - ALASKA - BP Project: PBU Reference Site: 03 Site Error: 0.00usft Reference Well: 03-07 Well Error: 0.00usft Reference Wellbore PLAN 03-07B Reference Design: 03-07B WP04 BP Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 03-07 Mean Sea Level KB @ 55.50usft (3-07A:) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Baker Hughes Reference 03-07B WP04 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,310.78 to 14,020.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum centre distance of 1599 Error Surface: Pedal Curve Survey Tool Program Date 11/11/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 94.50 7,894.50 1 : Camera based gyro multisho (03-07) CB -GYRO -MS Camera based gyro multishot 7,968.00 10,310.78 3-07A MWD (03-07A) MWD MWD - Standard 10,310.78 14,020.00 03-07B WP04 (PLAN 03-07B) MWD MWD - Standard 11/11/2019 1:11:04PM Page 2 of 4 COMPASS 5000.15 Build 90 •NBP Reference Baker pAnticollision No -Go Report Hughes Company: North America - ALASKA - BP Local Co-ordinate Reference: Well 03-07 Deviation Project: PBU ND Reference: Mean Sea Level Distance Reference Site: 03 MD Reference: KB @ 55.50usft (3-07A:) (usft) Site Error: 0.00usft North Reference: True Reference Well: 03-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore PLAN 03-07B Database: EDM R5K - Alaska PROD - ANCP1 03-03 - 03-03 - 03-03 Reference Design: 03-07B WP04 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) 03 03-02 - 03-02 - 03-02 Out of range 03-03 - 03-03 - 03-03 Out of range 03-04 - 03-04 - 03-04 Out of range 03-05 - 03-05 - 03-05 Out of range 03-06 - 03-06 - 03-06 Out of range 03-07 - 03-07 - 03-07 10,832.71 10,475.00 1,287.60 252.72 1,062.55 Pass - Major Risk 03-07 - 03-07A - 03-07A Out of range 03-08 - 03-08 - 03-08 10,662.87 10,370.00 904.93 744.30 178.71 Pass - Major Risk 03-11 - 03-11 - 03-11 Out of range 03-12 - 03-12 - 03-12 Out of range 03-12 - 03-12A - 03-12A Out of range 03-15 - 03-15 - 03-15 Out of range 03-15 - 03-15A - 03-15A Out of range 03-15 - 03-15ALl - 03-15ALl Out of range 03-15 - 03-15B - 03-158 11,614.64 10,500.00 464.55 517.05 128.30 Pass - Major Risk 03-15 - 03-15C - 03-15C 12,400.00 9,450.00 1,041.73 423.59 610.56 Pass - Major Risk 03-17 - 03-17 - 03-17 13,200.00 9,350.00 950.21 171.07 784.12 Pass - Major Risk 03-20 - 03-20 - 03-20 Out of range 03-20 - 03-20A - 03-20A Out of range 03-21 - 03-21 - 03-21 12,100.00 9,450.00 584.94 436.25 138.88 Pass - Major Risk 03-21 - 03-21 A - 03-21A 10,986.91 10,956.00 57.94 8.05 57.63 Pass - Minor 1/10 03-26 - 03-26 - 03-26 Out of range 03-28 - 03-28 - 03-28 Out of range 03-29 - 03-29 - 03-29 13,800.00 9,750.00 1,190.37 766.00 442.23 Pass - Major Risk 03-29 - 03-29A - 03-29A 14,020.00 10,325.00 945.35 776.84 190.26 Pass - Major Risk 03-30 - 03-30 - 03-30 Out of range 03-30 - 03-30A - 03-30A Out of range 03-31 - 03-31 - 03-31 Out of range 03-31 - 03-31 A - 03-31 A Out of range 03-32 - 03-32 - 03-32 Out of range 03-32 - 03-32A - 03-32A Out of range 03-32 - 03-32B - 03-32B 13,900.92 11,125.00 440.22 467.70 142.25 Pass - Major Risk 03-32 - 03-32131-1 - 03-32BL1 13,900.92 11,125.00 440.22 465.18 143.69 Pass - Major Risk 03-32 - 03-32131-1 - 03-32BL1 WP03 13,900.92 11,125.00 440.22 465.18 143.69 Pass - Major Risk 03-32 - 03-32BL2 - 03-32BL2 13,900.92 11,125.00 440.22 465.18 143.69 Pass - Major Risk 03-32 - 03-32BL2 - 03-32131-2 WP03 13,900.92 11,125.00 440.22 465.18 143.69 Pass - Major Risk 03-34 - 03-34B - 03-34B 10,432.00 10,875.00 897.21 735.59 228.02 Pass - Major Risk 03-34 - 03-34CXX - Plan #4 10,432.00 10,875.00 899.27 735.75 227.53 Pass - Major Risk 03-35 - 03-35 - 03-35 Out of range 03-35 - PLAN 03-35A - 03-35A WP01 Out of range 03-36 - 03-36 - 03-36 Out of range 03-36 - 03-36A - 03-36A Out of range 03-36 - PLAN 03-36B - 03-36B WP08A Out of range 03-37 - 03-37 - 03-37 10,900.00 9,950.00 1,428.65 424.77 1,010.31 Pass - Major Risk 17 17-14 - 17-14 - 17-14 10,500.00 12,075.00 908.09 595.43 320.98 Pass - Major Risk EX LAKEST-01 LAKEST-01 - LAKEST-01 - LAKEST-01 Out of range EX SD311016 SD311016 - SD311016 - SD311016 Out of range 11/11/2019 1: 11 04P Page 3 of 4 COMPASS 5000.15 Build 90 woodVZ7 5�t bBP p Anticollision Report Baker s Hughes Company: North America - ALASKA - BP Local Co-ordinate Reference: Well 03-07 Project: PBU TVD Reference: Mean Sea Level Reference Site: 03 MD Reference: KB @ 55.50usft (3-07A:) Site Error: 0.00usft North Reference: True Reference Well: 03-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore PLAN 03-07B Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: 03-07B WP04 Offset TVD Reference: Offset Datum 1200— Reference Depths are relative to KB @ 55.50usft (3-07A:) Coordinates are relative to: 03-07 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27 ' OGP-Usa AK Central Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 1.63° Ladder Plot 1600— 600- ------------------ ----.---- ---- ----'---- -' ------ --12000 1200— C) C) Li c ----- ------ -'---- - ----- - - - - - ` -- -- --' ----- a - cn 800--- UQ) ------------ ------- --' - ---------- 0 m i � 00 2 400-- U U - - --- ------------------ - --- ----- ----- 0 0 2500 5000 7500 10000 12500 15000 -)E- 03-06,03-06,03-06V1 $ OaYle,�il{1iln) $ 03-26,03-26,03-26V4 03-15.03-15,03-15V1 03-32,03-32,03-32 V4 0321 0321A 0321AVO $ 03-15,03-15A, 03-15A V1 -Ar- 0334, 0334CXX, Plan #4 V2 -X- 03-21,03-21,03-21 V1 $ 0315, 03156, 0315B VO -4— 0334, 0334B, 03346 V 1 0335, PLAN 0335A, 0335A V1 P01 VO $ 0315,0315AL1,0315AL1V7 $ 0336,0336A,0336AV5 -i- 0335,0335,0335 V1 $ 0315, 0315C, 0315C VO $ 03-36,03-36,03-36 VII $ 03-17,03-17,03-17 V1 -F 03-02,03-02,03-02 V1 $ 17-14,17-14,17-14V1 $ 0312, 0312A, 0312A VO -rte 03-03,03-03,03-03 V1 0337, 0337, 0337 VO $ 03-12,03-12,03-12 V1 -� 03-07, 03-07A, 03-07A V8 -18r- 03-04,03-04,03-04 V1 03-31,03-31,03-31 V1 $ 03-07,03-07,03-07 V1 $ 03-28,03-28,03-28 V1 0331, 0331A, 0331A VO $ 03-08,03-08, 0308 V1 $ 03-05, 03-05, 03-05 VO $ 0336, PLAN 03366, 03366 VW08A VO $ 03-11,0311,0311 V5 $ 0330,0330A,0330AVO $ LAKEST-01, LAKEST-01, LAKEST-01 V1 11/11/2019 1:11:04PM Page 4 of 4 COMPASS 5000.15 Build 90 t n Z v m 2> oda Z O n m ouoi. 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O C O o 0 0 CD O O O LO r- m 0 0 ^ U o o 0 0 0 0 0 o o Oo C'7 LO I� O V O O O O O O N N �\ � Northing gmoam% C. &q« 000A6ulAoN Obp North America - ALASKA - BP PBU 03 03-07 PLAN 03-07B 03-07B WP04 Plus 500ft MD AOGCC Offset Well Report 11 November, 2019 Baker S Hughes ► BP ,± p Anticollision Report Baker s % Hughes Company: NorthAmerica- ALASKA - BP Project: PBU Reference Site: 03 Site Error: 0.00usft Reference Well: 03-07 Well Error: 0.00usft Reference Wellbore PLAN 03-07B Reference Design: 03-07B WP04 Plus 500ft MD Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 03-07 Mean Sea Level KB @ 55.50usft (3-07A:) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 03-07B WP04 Plus 500ft MD Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum centre distance of 200 Error Surface: Pedal Curve Survey Tool Program Date 11/11/2019 Centre to Measured From To Depth Depth (usft) (usft) Survey (Wellbore) Tool Name Description 94.50 7,894.50 1 : Camera based gyro multisho (03-07) CB -GYRO -MS Camera based gyro multishot 7,968.00 10,310.78 3-07A MWD (03-07A) MWD MWD - Standard 10,310.78 14,520.00 03-07B WP04 Plus 500ft MD (PLAN 03-07 MWD MWD - Standard Summary Site Name Offset Well - Wellbore - Design 03 03-06 - 03-06 - 03-06 03-07 - 03-07 - 03-07 03-07 - PLAN 03-07B - 03-07B WP04 03-08 - 03-08 - 03-08 03-20 - 03-20 - 03-20 03-20 - 03-20A - 03-20A 03-21 - 03-21 A - 03-21 A 03-31 - 03-31 - 03-31 03-31 - 03-31 A - 03-31 A 17 EX LAKEST-01 EX SD311016 SAG RIV ST 1 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 3,298.67 3,325.00 65.51 8,214.36 8,225.00 29.82 13,625.00 13,625.00 0.44 3,526.00 3,525.00 122.00 5,895.31 5,300.00 112.25 5,900.18 5,300.00 112.39 10,986.91 10,956.00 57.94 4,385.75 4,375.00 26.85 4,385.75 4,375.00 26.85 11/11/2019 2:37:37PM Page 2 of 2 COMPASS 5000.15 Build 90 0 0 C (D N U m E .Q N L Y U fd W in 0 U a) .M� W O I M O dCD r - O W C � O d N L Q Q N m 0- 9.S I M O a) 0 LL 0 Q 4F cn CD (� N CU _C_ cn C 3 a L a) V +C. 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Well Bighole CDR2-AC 4 Ram BOP Schematic Date 21 -Nov -17 Quick Test Sub to Otis 1.1 ft —..... —' —' Top of7"Otis O.Oft -----------------—._.—._.—. 4 CDR2 Rig's Drip Pan Distances from top of riser Excluding quick -test sub 4 7-1116" 51k Flange X 7" Otis Box Top of Annular 6.0 ft ydril 7 1/16 Top of Annular Element 6.7 ft Annular Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 . 84 Choke Line Kill Line Cu 2-3/8" x 3-1/2" VERs 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ftIN CL of Top Swab 16.0 ft j 4 Swab Test Pump Hose T1 T2 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS II Ground Level Davies, Stephen F (CED) From: Hyatt, Trevor <Trevor.Hyatt@bp.com> Sent: Thursday, December 5, 2019 1:19 PM To: Davies, Stephen F (CED) Subject: RE: PBU 03-07B (PTD 219-182) - Question Steve, We do not plan to pre -produce 03-07B. Trevor Hyatt BP Exploration (Alaska) GWO — Drilling Engineer Coil Tubing Drilling & Rig Workover Trevor.Hyatt@bp.com Cell: 907-223-3087 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Thursday, December 5, 2019 12:18 PM To: Hyatt, Trevor <Trevor.Hyatt@bp.com> Subject: RE: PBU 03-07B (PTD 219-182) - Question Hi Trevor, Just trying to keep this application moving along... Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Wednesday, December 4, 2019 4:47 PM To: 'Trevor.hyatt@bp.com' <Trevor.hyatt@bp.com> Subject: PBU 03-07B (PTD 219-182) - Question Trevor, Will this planned injection well be pre -produced, or will it be flowed back briefly (a few days) solely to clean up the wellbore? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. TRANSMITTAL LETTER CHECKLIST WELL NAME: ���� 0 ,j 0 79 PTD: 2- <�' - le z- - Development ✓ Service Exploratory _ Stratigraphic Test _ Non -Conventional 12 FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. (If flast two digits AP I No. 50- Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs Pilot Hole acquired for the pilot hole must be clearly differentiated in both well name ( PIS and API number (50- - - - ) from records, data and logs acquired for well name on '-rmit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Exception Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Comuany Name) Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where sam les are first caught and 10' sample intervals throw tar et zones. Please note the following special condition of this permit: Non -Conventional production or production testing of coal bed methane is not allowed for (name of well) until after (Comms Name) has designed Well and implemented a water well testis Program g p gram to provide baseline data on water quality and quantity. (C2MMy Name) must contact the AOGCC I obtain advance approval of such water well testing Pro M. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of F7/', well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite for curves well logs run must be submitted to the AOGCC within 90 da s after com letion, su erasion or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 _ Date: Well Name: PRUDHOE BAY UNIT 03.076 -----Program SER Well bore seg ❑ PTD#:2191820 Company BP Exploration(Al.is ka) Inc. Initial Class/Type SER /PEND GeoArea 890 Unit 11650 On/Off Shore On _ Annular Disposal ❑ Administration 1 Permit fee attached_ 2 Lease number appropriate_ - - Yes Surface Location lies withinADL0028327- Top Productive Interval lies in ADL0028331;_ 3 Unique well name and number - - - - - - . Yes TD Lies in ADL0028328. 4 Well located -in_a_defined_pool _ _ Yes - - - - - - PRUDHOE BAY, PRUDHOE OIL POOL- 64015, governed by CO -341H 5 Well located proper distance- from_ drilling unit -boundary_ _ _ _ Yes _ _ - CO 341_H, Rule 2; There shall be no -restrictions as to well spacing except that no pay shall be . _ _ _ _ _ _ _ - 6 Well located proper distance from other wells_ - - - - - - Yes - - - opened_ in a well closer than 500 feet to -the boundaryof the affected. area. As fanned, well ------------- 7 Sufficient acreage available in drilling unit_- -- - - Yes . conforms to spacing requirements, 8 -if deviated, is -wellbore plat -included - - - - Yes 9 Operator only affected party- - - - - - - - - - - - - - - - Yes 10 Operator has_ appropriate- bond in force - - - - - Yes - 11 Permit can be issued without conservation order_ - - - Yes - ---------------------- -- - ---------------- Appr Date 12 Permit_can be issued without administrative_appr_oval Yes -- - - SFD 12/9/2019 13 Can permit be approved before 15 -day wait_ - - - _ - - - - - Yes _ - - - _ _ - - _ - - - - - - - - - 14 Well located within area and -strata authorized by Injection Order # (put_ 10# in comments) Yes Prudhoe Bay Unit, Eastern Operating _A_rea_is governed by_AIO 4G_issued_ 1-0/15/2015. 15 A11 -wells-within-1/4 _mile_area_of review identified (For service well only) Yes PBU 03-07, 03-07A, 03-08, 03-15B, 03-15C,_03-17, 03-21, 03-21A, 03-29, 03-29A, _ _ ,16 Pre -produced injector: durationof pre production Less than 3 months (For service well only) - - No_ - - - - - - - 03-32B, 03-32BL1, 03-32BL2, 03-3451 03-37, 17-07A, 17-0761 17-14 17 Nonconven. gas conforms to AS31.05.030Q.1_.A),(j.2.A-D) - - - - - _ NA_ - - - - - - - _ - - - - - - - - 18 Conductor string -provided - - - - - - N_A_ - - - - 03-07_13_will be_a coiled_ tubing- sidetrack -from -an existing wellbore_- all drilling in the reservoir_ Engineering 19 Surface casing protects all -known USDWs - - - - - - - NA_ - - 03--07B-will be_a_ coiled_tubing_s_id_etrack from -an existing wellbore.- all drilling in the reservoir_ �21 20 CMT -vol adequate_ to circul_ate_on conductor_ & su_- rf csg NA_ . - 9i - - - - - 03-07Bwill be a coiled_tubing_ sidetrack from_an existin9wellbore --all drilling n the reservoir_ - - CMT_vol adequate to tie-inlong string to surf csg_ _N_A. - - - 03-07_B_will be_a coiled -tubing- sidetrack from.an existing wellbore ---all drilling in the reservoir_ - - - - - - '22 _C_MT will coverall known -productive horizons_- -- - --- ------------- Yes- - - - - - Fully cemented production liner - - - - 23 _Casing designs adequate for C,, B &_permafrost_ - - - _ Yes . - - - - - - 03-07B_will be_a coiled_ tubing- s_idetrack fr_om_an existing wellbore - all drilling in the reservoir_ ;24 Adequatetan_kage_or reserve pit - - - - - - Yes CDR2 is in_ongoing operations with good truck support. 125 If.a_re-drill,has_a1.0-403 for abandonment been approved - - -_ Yes --- --_-.- Sundry _319-546 ------- - - - --- - - - -- -------------------- - - - - -- 26 Adequate wellbore separation -proposed _ - - - - - - - _ Yes All wells but 03-21A pass _m_ajor [isksepa_ration criteria, 03-21A_passes 1:10 risk. Both wells is th_e_prod_zon 27 If_diverter required, does it meet_ regulations_ - - - - _ N _ A - - _ - - 03 -07B -will_ be -a- coiled -tubing _sidetrack fr_om_an existing wellbore_- all drilling in the reservoir_ _ _ - - - - - - Appr Date 28 Drilling fluid program schematic_& equip list adequate_ - - - - - - - _ _ - - - _ Yes -- - - - - - - NIGR 12/9/2019 29 BOPEs,_do-they meet_ regulation - _ --- Yes 1 annular 4 ram stack for CTD -- - -- 30 BO_PE_press rating appropriate; test to -(put psig in comments)_ - - Yes - - - -- - - - - - - 5000 psi stack - - - - - 31 Choke- manifold complies w/API- RP -53 (May 84)_ - . - - - - - - - - - _ - - - Yes 32 Work will occur without operation shutdown_ - - - - - - - Yes CDR2 is in ongoing operations_ - - _ _ - 33 Is presence_ of H2S gas_ probable - - - ---------- Yes BP standard systems place. ---- - ------- 34 Mechanical_condition of wells within AOR verified (For service well only) - Yes 35 Permit can be issued w/o hydrogen, sulfide measures -No D$ 03 wells are_H2_S-bearing. H2S measures are required. Geology 36 _Data -presented on potential oye_rpressure zones _ - -- - - - _Yes - - - - -- Expected reservoir pressure is 7,36 ppg EMW; will be drilled using 8.4 ppg mud and coiled tubing. _ Appr Date 37 Seismicanalys_is_ of shallow gas -zones - - _ _ _ - NA_ - - - - Should higher_pore_pressures be-encou_ntere_d, BP has -immediate access to nearby f1_uid-mixing facilities. SFD 12/4/2019 38 Seabed condition survey (if off -shore) - - - - _ _ - _ - - NA_ - - - - - - One fault will be crossed; Operator considers lost circulation risk to be low._ 39 Contact name/phone for weekly -progress reports_ [exploratory only] - NA_ _ Geologic Commissioner: Date: Engineering Commissioner: Public Date Commissioner Date
