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218-110
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20776-00-00Well Name/No. KUPARUK RIV UNIT 2S-315Completion Status1-OILCompletion Date12/13/2018Permit to Drill2181100Operator ConocoPhillips Alaska, Inc.MD14654TVD6009Current Status1-OIL1/20/2021UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/Res/Neu/Den/NMR/Microscope, Mudlogs, CBL, PPROFYesYesYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC1/11/20192 3578 Electronic Data Set, Filename: 2S-315 VISION Service Memory 13.5 Drilling Data.las30233EDDigital DataC1/11/20193229 10018 Electronic Data Set, Filename: 2S-315 VISION Service Memory 8.5_part 1 Drilling Data_no sigma.las30233EDDigital DataC1/11/20199628 14654 Electronic Data Set, Filename: 2S-315 VISION Service Memory 8.5_part 2 Drilling Data_no sigma.las30233EDDigital DataC1/11/20199900 14648 Electronic Data Set, Filename: 2S-315 VISION Service Memory 8.5_part 2 Ream Up_no sigma.las30233EDDigital DataC1/11/2019103 14654 Electronic Data Set, Filename: 2S-315 VISION Service Memory Drilling Data.las30233EDDigital DataC1/11/2019 Electronic File: 2S-315_VISION_Service_2_Inch_MD_Recorded_Mode_Log.Pdf30233EDDigital DataC1/11/2019 Electronic File: 2S-315_VISION_Service_2_Inch_TVD_Recorded_Mode_Log.Pdf30233EDDigital DataC1/11/2019 Electronic File: 2S-315_VISION_Service_5_Inch_MD_Recorded_Mode_Log.Pdf30233EDDigital DataC1/11/2019 Electronic File: 2S-315_VISION_Service_5_Inch_TVD_Recorded_Mode_Log.Pdf30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad27 EOW Compass Surveys.pdf30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad27 [Canvas].txt30233EDDigital DataWednesday, January 20, 2021AOGCCPage 1 of 82S-315 VISION ,Service Memory Drilling Data.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20776-00-00Well Name/No. KUPARUK RIV UNIT 2S-315Completion Status1-OILCompletion Date12/13/2018Permit to Drill2181100Operator ConocoPhillips Alaska, Inc.MD14654TVD6009Current Status1-OIL1/20/2021UICNoC1/11/2019 Electronic File: 2S-315 Nad27 [Macro].txt30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad27 [Petrel].txt30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad27 [Surveys].txt30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad83 EOW Compass Surveys.pdf30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad83 [Canvas].txt30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad83 [Macro].txt30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad83 [Petrel].txt30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Nad83 [Surveys].txt30233EDDigital DataC1/11/2019 Electronic File: 2S-315 Final Surveys.csv30233EDDigital DataC1/11/2019 Electronic File: 2S-315_DLIS_Data.zip30233EDDigital DataC1/17/2020103 14654 Electronic Data Set, Filename: 2S-315 VISION Service Memory Drilling Data_Rev2.las30233EDDigital DataC1/11/20199627 14655 Electronic Data Set, Filename: CPAI_2S-315_MicroScope_Resistivity_Curves.las30234EDDigital DataC1/11/20199627 14655 Electronic Data Set, Filename: CPAI_2S-315_MicroScope_Resistivity_Images.las30234EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_MicroScope_Deliverables.dlis30234EDDigital DataC1/11/2019 Electronic File: 2S-315_Drilling_12B.xml30234EDDigital DataC1/11/2019 Electronic File: 2S-315_Drilling_3B.xml30234EDDigital DataC1/11/2019 Electronic File: 2S-315_Drilling_60B.xml30234EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_MicroScope_Dynamic_Image_9984-14620ft_20.pdf30234EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_MicroScope_Dynamic_Image_9984-14620ft_200.pdf30234EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_MicroScope_Static_Image_9984-14620ft_20.pdf30234EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_MicroScope_Static_Image_9984-14620ft_200.pdf30234EDDigital DataWednesday, January 20, 2021AOGCCPage 2 of 82S-315 VISION ,Service Memory Drilling Data_Rev2.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20776-00-00Well Name/No. KUPARUK RIV UNIT 2S-315Completion Status1-OILCompletion Date12/13/2018Permit to Drill2181100Operator ConocoPhillips Alaska, Inc.MD14654TVD6009Current Status1-OIL1/20/2021UICNoC1/11/20199900 14517 Electronic Data Set, Filename: CPAI_2S_315_R3_proVISION Plus_9900_14517ft.las30235EDDigital DataC1/11/2019 Electronic File: CPAI_2S_315_R3_proVISION Plus_9900_14517ft.dlis30235EDDigital DataC1/11/2019 Electronic File: CPAI_2S_315_R3_proVISION Plus_9900_14517ft.pdf30235EDDigital DataC1/11/2019 Electronic File: CPAI_2S_315_R3_proVISION processing snaps.pptx30235EDDigital DataC1/11/20193571 9922 Electronic Data Set, Filename: CPAI_2S-315_Processed_SonicScope_R2_8.5_DTCO_3571-9922ft.las30236EDDigital DataC1/11/201910010 14536 Electronic Data Set, Filename: CPAI_2S-315_Processed_SonicScope_R3_8.5in_DTCO_10010-14536ft.las30236EDDigital DataC1/11/20193571 9922 Electronic Data Set, Filename: CPAI_2S-315_Processed_SonicScope_R2_8.5_QPInv_3571-9922ft.las30236EDDigital DataC1/11/201910010 14536 Electronic Data Set, Filename: CPAI_2S-315_Processed_SonicScope_R3_8.5in_QP_10010-14536ft.las30236EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R2_8.5_DTCO_3571-9922ft.dlis30236EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R2_8.5_DTCO_3571-9922ft.pdf30236EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R3_8.5in_DTCO_10010-14536ft.dlis30236EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R3_8.5in_DTCO_10010-14536ft.pdf30236EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R3_8.5in_DTCO_QC_Rt_vs_Rm.pdf30236EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R2_8.5_QPInv_3571-9922ft.dlis30236EDDigital DataWednesday, January 20, 2021AOGCCPage 3 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20776-00-00Well Name/No. KUPARUK RIV UNIT 2S-315Completion Status1-OILCompletion Date12/13/2018Permit to Drill2181100Operator ConocoPhillips Alaska, Inc.MD14654TVD6009Current Status1-OIL1/20/2021UICNoC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R2_8.5_QPInv_3571-9922ft.pdf30236EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R3_8.5in_QP_10010-14536ft.dlis30236EDDigital DataC1/11/2019 Electronic File: CPAI_2S-315_Processed_SonicScope_R3_8.5in_QP_10010-14536ft.pdf30236EDDigital DataC1/11/2019 Electronic File: 2S-315 Geo Morning Report.xls30237EDDigital DataC1/11/2019 Electronic File: 2S-315 Geological Summary.doc30237EDDigital DataC1/11/2019 Electronic File: 2S-315 Geological Summary.pdf30237EDDigital DataC1/11/2019 Electronic File: 2S-315 Geosurvey.xlsm30237EDDigital DataC1/11/2019 Electronic File: 2S-315 MD Lithology Log (TVD).pdf30237EDDigital DataC1/11/2019 Electronic File: 2S-315 MD Lithology Log.pdf30237EDDigital DataC1/11/2019118 14654 Electronic Data Set, Filename: 2S-315_14654 ft_All data.LAS30238EDDigital DataC1/11/201910450 14654 Electronic Data Set, Filename: 2S-315_GeoIsotopes_Composite_QC_Data_10450_14654ft.las30238EDDigital DataC1/11/2019150 14654 Electronic Data Set, Filename: 2S-315_Lithology_Data_150_14654ft.las30238EDDigital DataC1/11/2019 Electronic File: 2S-315_ Drilling Log_14654 ft.pdf30238EDDigital DataC1/11/2019 Electronic File: 2S-315_ Gas Ratio Log_14654 ft.pdf30238EDDigital DataC1/11/2019 Electronic File: 2S-315_ Isotope Composite Log_14654 ft.pdf30238EDDigital DataC1/11/2019 Electronic File: 2S-315_ Mud Log_14654 ft.pdf30238EDDigital DataC1/11/2019 Electronic File: 2S-315_GEOLOG_End_of_well_report_draft.pdf30238EDDigital DataC3/13/2019 Electronic File: 2S-315 Schematic.pdf30443EDDigital DataC3/13/2019 Electronic File: 2S-315 WSR Summary.pdf30443EDDigital DataC3/13/2019 Electronic File: Conoco Phillips - Kuparuk River #2S-315 PJI Updated.pdf30443EDDigital DataWednesday, January 20, 2021AOGCCPage 4 of 82S-315_14654ft_All data.LAS DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20776-00-00Well Name/No. KUPARUK RIV UNIT 2S-315Completion Status1-OILCompletion Date12/13/2018Permit to Drill2181100Operator ConocoPhillips Alaska, Inc.MD14654TVD6009Current Status1-OIL1/20/2021UICNoC3/13/2019 Electronic File: 2S-315 PTS Well Test Total Flow Report.xls30443EDDigital DataC3/13/2019 Electronic File: WPSettings.dat30443EDDigital DataC3/13/2019 Electronic File: IndexerVolumeGuid30443EDDigital DataC3/13/2019 Electronic File: CONOCOPHILLIPS NORTH SLOPE - EBUS_KRU 2S_315_GWPC.xls30443EDDigital DataC3/28/2019 Electronic File: 2S-315 Isotech water analysis Job40911.xls30517EDDigital DataC3/28/2019 Electronic File: 2S-315 KUP LABS_water_analysis_01_24_2019.pdf30517EDDigital DataC3/28/2019 Electronic File: 2S-315 KUP LABS_water_analysis01_29_2019.pdf30517EDDigital DataC3/28/2019 Electronic File: 2S-315 Isotech Mud gas data Job40348.xls30517EDDigital DataC3/28/2019 Electronic File: 2S-315 Isotech Mud gas data_Job40348.pdf30517EDDigital DataC3/28/2019 Electronic File: 2S-315 Isotech water analysis Job40837.xls30517EDDigital DataC3/28/2019 Electronic File: WPSettings.dat30517EDDigital DataC3/28/2019 Electronic File: IndexerVolumeGuid30517EDDigital DataC5/7/201943590 43590 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_14000_ConCu_R01_Sta005.las30723EDDigital DataC5/7/201943590 43590 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_14210_ConCu_R01_Sta007.las30723EDDigital DataC5/7/201913930 14272 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Dynamic_100_ConCu_R01_L026Down.las30723EDDigital DataC5/7/201913948 14260 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Dynamic_100_ConCu_R01_L028Up.las30723EDDigital DataC5/7/201913912 14279 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Dynamic_120_ConCu_R01_L024Down.las30723EDDigital DataWednesday, January 20, 2021AOGCCPage 5 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20776-00-00Well Name/No. KUPARUK RIV UNIT 2S-315Completion Status1-OILCompletion Date12/13/2018Permit to Drill2181100Operator ConocoPhillips Alaska, Inc.MD14654TVD6009Current Status1-OIL1/20/2021UICNoC5/7/201913943 14257 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Dynamic_120_ConCu_R01_L034Up.las30723EDDigital DataC5/7/201913934 14240 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Dynamic_80_ConCu_R01_L029Down.las30723EDDigital DataC5/7/201913942 14255 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Dynamic_80_ConCu_R01_L031Up.las30723EDDigital DataC5/7/201913936 14288 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Shut in_1 hr_ConCu_R01_L037Down.las30723EDDigital DataC5/7/201913930 14302 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Shut in_1 hr_ConCu_R01_L038Up.las30723EDDigital DataC5/7/201913941 14298 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Shut in_2 hr_ConCu_R01_L040Up.las30723EDDigital DataC5/7/201913939 14272 Electronic Data Set, Filename: CPAI_2S-315_PPROF_05May19_Shut in_8 hr_ConCu_R01_L013Up.las30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_14000_ConCu_R01_Sta005.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_14210_ConCu_R01_Sta007.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Dynamic_100_ConCu_R01_L026Down.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Dynamic_100_ConCu_R01_L028Up.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Dynamic_120_ConCu_R01_L024Down.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Dynamic_120_ConCu_R01_L034Up.dlis30723EDDigital DataWednesday, January 20, 2021AOGCCPage 6 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20776-00-00Well Name/No. KUPARUK RIV UNIT 2S-315Completion Status1-OILCompletion Date12/13/2018Permit to Drill2181100Operator ConocoPhillips Alaska, Inc.MD14654TVD6009Current Status1-OIL1/20/2021UICNoC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Dynamic_80_ConCu_R01_L029Down.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Dynamic_80_ConCu_R01_L031Up.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Shut in_1 hr_ConCu_R01_L037Down.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Shut in_1 hr_ConCu_R01_L038Up.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Shut in_2 hr_ConCu_R01_L040Up.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Shut in_8 hr_ConCu_R01_L013Up.dlis30723EDDigital DataC5/7/2019 Electronic File: CPAI_2S-315_PPROF_05May19_Field Print.Pdf30723EDDigital DataC11/15/201910428 14449 Electronic Data Set, Filename: CPAI_2S-315_CBL_09Dec18_ConCu_R01_L009_Main_Pass.las31441EDDigital DataC11/15/201914038 14454 Electronic Data Set, Filename: CPAI_2S-315_CBL_09Dec18_ConCu_R01_L008_Repeat_Pass.las31441EDDigital DataC11/15/2019 Electronic File: CPAI_2S-315_CBL_09Dec18_FieldPrint.Pdf31441EDDigital DataC11/15/2019 Electronic File: CPAI_2S-315_CBL_09Dec18_ConCu_R01_L008_Repeat_Pass.dlis31441EDDigital DataC11/15/2019 Electronic File: CPAI_2S-315_CBL_09Dec18_ConCu_R01_L009_Main_Pass.dlis31441EDDigital DataC11/15/2019 Electronic File: WPSettings.dat31441EDDigital DataC11/15/2019 Electronic File: IndexerVolumeGuid31441EDDigital DataWednesday, January 20, 2021AOGCCPage 7 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20776-00-00Well Name/No. KUPARUK RIV UNIT 2S-315Completion Status1-OILCompletion Date12/13/2018Permit to Drill2181100Operator ConocoPhillips Alaska, Inc.MD14654TVD6009Current Status1-OIL1/20/2021UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date: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:12/13/2018Release Date:1/13/202112/10/2018150 601071689CuttingsWednesday, January 20, 2021AOGCCPage 8 of 8M. Guhl1/20/2021 1 Guhl, Meredith D (CED) From:Alvord, Chip <Chip.Alvord@conocophillips.com> Sent:Friday, January 15, 2021 8:52 AM To:Guhl, Meredith D (CED) Subject:RE: [EXTERNAL]KRU 2S-315, PTD 218-110, Confidentiality Period Expired Meredith, Thanks for the notification. ConocoPhillips ok with letting go of the confidentiality of this well and allowing the data to go public. Appreciate the notification. Best, Chip Alvord From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Thursday, January 14, 2021 8:51 AM To: Alvord, Chip <Chip.Alvord@conocophillips.com> Subject: [EXTERNAL]KRU 2S‐315, PTD 218‐110, Confidentiality Period Expired CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Dear Mr. Alvord, KRU 2S‐315, an exploration well drilled and completed December 13, 2018, is due for release from the 2 year confidentiality period after January 13, 2021. I have checked with Division of Oil and Gas, Department of Natural Resources and to date ConocoPhillips Alaska has not made a request to DNR for extended confidentiality. As these are unusual times, I just wanted to confirm with ConocoPhillips Alaska that no request for extended confidentiality will be made and that ConocoPhillips understand all AOGCC reports and data submitted to the AOGCC associated with KRU 2S‐315 will enter the public realm. Thank you, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793‐1235 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 Meredith Guhl at 907‐793‐1235 or meredith.guhl@alaska.gov. 1 Guhl, Meredith D (CED) From:Frank, Kevin J (DNR) Sent:Monday, January 11, 2021 8:50 AM To:Guhl, Meredith D (CED) Subject:RE: KRU 2S-315, PTD 218-110, Due for release after 1/13/2021 Good morning Meredith, We have not received any request from ConocoPhillips Alaska requesting extended confidentiality for their exploration well KRU 2S‐315, PTD 218‐110. Thanks for checking. Cheers, Kevin Kevin Frank Petroleum Geologist Resource Evaluation Section Manager SOA‐Dept. of Natural Resources Division of Oil and Gas 550 West 7th. Suite 1100 Anchorage, AK 99501‐3560 (907) 269‐8791 kevin.frank@alaska.gov CONFIDENTIAL and PROPRIETARY pursuant to AS 38.05.020(b)(10),(11), and (12) and other applicable laws: This email message including any attachments is for the sole use of the intended recipient(s) and may contain confidential, privileged, or proprietary information also protected under AS 43.05.230 and AS 40.25.100 or other applicable law; any release of this information without proper approval is not authorized. If you are not the intended recipient, any unauthorized disclosure, copying, distribution or action in reliance on the contents of this document is prohibited. If you have received this document in error, please inform the sender immediately and destroy all copies of the original message. From: Guhl, Meredith D (CED) Sent: Tuesday, January 5, 2021 12:36 PM To: Frank, Kevin J (DNR) <kevin.frank@alaska.gov> Subject: KRU 2S‐315, PTD 218‐110, Due for release after 1/13/2021 Hello Kevin, Happy New Year! Has ConocoPhillips Alaska requested extended confidentiality for their exploration well KRU 2S‐315, PTD 218‐110, which is due for release after January 13, 2021? Thank you, Meredith Meredith Guhl 2 Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793‐1235 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 Meredith Guhl at 907‐793‐1235 or meredith.guhl@alaska.gov. schlumbepgep Transmittal #: 22NOV19-SP01 Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska, Inc. Dispatched To: CPAI: Ricky Elgarico Well Name: 2S-315 Rev -2" Date Dispatched: 22 -Nov -19 Service Order #: 18AKA0045 Dispatched By: Stephanie Pacillo Product Description Hardcopy Di ital CODV Looninn Date Color Log Prints: N/A Contents on CD 5 -Dec -18 VISION*Service R It, � JAN 17120 aoGc Digital Data N/A Contents on CD Recorded Mode LAS Data ff X Revision -2 update to corrrect null values and curve name headers SurveysN/A I Contents on CD LWD Partner EOW Data 1 CD Contents on CD CD Data: ' LAS *AOGCC REV -1 previously delivered to Ricky Elgarico 18NOV19-SP01 Received Bv: Please sign and email a copy to: AI ka TSPrintCenter nry slh.corr 4t n: Stepha� Pacillo Guhl, Meredith D (CED) From: Guhl, Meredith D (CED) Sent: Wednesday, November 20, 2019 1:59 PM To: Elgarico, Richard E; Lemke, Sandra D Subject: KRU 25-315: Schlumberger LAS header and null values bad Attachments: KRU 25-315.pdf Hi Sandra and Ricky, I went to load the new LAS file provided yesterday to KRU 25-315, and the header isn't constructed properly and the null value isn't in the file correctly. Old file, which loaded, but was missing a curve looks like this: 103.00000 102.99985 -999.25 -999.25 -999.25 103.50000 103.49985 -999.25 -999.25 -999.25 104.00000 103.99984 -999.25 -999.25 -999.25 104.50000 104.49984 -999.25 -999.25 -999.25 105.00000 104.99983 -999.25 -999.25 -999.25 105.50000 105.49983 -999.25 -999.25 -999.25 106.00000 105.99983 -999.25 -999.25 -999.25 106.50000 106.49982 -999.25 -999.25 -999.25 107.00000 106.99982 -999.25 -999.25 -999.25 107.50000 107.49981 -999.25 -999.25 -999.25 108.00000 107.99981 -999.25 -999.25 -999.25 108.50000 108.49981 -999.25 -999.25 -999.25 109.00000 108.99980 -999.25 -999.25 -999.25 109.50000 109.49980 -999.25 -999.25 -999.25 110.00000 109.99979 -999.25 -999.25 -999.25 110.50000 110.49979 -999.25 -999.25 -999.25 New file, which won't load, looks like this: -Ascii - 103.0 -9999 -9999 -9999 -9999 -9999 103.5 -9999 -9999 -9999 -9999 -9999 104 -9999 -9999 -9999 -9999 -9999 104.5 -9999 -9999 -9999 -9999 -9999 105 -9999 -9999 -9999 -9999 -9999 105.5 -9999 -9999 -9999 -9999 -9999 106 -9999 -9999 -9999 -9999 -9999 106.5 -9999 -9999 -9999 -9999 -9999 107 -9999 -9999 -9999 -9999 -9999 107.5 -9999 -9999 -9999 -9999 -9999 108 -9999 -9999 -9999 -9999 -9999 108.5 -9999 -9999 -9999 -9999 -9999 109 -9999 -9999 -9999 -9999 -9999 109.5 -9999 -9999 -9999 -9999 -9999 110 -9999 -9999 -9999 -9999 -9999 110.5 -9999 -9999 -9999 -9999 -9999 1 I was able to unzip and open the DLIS file in Schlumberger DLIS to ASCII, so that is good. So the CBL has been submitted, and a working DLIS file, but the LAS is still not complete. If you can get me a new LAS by 2 pm Friday, I can check it and we can cross this one off. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2181 10 302-33 ConocoPhillipS RECEIVED, �10V 19 2019 Transmittal #1261 Detail AOGCC Date: 11/19/2019 To (External Party): Email*: meredith.guhl@alaska.gov First Meredith Name*: Last Name*: Guhl Phone (907) 793-1235 Number: Company: AOGCC Address: 333 W. 7th Ave. City: Anchorage State: Alaska Zip Code: 99501 Sent Via: Justification: Compliance From (CPAI Contact): Email*: richard.e.elgarico@conocophillips.com First Name*: Ricky Last Name*: Elgarico Phone Number: (907) 265-6580 Company: CPAI Address: 700 G Street City: Anchorage State: AK Zip Code: 99501 Transmittal Info Tracking #: Data Detail Quantity*: Description*: Type*: 1 2S-315 LWD Data Replacement USB Drive Attachments: t_l5 Vja-,- �--% ua�5 WVLY Received By: Signa ure: Approver: Signature: Date: l) I2o11q VMF�'�5e�rrn wNA Date: v Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax CGis, r IDT -P,11`17 UL Delivered to: x' AOGCC ATTN: Natural Resources Technician II -% Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 t- Anchorage, AK 99501 218110 38723 memo �=� IFNAME 1A -04A 2A-09 1R-07 API # 50-029-20621-01 50-103-20059-00 50-029-21332-00 ORDER # EBNL-00001 EOSH-00041 EOSH-00042 FIELD NAME KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER DESCRIPTION WL WL WL DEUVERABLE DESCRIPTION Caliper Rev1 Caliper Caliper r, FINAL FIELD FINAL FIELD FINAL FIELD Color r r GGED Prints 4 -Apr -19 17 -Apr -19 18 -Apr -19 CD's 1 1 1 2A-08 1y-11 50-103-20049-00 50-029-20926-00 DWUJ-00092 EBNL-00016 KUPARUK RIVER KUPARUK RIVER WL WL IPROF LDL FINAL FIELD FINAL FIELD 28 -Apr -19 28 -Apr -19 1 1 213-07 1A-01 2X-10 50-029-21080-00 50-029-20590-00 50-029-21187-00 DWUJ-00093 EBNL-00018 DWUJ-00094 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL IPROF PPROF PPROF FINAL FIELD FINAL FIELD FINAL FIELD 29 -Apr -19 30 -Apr -19 30 -Apr -19 1 1 1 3H-21 2S-315 50-103-20094-00 50-103-20776-00 EBSI-00004 EBNL-00020 1 KUPARUK RIVER KUPARUK RIVER WL WL Caliper PPROF FINAL FIELD FINAL FIELD 3 -May -19 5 -May -19 1 1 r. fED a 10 Tr ns ittal Re I 'X tl9 a Print Na Signature Date Please return via courier or sign/scan and email a copy to Schlumberger and CPAI. AlaskaPTSPrintCenterslb.com Tom.Osterkamogconocophillips.com MnDUENTIAL Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Guhl, Meredith D (CED) From: Guhl, Meredith D (CED) Sent: Tuesday, November 5, 2019 3:16 PM To: Lemke, Sandra D Cc: Elgarico, Richard E Subject: PTD 218-110, KRU 2S-315, Additional Data Requested Hello Sandra, In a review of the 10-407 submitted for KRU 2S-315, it was noted that a CBL was run on 12/9/2018 by SLB. That digital log data has not yet been provided to the AOGCC. Also, the LAS file for the Vision Service is missing the P34L curve line. When I attempted to open the DLIS file, to convert it to LAS in case the curve line was in that file, the DLIS would not open and requested a password. Confirmation x 2S-315 DLIS_Data.zip Archive is not readable. Would you like to try a password: Yes No Please provide a complete LAS file, a working DLIS file, and the CBL log digital data for this well. Please provide the data by November 19, 2019. You may provide the requested data on a single thumb drive, addressed to my attention. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 218110 RECEIVED3 14 4 1 Conor NOV 15 2019 TRANSMITTAL AOGC CONFIDENTIAL DA TA FROM: Sandra D. Lemke, ATO -704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. 7t" Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2S-315 Permit: 218-110 DATE: 11/15/2019 Transmitted: Kuparuk River Unit 2S-315 (Cairn) USB drive _J CPAl-2S-315_CBL_D9Dec1B_CanCu_RD1_LCtDS_Fepeat_Pass.dlis j CPAl-2S-315_CBL_G9Dec1B_CanCu_RD1_LCCtS_Repeat_Pass;las: ? CPAI_2S-315_CBL_DgDec1g_ConCu_ROi1_LO09_Main_P'as�-,.dlis -' CP I_2S-315_C BL_C#9Dec1 _ConCu_RO1_LCC(9_Main_PasE.las: (:PAI-25-315-CBL-Cl�L)ecl�_FieldP rint, Pdf Size Date n-jedi€ied Tvpe 1,926 KB 13,275 kF 1,dD1 KR _6,416 KB 4,400 K6 12-I' 1'^ 1.-� Pf.1 DLIS File PPA 1 : 1C1.'�PNl LAS File DLIS File LAS File Fcrit PhantcmPU„ Transmittal instructions: please promptly sign, scan, and e-mail to Sandra. D. Lemke0conocophiXos.com CC: 2S-315 - e -transmittal well folder Receipt: � Date: Alaska/IT--GGRE ono coP fillips Alaska I Office: 907.265.6947; Mobile 907 440 4512 110"" ConocoMilips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO -704 TO: Abby Bell ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. 7'h Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2S-315 Permit: 218-110 DATE: 3/27/2019 Transmitted: I Kuparuk River Unit 12S-315 (Cairn) I USB drive 2 1 8 1 10 2S-315 Isotech Mud gas data Job40348.xls 1/8/2019 12:29 PM N/licrosoft Excel 97— 338 KB 2S-315 Isotech Mud gas data - Job4O340,.pdf 1,`8/201912:29 PM Foxit PhantomPD... 85 KB *L.'2S-315 Isotech water analysis Job40937,xls 3/27/2,01911:1U AM 1 Nlicrosoft Excel 97_ 285 KB, 2S-315 Isotech water analysis Job4091 I xls 3/26/2019 5:30 PPA Microsoft Excel 97 ... 269 KB 2S-315 KUP LABS -water - analysis- 0124 - 2019.pdf 1! 3 CD 20197; 34 AM Foxit PhantomPl) ... 431 B F,'Q1 2S-315 KUP LABS-water-analysi--�01-29--7-Dl9,pdf Z-'3', -201911:56 AM Foxit P h a nto m P D ... 42 KB 30517 INo rock data was collected from the well, and the oil samples we collected and are in process of analysis. I ransmittal instructions: please promptly sign, scan, and e-mail to Sandra. D.Lemke(aconocophi/lips.com CC: 2S-315 - e -transmittal well folder 4lIq �-' Receipt: Date: Alaska/IT-GGRE I Co Phillips Alaska I Office: 907.265.6947; Mobile 907.440.4512 RECEIVE["" ALAS' OIL AND GAS CONSERVATION COW- 'ION REPO. (OF SUNDRY WELL OPERA.:ONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ rforate New Pool ❑ Repair Well ❑Re-enter Susp Well ❑ Other Testing 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory 0 Stratigraphic ❑ Service ❑ 218-110 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20776-00-00 7. Property Designation (Lease Number): 8. well Name and Number KRU 2S-315 ADL 025603/ ADL 025608 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field'/Pool(s): N/A Ku aruk River Field/Exploratory 11. Present Well Condition Summary: Total Depth measured 14654' feel Plugs measured N/A feet true vertical 6009' feel Junk measured N/A feet Effective Depth measured 14654' feel Packer measured 14030', 14266 feet true vertical 6009' feet true vertical 5569', 5735' feet Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 119' 119' Surface 3530' 10-3/4" 3571' 2636' Production 14558' 7-5/8" 14558' 5941' 14173'-14203' MD, feet Perforation depth: Measured depth: 14315'-14345' MD 5669'-5690' TVD, feet True Vertical depth: 5769'-5790' TVD Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 14300' MD 5758' TVD Packers and SSSV (type, measured and true vertical de SSSV: NONE N/A N/A PACKER: Baker Premier 14030' MD 5569' TVD PACKER: Baker Premier 14266' MD 5734' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 14173'-14203' MD and 14315'-14345' MD Treatment descriptions including volumes used and final pressure. Total Well- 2 stages 304,689 Itis of 20/40 proppant placed... see attached frac treatment report for full details. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 84 403 694 1493 405 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑� Development ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation DataO GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-548 Contact Name: Sandeep Pedam Authorized Name: Sandeep Pedam Contact Email: Sandeep.Pedam@conocophillips.com Authorized Title: Staff Completions Engineer rJOgyp 4P Contact Phone: 263-4724 ►/ (907) Authorized Signature: Date: S _ 13 — Ton Form 10-404 Revised 4/2017�✓ bmit Ori inal Onl y V'4-51 XJIMq 3'�� !` RBDMSMAR 13 204 g Y Ar- KUP PROD WELLNAME 2S-315 :LLBORE 2S-315 COIIOCOPI Well Attributes Max Angle & MD TD IIIIIpS Alaska, Inc. Field Name Wellbore APIIUWI Wellbore StaWs Incl (") MD (ftKB) Act atm (ftKB) TRACT OPERATION CAIRNTRI 501032077600 PROD 76.26 3,123.81 14,654.0 te Comment H2S (ppm) Date Annotation End DaKB-Gm (ft) RIg Release Date SSSV. NIPPLE LAST WO: 3942 12113/2018 I SLANT -2S-315, 3/11/20191: 36: 47 PM Last Tag Vertical schematic (aclua0 Annotation Depth (ftKB) I End Date Wellbore Last Mod By Last Tag: RKB 14,337.0 12/18/2018 2S-315 Jzernlbaej HANGER; 356- Last Rev Reason Annotation End Date Wellbore I Last Mod By .. .................. ................._........ .. .. ..__ ..... Rev Reason Installed GLYs 1/16/2019 2S-315 Jzernlbaej Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Will -en (I... Grade Top Thread CONDUCTOR 16 15.25 40.5 119.0 119.0 62.50 H40 Welded ..................... .. .. ..... _.. Casing Description 10 (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (I... Grade Top Thread 1013,11) SURFACE 103/4 9.95 40. 3,570.9 2,635.8 45.50 L-80 Hydril 563 Casing Description OD (In) ID (in) T.,'11111(13, Set Depth (ftKB) Set Depth (TVD)... WtrLen (I... Grade Top Thread PRODUCTION 75/8 6.88 37.8 14,558.4 5,940.8 29.70 IL80 TXP-m Tubing Strings Tubing Description String Me... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ib/rt) Grade Top Connection TUBING- 31/2 2.99 35.6 14,300.0 5,758.2 9.30 L-80 EUE-m PRODUCTION Completion Details Top(TVD) Top Incl Nominal Top (ftKB) (ftKB) (") Item Des Com ID (in) 35.6 35 6 0.00 HANGER Hanger, 4-1/2" x 10-3/4" Gen 5, FMC TC -1A . SAS TYPE H PV 3.860 CONDUCTOR, 40 527.1 527.1 1.69 NIPPLE 3-1/2" Nipple, Cameo, 2,875' DS Profile, SN:T09 412 (4.9° 2.875 hole hole angle) 13,9 -0.1 5,492.0 45.48 NIPPLE 3-1/2" X Nipple, Carrico, 2.813", SN:2662-15 (45.48° 2.813 hole angle) NIPPLE, 527.1 13,972.6 5.528.8 45.48 GAUGE Gauge Carrier, SLB, SGM With Sapphire tubing pressure gauge, 2.896 SN:CI6GM-0460 14,030.2 5,569.2 45.52 PACKER Packer, Baker 3 112" x 75/8" Premier CN 106290353-02 2.880 14182.2 5,675.7 45.52 SLIDING Baker 2.81' X profile CMU Sliding Sleeve (1443308) OPENED 2.810 SLEEVE 1/5/2018 GAS LIFT; 2,919.6 14,266.2 5,734.5 45.52 PACKER Packer, Baker 3 1/2" x 7 518" Premier SN 106749821 2.870 14,282.4 5,745.9 45.51 NIPPLE 3-1/2" GXN Nipple, Camco, 2.813" , 2.812" 2.75 no-go ) SN:2610- 2.812 3 (45.5° hole angle) 14.,293.7 5,753.8 45.51 CASING 3 112" X 7 518" Trailblazer Casing scraper Tool SN 0131349 2.810 SCRAPER 14.298.7 5,757.3 45.51 MULE SHOE 3.5" WLEG Mule Shoe 3.010 SURFACE, 40.4-3,570 9 Perforations &Slots Shot Dens Top(TVD) Btm(TVD) IshotsfR Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Com 14,173.0 14,203.0 5,6692 5,690.2 12/10/2018 6.0 Perforated 14,315.0 14,345.0 5,768.7 5,789.7 12/22/2018 6.0 IPERF 2.5' HSD, HyperJet 2506, _ - -- 6SPF, 60 -deg Phasing, s/ 10.5g RDX. WeIITec Tractor Deployed GAS LIFT 13.829s Frac Summary Start Date Proppant Designed hin) Proppant In Formation (Ib) 1/20/2019 150,000.0 150,013.0 Stg # Start Date Top Depth (ftKB) Blm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1 1/20/2019 2,591.00 2,736.00 NIPPLE, 13,920.1 Start Date Proppant Designed (Ib) Proppant In Formation (lb) 1/20/2019 150,000.0 154676.0 Stg # IstartDate Tap Dep[h (ftKB) Btm (ftKB) Link to Flultl System Vol Clean (bbl) Vol Slurry (bbl) 2 1/5/2019 2,467.00 2,467.00 Mandrel Inserts GAUGE; 13,972.6 St ad Top (TVD) N TOpgtKB) (ftKB) Make Valve Latch PortSize TRO Run Model Do (in) Be, Type Type (in) (psi) Run Date Com 1 2,919,81 2,465.2 Camco KBMG 1 1/2 GAS LIFT GLV RK 0.188 1,803.0 1/16/2019 2 13,829.8 5,428 7 C--KBMG 1 1 GAS LIFT OV BK 1 0.2501 0.0 1/16/2019 PACKER; 14,030.2 - Notes: General &Safety End Datc Annotation 1/16/2019 i • NO TELower Zone Fracture Treatment purnped `150,013 Ills of proppant & 2,351 bbls H2O in Bermuda 1/16/2019 NO I EUpper Zone Fracture Treatment pumped` 154,676 lbs of proppant & 2,37lbbS H2O in Caim thru SS 7 1/17/2019 INOTE 'View Schematic w/ Alaska Schematic10.0 n -elk. I` cz SLIDING SLEEVE, 14,182.2 Perforaled ,14,173.0-14,2030- PACKER, 14,266.2 NIPPLE, 14,282.4 MULE SHOE', 14,298.7 IPERF', 14,315.0-14,345.0-. [ �'A '• _^- � PRODUCTION, 37.8-14,558.4 2S-315 DTTMSTART JOBTYP SUMMARYOPS 12/21/18 PERFORATIONS - PERFORM TRACTOR AND PERFORATING SYSTEM CHECKS. TROUBLESHOOT TOOL ELINE COMMUNICATION ISSUES. ALL CHECKED OUT AND LAY DOWN TOOLS FOR A.M START. 12/21/18 TEST -LOG -PROFILE PERFORM TRACTOR AND PERFORATING SYSTEM CHECKS. TROUBLESHOOT TOOL COMMUNICATION ISSUES. ALL CHECKED OUT AND LAY DOWN TOOLS FOR A.M START. 12/22/18 TEST -LOG -PROFILE TD TAGGED AT 14417'. PERFORATE INTERVAL 14315'— 14345', CCL TO TOP SHOT = 6.0 FT, CCL STOP DEPTH = 14309', LOG CORRELATED TO SLB CBL DATED 09 -DEC -2018. r DOWNHOLE GAUGE DATA ACQUIRED DURING PERFORATING. (ATTACHED) 12/22/18 `� PERFORATIONS - TD TAGGED AT 14417'. PERFORATE INTERVAL 14315'— 14345', CCL TO TOP SHOT = 6.0 FT, ELINE CCL STOP DEPTH = 14309', LOG CORRELATED TO SLB CBL DATED 09 -DEC -2018. DOWNHOLE GAUGE DATA ACQUIRED DURING PERFORATING. (ATTACHED) 12/31/18 TEST -LOG -PROFILE MOVE IN/RIG UP TREE SAVER, FRAC PACKAGE AND TANKS. 12/31/18 PERFORATIONS - ELINE MOVE IN/RIG UP TREE SAVER, FRAC PACKAGE AND TANKS. 1/1/19 TEST -LOG -PROFILE MOBILIZED PTS EQUIPMENT TO LOCATION, START PTS RIG UP 1/2/19 PERFORATIONS - PUMPED DIAGNOSTIC FRACTURE INJECTION TEST (DFIT): 8 -BPM, 100 -BBL SEAWATER ELINE MINI -FRAC AND 125 -BBL SEAWATER FLUSH, WITH 20 -BBL LVT FREEZE PROTECT. BREAKDOWN PRESSURE 1692 -PSI, 4128 -PSI BHP. ISIP: 1145 -PSI, 3461 -PSI BHP. MONITORED FALL-OFF APPROXIMATELY 3 -HR FOR SURFACE PRESSURE AND ALL-NIGHT ACQUIRING BHP. 1/2/19 TEST -LOG -PROFILE PUMPED DIAGNOSTIC FRACTURE INJECTION TEST (DFIT): 8 -BPM, 100 -BBL SEAWATER MINI -FRAC AND 125 -BBL SEAWATER FLUSH, WITH 20 -BBL LVT FREEZE PROTECT. BREAKDOWN PRESSURE 1692 -PSI, 4128 -PSI BHP. ISIP: 1145 -PSI, 3461 -PSI BHP. MONITORED FALL-OFF APPROXIMATELY 3 -HR FOR SURFACE PRESSURE AND ALL-NIGHT ACQUIRING BHP. 1/3/19 PERFORATIONS - Pumped Stage 1 (Lower Cairn) fracture stimulation treatmentIn acing 150 013-Ihs tntaI nrnn ant - +-' ELINE (148,513 -lbs 20/40 Wanli and 1500 -lbs 100 mesh), 2351 -bbl water and 17 -bbl LVT downhole. Pumped 23.3 -BPM max rate, 5824 -psi max treating pressure (3818 -psi max BHP). Max prop concentration stage 5 -PPA. ISIP: 3594 -psi BHP, 1336 -psi STP. 5 min: 3521 -psi BHP 10 min: 3477 - psi BHP 15 min: 3446 -psi BHP 1/3/19 TEST -LOG -PROFILE Pumped Stage 1 (Lower Cairn) fracture stimulation treatment placing 150,013 -lbs total proppant (148,513 -lbs 20/40 Wanli and 1500 -lbs 100 mesh), 2351 -bbl water and 17 -bbl LVT downhole. Pumped 23.3 -BPM max rate; 5824 -psi max treating pressure (3818 -psi max BHP). Max prop concentration stage 5 -PPA. ISIP: 3594 -psi BHP, 1336 -psi STP. 5 min: 3521 -psi BHP 10 min: 3477 - psi BHP 15 min: 3446 -psi BHP 1/4/19 PERFORATIONS - DRIFT & TAG TO 14346' SLM w/ 1.75" BAILER. BRUSH 'N FLUSH TUBING & 2.81" XN NIPPLE ELINE @ 14282' RKB, IN PROGRESS. 1/4/19 TEST -LOG -PROFILE DRIFT & TAG TO 14346' SLM w/ 1.75" BAILER. BRUSH 'N FLUSH TUBING & 2.81" XN NIPPLE @ 14282' RKB, IN PROGRESS. 1/5/19 PERFORATIONS - SET 2.81" PXN PLUG W/ SPARTEK GAUGES a 14282' RKB. OBTAINED MIT -T 4000 PSI, ELINE OPENED CMU @ 14182' RKB. READY FOR LRS TO PERFORM SRIT TEST. 1/5/19 (� ! TEST -LOG -PROFILE SET 2.81" PXN PLUG W/ SPARTEK GAUGES @ 14282' RKB. OBTAINED MIT -T 4000 PSI, OPENED CMU (a) 14182' RKB READY FOR LRS TO PERFORM SRIT TEST. 1/5/19 ��ERFORATIONS - CONFIRMED SLIDING SLEEVE OPENED. PERFORMED STEP -RATE INJECTION TEST (SRIT) i ELINE FROM 0.5 -BPM TO 5.0 -BPM. 1/6/19 TEST -LOG -PROFILE LRS CONFIRMED SLIDING SLEEVE OPENED. PERFORMED STEP -RATE INJECTION TEST (SRIT) FROM 0.5 -BPM TO 5.0 -BPM. v Pumped Stage 2 (Upper Cairn) fracture stimulation treatment placina 154.676 -lbs 20/40 Wanli,� /, r✓� proppant, 2371 -bbl water seawater, and 20 -bbl LVT downhole. Pumped 25.1 -BPM max rate; 4140 - psi max treating pressure (6750 psi max BHP). Max prop concentration stage 6 -PPA. ISIP: 3726 -psi BHP, 1771 -psi STP 5 min: 3586 -psi BHP 10 min: 3537 -psi BHP 15 min: 3509 -psi BHP 1/6/19 PERFORATIONS - ELINE Pumped Stage 2 (Upper Cairn) fracture stimulation treatment placing 154,676 -lbs 20/40 Wanli proppant, 2371-bbi water seawater, and 20 -bbl LVT downhole. Pumped 25.1 -BPM max rate; 4140 - psi max treating pressure (6750 -psi max BHP). Max prop concentration stage 6 -PPA. ISIP: 3726 -psi BHP, 1771 -psi STP 5 min: 3586 -psi BHP 10 min: 3537 -psi BHP 15 min: 3509 -psi BHP 1/13/19 TEST -LOG -PROFILE TAG @ 14189' RKB (SAMPLE OBTAINED); SET CATCHER ASSEMBLY @ 13920' RKB; PULLED DMY @ 13829' RKB & ATTEMPT TO SET OV. IN PROGRESS. 1/13/19 PERFORATIONS - TAG @ 14189' RKB (SAMPLE OBTAINED); SET CATCHER ASSEMBLY @ 13920' RKB; PULLED ELINE DMY @ 13829' RKB & ATTEMPT TO SET OV. IN PROGRESS. 1/16/19 PERFORATIONS - PULLED DV FROM STATION 1 & 2. SET OV AT STATION #2 (13,830 RKB) AND GLV AT ELINE STATION #1 (2,920' RKB) IA DDT PASSED. PULLED CATCHER. JOB COMPLETE. 2S-315 DTTMSTART JOBTYP SUMMARYOPS 12/21/18 PERFORATIONS - PERFORM TRACTOR AND PERFORATING SYSTEM CHECKS. TROUBLESHOOT TOOL ELINE COMMUNICATION ISSUES. ALL CHECKED OUT AND LAY DOWN TOOLS FOR A.M START. 12/21/18 TEST -LOG -PROFILE PERFORM TRACTOR AND PERFORATING SYSTEM CHECKS. TROUBLESHOOT TOOL COMMUNICATION ISSUES. ALL CHECKED OUT AND LAY DOWN TOOLS FOR A.M START. 12/22/18 TEST -LOG -PROFILE TD TAGGED AT 14417'. PERFORATE INTERVAL 14315'— 14345',CCL TO TOP SHOT = 6.0 FT, CCL STOP DEPTH = 14309', LOG CORRELATED TO SLB CBL DATED 09 -DEC -2018, DOWNHOLE GAUGE DATA ACQUIRED DURING PERFORATING. (ATTACHED) 12/22/18 V PERFORATIONS - TD TAGGED AT 14417'. PERFORATE INTERVAL 14315'— 143451, CCL TO TOP SHOT = 6.0 FT, ELINE CCL STOP DEPTH = 14309', LOG CORRELATED TO SLB CBL DATED 09 -DEC -2018. DOWNHOLE GAUGE DATA ACQUIRED DURING PERFORATING. (ATTACHED) 12/31/18 TEST -LOG -PROFILE MOVE IN/RIG UP TREE SAVER, FRAC PACKAGE AND TANKS. 12/31/18 PERFORATIONS - ELINE MOVE IN/RIG UP TREE SAVER, FRAC PACKAGE AND TANKS. 1/1/19 TEST -LOG -PROFILE MOBILIZED PTS EQUIPMENT TO LOCATION, START PTS RIG UP 1/2/19 PERFORATIONS - PUMPED DIAGNOSTIC FRACTURE INJECTION TEST (DFIT): 8 -BPM, 100 -BBL SEAWATER ELINE MINI -FRAC AND 125 -BBL SEAWATER FLUSH, WITH 20 -BBL LVT FREEZE PROTECT. BREAKDOWN PRESSURE 1692 -PSI, 4128 -PSI BHP. ISIP: 1145 -PSI, 3461 -PSI BHP. MONITORED FALL-OFF APPROXIMATELY 3 -HR FOR SURFACE PRESSURE AND ALL-NIGHT ACQUIRING BHP. 1/2/19 TEST -LOG -PROFILE PUMPED DIAGNOSTIC FRACTURE INJECTION TEST (DFIT): 8 -BPM, 100 -BBL SEAWATER MINI -FRAC AND 125 -BBL SEAWATER FLUSH, WITH 20 -BBL LVT FREEZE PROTECT. BREAKDOWN PRESSURE 1692 -PSI, 4128 -PSI BHP. ISIP: 1145 -PSI, 3461 -PSI BHP. MONITORED FALL-OFF APPROXIMATELY 3 -HR FOR SURFACE PRESSURE AND ALL-NIGHT ACQUIRING BHP. 1/3/19 PERFORATIONS - Pumped Stage 1 (Lower Cairn) fracture stimulation treatmentIn acing 150 013 ELINE 'pant (148,513 -lbs 20/40 Wanli and 1500 -lbs 100 mesh), 2351 -bbl water and 17 -bbl LVT downhole. Pumped 23.3 -BPM max rate; 5824 -psi max treating pressure (3818 -psi max BHP). Max prop concentration stage 5 -PPA. ISIP: 3594 -psi BHP, 1336 -psi STP. 5 min: 3521 -psi BHP 10 min: 3477 - psi BHP 15 min: 3446 -psi BHP 1/3/19 TEST -LOG -PROFILE Pumped Stage 1 (Lower Cairn) fracture stimulation treatment placing 150,013 -lbs total proppant (148,513 -lbs 20/40 Wanli and 1500 -lbs 100 mesh), 2351 -bbl water and 17 -bbl LVT downhole. Pumped 23.3 -BPM max rate; 5824 -psi max treating pressure (3818 -psi max BHP). Max prop concentration stage 5 -PPA. ISIP: 3594 -psi BHP, 1336 -psi STP. 5 min: 3521 -psi BHP 10 min: 3477 - psi BHP 15 min: 3446 -psi BHP 1/4/19 PERFORATIONS - DRIFT & TAG TO 14346' SLM w/ 1.75" BAILER. BRUSH 'N FLUSH TUBING & 2.81" XN NIPPLE ELINE @ 14282' RKB, IN PROGRESS. 1/4/19 TEST -LOG -PROFILE DRIFT & TAG TO 14346' SLM w/ 1.75" BAILER. BRUSH 'N FLUSH TUBING & 2.81" XN NIPPLE @ 14282' RKB, IN PROGRESS. 1/5/19 PERFORATIONS - _ ET 2.81" PAN PLUG W/ SPARTEK GAUGES @ 142$2' RKB. OBTAINED MIT -T 4000 PSI, (� ELINE OPENED CMU @ 14182' RKB. READY FOR LRS TO PERFORM SRIT TEST. 1/5/19 fTEST-LOG-PROFILE SET 2.81" PXN PLUG W/ SPARTEK GAUGES @ 14282' RKB. OBTAINED MIT -T 4000 PSI, OPENED CMU (cry 14182' RKB. READY FOR LRS TO PERFORM SRIT TEST. 1/5/19 PERFORATIONS - CONFIRMED SLIDING SLEEVE OPENED. PERFORMED STEP -RATE INJECTION TEST (SRIT) ELINE FROM 0.5 -BPM TO 5.0 -BPM. 1/6/19 TEST -LOG -PROFILE LRS CONFIRMED SLIDING SLEEVE OPENED. PERFORMED STEP -RATE INJECTION TEST (SRIT) FROM 0.5 -BPM TO 5.0 -BPM, Pumped Stage 2 (Upper Cairn) fracture stimulation treatment placing 154.676 -lbs 20/40 Wanli proppant, 2371 -bbl water seawater, and 20 -bbl LVT downhole. Pumped 25.1 -BPM max rate; 4140 - psi max treating pressure (6750 Psi max BHP) Max prop concentration stage 6 -PPA. ISIP: 3726 Psi BHP, 1771 -psi STP 5 min: 3586 -psi BHP 10 min: 3537 -psi BHP 15 min: 3509 -psi BHP 1/6/19 PERFORATIONS - ELINE Pumped Stage 2 (Upper Cairn) fracture stimulation treatment placing 154,676 -lbs 20/40 Wanli proppant, 2371 -bbl water seawater, and 20 -bbl LVT downhole. Pumped 25.1 -BPM max rate; 4140 - psi max treating pressure (6750 -psi max BHP). Max prop concentration stage 6 -PPA. ISIP: 3726 -psi BHP, 1771 -psi STP 5 min: 3586 -psi BHP 10 min: 3537 -psi BHP 15 min: 3509 -psi BHP 1/13/19 TEST -LOG -PROFILE TAG @ 14189' RKB (SAMPLE OBTAINED), SET CATCHER ASSEMBLY @ 13920' RKB; PULLED DMY @ 13829' RKB & ATTEMPT TO SET OV. IN PROGRESS. 1/13/19 PERFORATIONS - TAG @ 14189' RKB (SAMPLE OBTAINED); SET CATCHER ASSEMBLY @ 13920' RKB; PULLED ELINE DMY @ 13829' RKB & ATTEMPT TO SET OV. IN PROGRESS. 1/16/19 PERFORATIONS - PULLED DV FROM STATION 1 & 2. SET OV AT STATION #2 (13,830 RKB) AND GLV AT ELINE STATION #1 (2,920' RKB) IA DDT PASSED. PULLED CATCHER. JOB COMPLETE. 1/16/19 TEST-LOG-PROFILE , iLLED DV FROM STATION 1 &2. SET OV AT Sl-„ ON #2 (13,830 RKB) AND GLV AT STATION #1 (2,920' RKB) IA DDT PASSED. PULLED CATCHER. JOB COMPLETE. 1/17/19 TEST-LOG-PROFILE COMPLETE JOB WALK THUR WITH OPS. PTS CONTINUE FINAL RIGUP. DTH IN PROCESS OF HOOTCHING PTS EQUIPMENT. 1/18/19 TEST-LOG-PROFILE COMPLETED FINAL RIG UP. LP TEST WITH N2 ON ALL PTS SURFACE EQUIPMENT SUCCESSFUL. LP TEST WITH DIESEL 1/19/19 TEST-LOG-PROFILE COMPLETED HIGH PRESSURE HYDRO TEST OF ALL PTS SURFACE EQUIPMENT. WRAPPING AND HEATING SURFACE LINES. 1/20/19 TEST-LOG-PROFILE WRAPING AND HEATING OF SURFACE HARDLINE. STANDBY FOR FINAL OPS WALK DOWN. SSV FAILED FUNCTION TEST. TROUBLE SHOOT IN PROCESS. 1/21/19 TEST-LOG-PROFILE COMPLETED WRAPING AND HEATING OF SURFACE HARDLINE. SSV FAILED FUNCTION TEST. SSV REPAIRED. FINAL JOB WALK DOWN WITH OPERATIONS IS COMPLETE. MOC IS APPROVED. IT WAS AGREED TO OPEN WELL IN THE AM AFTER CREW CHANGE. 1/22/19 TEST-LOG-PROFILE HOLD PRE JOB SAFETY MEETING. OPEN WELL AS PER PROCEDURE. 1/23/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP IS 316 BBLS ADJUSTING N2 RATE AND CHOKE SETTING AS REQUIRED TO STABILIZE FLOW. 1/24/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP IS 685 BBLS ADJUSTING N2 RATE AND CHOKE SETTING AS REQUIRED TO STABLIZE FLOW. 1/25/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP IS 1246 BBLS. N2 REACHED OV AT 13,830'. 1/26/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP IS 2112 BBLS. 1/27/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS TOTAL RETURNS SINCE POP IS 3056 BBLS. 1/28/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP IS 3849 BBLS. 1/29/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS, TOTAL RETURNS SINCE POP IS 4592 BBLS. WATER SAMPLES SENT TO THE LAB. Samples: StartEnd Oill .0111:5013:26 0 Gas1.0211:5013:26 Oi11.0315:5517:10 Gas1.0415:5517:10 Oill .0518:5021:15 Gas1.0618:5021:15 IATA 5-gal cans 1.0718:3019:30 1.0818:3019:30 1.0918:3019:30 1.1018:3019:30 1/30/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP IS 5272 BBLS. 1/31/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP IS 5876 BBLS. 2/1/19 TEST-LOG-PROFILE FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP IS 6000 BBLS. COMPLETED FLOWBACK OF FRAC FLUIDS (6000 BBLS TOTAL). SI WELL AT 05:40 AM. LRS FP'D TBG AND SURFACE LINES. ALSO PUMPED 5 BBLS OF METH IN PRODUCTION FL PER DSO REQUEST. SLICKLINE ARRIVED ON LOCATION AT 07:15 AM TO CLOSE SLIDING SLEEVE AND PULL PLUG/DH GAUGES. CLOSING THE SLEEVE WAS UNSUCCESSFUL. SL TAGGED FILL —2' BELOW THE SLEEVE. (-90' OF FILL TO THE PLUG). LEFT LOCATION 7:30PM. WS ARRIVED AT 9:OOPM TO RU FOR A CT FCO. HAD TO RELOCATE THE RO SKID —6' TO THE RIGHT OF THE WELLHOUSE TO ALLOW THE CTU FULL/CLEAR ACCESS TO THE WELLHOUSE. 2/1/19 PERFORATIONS - SLICKLINE ARRIVED ON LOCATION AT 07:15 AM TO CLOSE SLIDING SLEEVE AND PULL ELINE PLUG/DH GAUGES. CLOSING THE SLEEVE WAS UNSUCCESSFUL. TAGGED FILL —2' BELOW THE SLEEVE. (-90' OF FILL TO THE PLUG). SL LEFT LOCATION 7:30PM. 2/2/19 TEST -LOG -PROFILE -6 LEFT LOCATION AT 02:00AM. WS DAYSHIFT b,,.;K ON LOCATION 07:00 FINISHING CT RU. SLICKLINE CLOSED CMU SLIDING SLEEVE AND OBTAINED PASSING MIT -T. COIL TUBING ON LOCATION TESTING BOPE THEN MOVED TO WELL ONCE SLICKLINE DEPARTED LOCATION. CT RIGGING UP. CTU REPORTED THEY WERE HAVING ISSUES WITH THEIR ELECTRONICS / DATA ACQUISITION SYSTEM. ELECT TECH BEING SENT OUT FROM DEADHORSE SHOP TO TROUBLESHOOT 2/2/19 PERFORATIONS - ELINE SLICKLINE CLOSED CMU SLIDING SLEEVE AND OBTAINED PASSING MIT -T. 2/2/19 PERFORATIONS - COIL TUBING ON LOCATION TESTING BOPE THEN MOVED ON TO WELL ONCE SLICKLINE ELINE DEPARTED LOCATION. CT RIGGING UP. CTU REPORTED THEY WERE HAVING ISSUES WITH THEIR ELECTRONICS / DATA ACQUISITION SYSTEM. ELECT TECH BEING SENT OUT (f� o FROM DEADHORSE SHOP TO TROUBLESHOOT. 2/3/19 TEST -LOG -PROFILE CTU #4: RIH WITH JET NOZZLE. TAG FILL AT 14,105' CTMD. WASH TO 14,190' CTMD. HARD TAG. ATTEMPT TO WASH WITH SLICK DIESEL. MOBILIZED LRS. RU AND TEST LINES. PUMP 140 DEG HOT DIESEL AND ATTEMPT TO WASH THROUGH OBSTRUCTION @ 14,190' CTMD. NO SUCCESS. INITIAL T/1/0: 1463/1100/230 FINAL T/I/O: 100/1150/300 CT SUPERVISOR:TED SMITH 2/3/19 PERFORATIONS - CTU #4: RIH WITH JET NOZZLE. TAG FILL AT 14,105' CTMD. WASH TO 14,190' CTMD. HARD ELINE TAG. ATTEMPT TO WASH WITH SLICK DIESEL. MOBILIZED LRS. RU AND TEST LINES. PUMP 140 DEG HOT DIESEL AND ATTEMPT TO WASH THROUGH OBSTRUCTION @ 14,190' CTMD. NO SUCCESS. INITIAL T/I/O: 1463/1100/230 FINAL T/I/O: 100/1150/300 CT SUPERVISOR:TED SMITH 2/4/19 TEST -LOG -PROFILE CTU #4 = RIH WITH 3" G SPEAR. TAG PRONG AT 14,260' CTMD. JAR 5 TIMES. POOH WITH PRONG. RIH WITH 3" G SPEAR TO 14,268' CTMD. LATCH 2.81" PXN PLUG W/SPARTEK GAUGES. OBSERVE OVERPULL. POOH. RECOVER 2.81" PXN PLUG W/SPARTEK GAUGES. SWFN. INITIALT/I/O: 50/1137/216 FINAL T/1/0: 344/1132/211 CT SUPERVISOR: TED SMITH 2/4/19 PERFORATIONS - ELINE CTU #4 = RIH WITH 3" G SPEAR. TAG PRONG AT 14,260' CTMD. JAR 5 TIMES. POOH WITH PRONG. RIH WITH 3" G SPEAR TO 14,268' CTMD. LATCH 2.81" PXN PLUG W/SPARTEK GAUGES. OBSERVE OVERPULL. POOH. RECOVER 2.81" PXN PLUG W/SPARTEK GAUGES. SWFN. INITIAL T/I/O: 50/1137/216 FINAL T/1/0: 344/1132/211 CT SUPERVISOR: TED SMITH 2/5/19 TEST -LOG -PROFILE CTU #4 = RIH WITH 42BO SHIFTING TOOL. RUN IN TO 14,260' CTMD; NO INDICATION OF SHIFTING TOOL LOCATING IN SLIDING SLEEVE. GOOD SIGN OF SLEEVE REMAINING IN CLOSED POSITION. POOH NO EXTRA WEIGHT/DRAG OBSERVED. RDMO SVS TECH'S DID STATE TEST ON TREE SSV. VALVE CREW SERVICE WELL HEAD VALVES AND RO SKID VALVES. PTS RE -RIG FB HARDLINE TO WELLAND REVERSE OUT SKID. PTS PT'D FB HARDLINE AND RO SKID W/DIESEL TO 4000 PSI - PASSED PTS PUMPED 5 BBLS METH IN IA PRIOR TO WELL RE -POP. PREP TO RE -POP WELL FOR ZONE 1 FB/CLEAN-UP (BERMUDA). 2/5/19 PERFORATIONS - CTU #4 = RIH WITH 42BO SHIFTING TOOL. RIH TO 14,260' CTMD. NO INDICATION OF ELINE SHIFTING TOOL LOCATING IN SLIDING SLEEVE. POOH NO EXTRA WEIGHT/DRAG OBSERVED. POOH. JET 1.75" CT REEL WITH N2. RDMO. INITIAL WHP/IA/OA: 349/1122/183 FINAL WHP/IA/OA: 334/1115/208 SUPERVISOR: TED SMITH 2/6/19 TEST -LOG -PROFILE PER STEP 2 OF PROCEDURE PRIOR TO POP; TOOK 2 EACH 1 L SAMPLES OF: HARDLINE FP FLUID, WATER OFF THE BOTTOM OF THE TEST SEP VESSEL, FB TANK (TANK FARM) 1 RE -POP WELLAT 12:15am. (NOTIFIED CPF-2 BOARD OPERATOR AND 2S DSO) SALINITY DROPPED TO THE LOW/MID 18000. PTS COLLECTED THE WATER SAMPLES. DELIVERED TO THE KUP LAB. FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS, TOTAL RETURNS SINCE POP IS 714 BBLS. (ZONE 1 / BERMUDA) 2/7/19 TEST -LOG -PROFILE vvAS FLOWING WELL PER PROCEDURE. SHIPPING ALL FLUID RETURNS TO TANKS. TOTAL RETURNS SINCE POP WAS 1400 BBLS. (ZONE 1 /BERMUDA) UP UNTIL 6:30PM WELL STARTING PRODUCING FRAC/FORMATION SAND—2:OOAM. CUT CHOKE BACK FROM 42 TO 38 BEANS AT 7:OOAM EXPRO COLLECTED THE PRESSURIZED OIL/GAS SAMPLES, AND THE 4 - 5 GAL CANS OF OIL SI WELL AT 6:30PM DUE TO THE SAND DUMP LINE TO THE SPARGE TANK PLUGGED. HAD LRS PUMP AGAINST IT TO TRY TO CLEAR, NO LUCK. PTS DISCOVERED —140' OF THE LINE PLUGGED. PTS WORKING ON THE PLUGGED SECTION. DUE TO THE PLUGGED LINE, AND THE PLAN FORWARD PER TYSON, FP'D THE TBG WITH 30 BBLS DIESEL, AND THE SURFACE PIPING WITH 19 BBLS DIESEL, WHICH INCLUDES THE PROD FLOWLINE. 2/8/19 TEST -LOG -PROFILE PTS DISCONNECTED THE PLUGGED SECTION OF SAND DUMP LINE (-140') AND REPLACED WITH EXTRA PIPE IN ORDER TO GET THE LINE BACK IN SERVICE. HES SLICKLINE ARRIVED ON LOCATION TO SHIFT SLEEVE. TAGGED FILL 2000' ABOVE SLEEVE. GAUGED TBG TO 2.79" TO X -NIP @ 13920' RKB. IN PROGRESS. PHASE II WEATHER CONDITIONS DECLARED AT 8:OOPM. SECURED LOCATION AND CONVOYED BACK TO CAMP. 2/8/19 PERFORATIONS - HES SLICKLINE UNIT 765: ATTEMPT TO SHIFT SLIDING SLEEVE & ENCOUNTER DEBRIS IN ELINE TBG @ 12110' RKB; GAUGED TBG TO 2.79" TO X -NIP @ 13920' RKB. IN PROGRESS. INITIAL T/IA/OA = 1000/1280/0 FINAL T/IA/OA = 2400/1280/0 WELLS SUPERVISOR: ZEMBA 2/9/19 TEST -LOG -PROFILE PHASE II WEATHER CONDITIONS DECLARED. LOCATION SECURED, PTS NIGHT CREW AT CAMP (12-6) HES SLICKLINE UNIT 765: ATTEMPT TO BAIL FRAC SAND W/ 2.5" & 2" BAILERS FROM 14042' RKB BUT UNABLE TO MAKE HOLE. HANDOVER TO COIL FOR FCO. INITIAL T/IA/OA = 1000/1280/0 FINAL T/IA/OA = 1500/1280/0 WELLS SUPERVISOR: ZEMBA WS RU FB TANKS/HARDLINE FOR CT FCO. PTS PT'D SAND DUMP LINE THAT WAS REPLACED. 2/9/19 PERFORATIONS - HES SLICKLINE UNIT 765: ATTEMPT TO BAIL FRAC SAND W/ 2.5" & 2" BAILERS FROM ELINE 14042' RKB BUT UNABLE TO MAKE HOLE. HANDOVER TO COIL FOR FCO. INITIAL T/IA/OA = 1000/1280/0 F I NAL T/IA/OA = 1500/1280/0 WELLS SUPERVISOR: ZEMBA 2/10/19 TEST -LOG -PROFILE CTU #14: RIH w/ 1.75" OD Down Jet Nozzle. Tag at 14,371' CTMD. Attempt to wash deeper. Sweep Gel Pills around. POOH with 1.75" OD Down Jet Nozzle. SWFN. Initial WHP/IA/OA: 1337/1294/214 Final WHP/IA/OA: 167/1321/293 WELLS SUPERVISOR: TED SMITH WORKING THE FB PROCEDURE (NEXT PHASE, FLOW TO PROD) WITH OPS PROD ENG. PTS/LRS FLUSHED SAND HOG / MANIFOLD WITH DIESELTO CLEAN OUT THE REMAINING SAND IN PREP FOR THE NEXT FB PHASE TO PRODUCTION THE NIGHT DSO (BEN) REQUESTED WE HOLD OFF ON N2 SWEEPING THE SURFACE LINES UNTIL THE JOB OF RE -RIGGING FROM THE PROD FLOWLINE TO THE TEST HEADER IS NEARLY READY TO EXECUTE. HAS CONCERNS OF LEAKAGE BACK INTO THE FLOWLINE AND FREEZING. 2/10/19 PERFORATIONS - CTU #14: RIH w/ 1.75" OD Down Jet Nozzle. Tag at 14,371' CTMD. Attempt to wash deeper ELINE Sweep Gel Pills around. POOH with 1.75" OD Down Jet Nozzle. SWFN. Initial WHP/IA/OA: 1337/1294/214 Final WHP/IA/OA: 167/1321/293 WELLS SUPERVISOR: TED SMITH 2/11/19 TEST -LOG -PROFILE , HASE CONDITIONS APPROACHING, EVACUATE �JCATION AT 02:30AM (TURNED TO PHASE 3) CTU #14 ARRIVE ON LOCATION RIH TO SHIFT SLEEVE. RIH with 42BO Shifting Tool. RIH to 14,220' CTMD. PU and engage sliding sleeve with 42BO Shifting Tool. Pick up to 14,140' CTMD and observe 6K overpull to indicate sliding sleeve opened. No pressure change observed on well head pressure. POOH. RDMO. Initial WHP/IA/OA: 247/1295/252 Final WHP/IA/OA: 234/1293/242 WELLS SUPERVISOR: TED SMITH DSM ON LOCATION TO UNBLIND THE TEST LINE ON 2S-315 (COMPLETE) PTS / HES N2 DID BLOWDOWN ON THE SURFACE PIPING IN PREP TO RE -RIG THE FB HARDLINE FROM THE PROD FLOWLINE TO THE TEST LINE. 2/11/19 PERFORATIONS - CTU #14 ARRIVE ON LOCATION RIH TO SHIFT SLEEVE. RIH with 42BO Shifting Tool. RIH to ELINE 14,220' CTMD. PU and engage sliding sleeve with 42BO Shifting Tool. Pick up to 14,140' CTMD and observe 6K overpull to indicate sliding sleeve opened. No pressure change observed on well head pressure. POOH. RDMO. Initial WHP/IA/OA: 247/1295/252 Final WHP/IA/OA: 234/1293/242 WELLS SUPERVISOR: TED SMITH 2/12/19 TEST -LOG -PROFILE PTS COMPLETED THE RE -RIG OF THE FB HARDLINE FROM THE PROD FLOWLINE TO THE TEST LINE, PTS / OPS DID THE WALKDOWN TO CONFIRM THE RU WAS CORRECT PTS / HES N2 / LRS DID THE PT ON THE FB HARDLINE (LOW PT WITH N2, HIGH PT WITH DIESEL) LRS FP'D THE PROD FLOWLINE FOR OPS, AND PUMPED 5 BBLS METH IN THE IA IN PREP FOR POP. OPS FAC ENG WALKED DOWN THE JOB, COMPLETED THE MOC. DUE TO THE WEATHER FORECAST OF PHASE CONDITIONS TONIGHT, HOLDING OFF ON POP UNTIL TOMORROW MORNING (2/13 A.M.) 2/13/19 TEST -LOG -PROFILE PTS POP'D WELL AT 11:15AM. TAKING FLUIDS TO TANKS, GAS RETURNING THROUGH THE TEST LINE. PTS MONITORING WELL FOR SOLIDS. 2/14/19 TEST -LOG -PROFILE PTS SEEN A LITTLE SOLIDS PRODUCTION, BACKED CHOKE DOWN A LITTLE. SUBSIDED. WORKED CHOKE BACK UP SLOWLY. EXPRO COLLECTED THE REQUESTED SAMPLES AT 02:OOAM. ONCE SOLIDS CRITERIA WAS MET, PTS DIVERTED PROD FLUIDS FROM TANKS TO THE TEST LINE / MPM AT 5:OOAM WHEN FLOW WAS DIVERTED, THEY BACKED OUT HES N2 AND STARTED MI GAS LIFT. RELEASED HES N2 AT 05:30AM TO RDMO. MI GAS LIFT ORIFICE PLATE TOO BIG, G/L RATE WILL NOT HOLD STEADY UNLESS OVER 1.0 MMSCFD. CPF-2 PROD ENG ADVISED TO INCREASE G/L RATE TO 1.25 MMSCFD. THEN ADVISED TO INCREASE TO 2.0 MMSCFD. 2/15/19 TEST -LOG -PROFILE CONTINUED TO FLOW WELL TO TEST LINE / MPM. MONITOR FOR SOLIDS. SI WELL AT 10:15AM AND HAD LRS FP TBG W/30 BBLS METH. (A SMALL HYDRATE PLUG HAD STARTING FORMING IN THE TBG. THE METH CUT THROUGH IT) HES N2 BLOWDOWN ALL SURFACE LINES. PTS / DTH BEGAN RD OF THE TEST SPREAD. STARTED RELEASING TANKS, EQUIPMENT THATS READY TO BE PICKED UP / HAULED AWAY. 2/16/19 TEST -LOG -PROFILE PTS / DTH CONTINUES RD OF THE TEST SPREAD. 2/17/19 TEST -LOG -PROFILE PTS / DTH FINISHED RD OF THE TEST SPREAD DTH, WELL SUPPORT, ETC WILL CONTINUE HAULING EQUIPMENT OFF PAD. DTH LOADER SCRATCHED THE TEST SPREAD AREA TO CLEAN UP / LEVEL THE AREA. REALEASED THE ENVIROVAC ON THE WEST END OF THE PAD Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: Job End Date: State: County: API Number: Operator Name: Well Name and Number: Latitude: Longitude: Datum: Federal Well: Indian Well: True Vertical Depth: Total Base Water Volume (gal): Total Base Non Water Volume: 1/2/2019 1/2/2019 Alaska Harrison Bay 50-103-20776-00-00 ConocoPhillips Company/Burlington Resources 2S-315 70.21949800 -150.15672700 NAD83 NO NO 6,008 209,276 Hydraulic Fracturing Fluid Composition: Rac Disclosure Registry ptoo c1toN COUNCII. 7 Oil&Gas Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS #) (% by mass)** (% by mass)** Sea Water Operator BASE FLUID Water 7732-18-5 79.86140 Density=8.540 SP BREAKER Halliburton Breaker Listed Below MO-67 Halliburton pH Control Additive Listed Below Wanli 20/40 Halliburton Additive Ceramic Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below OPTIFLO-III Halliburton Breaker DELAYED RELEASE BREAKER Listed Below CL-22 UC Halliburton Crosslinker Listed Below SAND-COMMON Halliburton Proppant WHITE-100 MESH SSA-2, BULK (100003676) Listed Below CL-31 Halliburton Crosslinker CROSSLINKER Listed Below OPTIFLO-ll Halliburton Breaker DELAYED RELEASE BREAKER Listed Below BE -6 MICROBIOCIDE Halliburton Biocide Listed Below WG -36 GELLING AGENT Halliburton Gelling Agent Listed Below items above are I racle Rarries wrfn tne exception of 6ase Water Items below are Me individual Corundum ingredients. 1302-74-5 55.00000 7.61955 Mullite 1302-93-8 45.00000 6.23418 Sodium chloride 7647-14-5 4.00000 3.32899 Hydrotreated Distillite, Light 64742-47-8 100.00000 2.40343 Guar gum 9000-30-0 100,00000 0.19722 WATER 7732-18-5 100.00000 0.10166 Crystalline silica, quartz 14808-60-7 100.00000 0.07574 Borate salts Proprietary 60.00000 0.05874 Potassium formate 590-29-4 60.00000 0.05874 Ethanol 64-17-5 60.00000 0.04536 Potassium metaborate 13709-94-9 60.00000 0.02681 Heavy aromatic petroleum naphtha 64742-94-5 30.00000 0.02268 Ammonium persulfate 7727-54-0 100.00000 0.02095 Sodium hydroxide 1310-73-2 30.00000 0.01364 Cured acrylic resin Proprietary 30.00000 0.00628 Oxylated phenolic resin Proprietary 5.00000 0.00378 Naphthalene 91-20-3 5.00000 0.00378 Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)- omega-hydroxy-, branched 127087-87-0 5.00000 0.00378 Potassium hydroxide 1310-58-3 5.00000 0.00223 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on the maximum potential for concentration and thus the total may be over 100% If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) 2-Bromo-2-nitro-1,3- 52-51-7 100.00000 0.00130 propanediol Sodium glycollate 2836-32-0 1.00000 0.00098 Acrylate polymer Proprietary 1.00000 0.00098 Denise Tuck; Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226 Sodium carboxymethyl 9004-32-4 1.00000 0.00098 cellulose Sodium persulfate 7775-27-1 100.00000 0.00093 1,2,4 Trimethylbenzene 95-63-6 1.00000 1 0.00076 Sodium sulfate 7757-82-6 0.10000 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on the maximum potential for concentration and thus the total may be over 100% If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) Operations Summary (Detailed) Yp. 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 12/8/2018 12/8/2018 1.50 TRAV DEPART KOC AND DRIVE TO 2S- 0.0 0.0 22:00 23:30 315. 12/8/2018 12/9/2018 0.50 RURD SAFETY MEETING. COMPANY 0.0 0.0 23:30 00:00 MAN DECIDED TO CANCEL JB RUN AND PROCEED WITH CBL LOG. 12/9/2018 12/9/2018 2.50 RURD CONTINUED SAFETY MEETING. 0.0 0.0 00:00 02:30 COMPANY MAN DECIDED TO CANCEL JB RUN AND PROCEED WITH CBL LOG. 12/9/2018 12/9/2018 2.50 RURD SPOT EQUIPMENT, REHEAD, 0.0 0.0 02:30 05:00 MAKE UP CBL TOOL AND PERFORM SURFACE CHECKS. 12/9/2018 12/9/2018 1.50 ELNE RIH WITH CBL/WELTEC TRACTOR. 0.0 0.0 05:00 06:30 OAL= 56'. OD=6.20". OAW=900LBS. TAGGED 14,448'. RIH TO POINT OF REFUSAL AT 3,300'. 12/9/2018 12/9/2018 4.25 ELNE TRACTOR DOWN FROM 3,300' TO 0.0 0.0 06:30 10:45 TD AT 14,448'. 12/9/2018 12/9/2018 5.00 ELNE PEROFRM REPEAT PASS FROM 0.0 0.0 10:45 15:45 TD -14,093'. PERFORM MAIN PASS FROM TD -10,476'. POOH. 12/9/2018 12/9/2018 1.50 RURD RIG DOWN DSLT. 0.0 0.0 15:45 17:15 12/9/2018 12/9/2018 4.00 WORG WAIT FOR RIG TO TEST RAMS 0.0 0.0 17:15 21:15 AND MOVE PIPE. PERFORM SURFACE CHECKS FOR PERF AND RIG UP. 12/9/2018 12/9/2018 1.50 ELNE RIH WITH 30' GUN TO 3,300'. 0.0 0.0 21:15 22:45 12/9/2018 12/10/2018 1.25 ELNE BEGIN TRACTOR TO TD. 0.0 0.0 22:45 00:00 12/10/2018 12/10/2018 6.00 ELNE CONINUE IN HOLE TO 4250' RKB, 0.0 0.0 00:00 06:00 BEGIN TRACTORING TO TD AT 60 FPM. 12/10/2018 12/10/2018 1.00 ELNE CORRELATE AND TIE IN GUN. 0.0 0.0 06:00 07:00 12/10/2018 12/10/2018 3.00 ELNE REQUESTED PERF 0.0 0.0 07:00 10:00 INTERVAL: 14,173'-14,203'. CCL TO TOP SHOT: 12.9'. CCL STOP DEPTH: 14,160.1'. GUN FIRED WITH GOOD INDICATION. POOH. 12/10/2018 12/10/2018 1.75 RURD RIG DOWN. 0.0 0.0 10:00 11:45 12/10/2018 12110/2018 0.50 TRAV DEPART 2S-315 AND DRIVE TO 0.0 0.0 11:45 12:15 KOC. 12/11/2018 12/11/2018 1.00 TRAV RECEIVED CALL OUT. DRIVE TO 0.0 0.0 15:00 16:00 2S-315. 12/11/2018 12111/2018 2.00 RURD SAFETY MEETING. RIG UP. 0.0 0.0 16:00 18:00 12/11/2018 12/11/2018 1.00 ELNE RIH WITH TRACTOR/UPCT FOR 0.0 0.0 18:00 19:00 CORRELATION LOG IN 3.5" TUBING. RAN IN TO POINT OF REFUSAL AT 2,400'. 12/11/2018 12/12/2018 5.00 ELNE BEGAIN TRACTORING FROM 0.0 0.0 19:00 00:00 2,400' TO LOWER PACKER AT 14,264'. MAX SPEED OF TRACTOR WAS 15 FT/MIN. 12/12/2018 12/12/2018 8.00 ELNE CONTINUE WITH TRACTORING 0.0 0.0 00:00 08:00 DOWN TO LOWER PACKER AT 14,264'. MAX SPEED OF TRACTOR IS 15 FT/MIN. Page 1/30 Report Printed: 3/11/2019 Operations Summa :.< p Summary (Detailed) 2S-315 Rig: PTS Job: TEST-LOG-PROFILE Time Log Start Time 12/12/2018 End Time 12/12/2018 Dur (hr) 3.00 Phase Op Code Activity Code Operation P Start depth (ft0. End Depth (ft Depth Progress (ft) 08:00 11:00 ELNE LOGGED FROM LOWER PACKER 0.0 0. 0.0 AT 14,264' TO RA TAG AT 13,425'. POOH. 12/12/2018 12/12/2018 1.00 RURD RIG DOWN. 0.0 0.0 11:00 12:00 12/12/2018 12/12/2018 1.00 TRAV DEPART 2S-315 AND DRIVE TO 0.p 0 0 12:00 13:00 KOC. 12/17/2018 12/17/2018 1.50 DEMOB TRAV TRVL TO CWG, PU FILE, GRAB 0.0 0.0 06:00 07:30 TOOLS @ W/L SHOP, ONTO LOCATION, CONTACT DSO 12/17/2018 07:30 12/17/2018 1.75 RURD ARRIVE/INSPECT, CHECK TREE 0 0 0.0 09:15 VALVES, (OA GATE HANDLE UNACCESSABLE DUE TO GRATING, IA FLANGE OUTSIDE FO GATE VLV NOT EVEN TIGHT, HANDY, CLOSE & FLAG, CALL WELLS SUPPORT), MIRU .125" WIRE, 2.125" RLR TS = 8', KJ, 6', KJ, 5', KJ, 6', KJ, 5', OJ, KJ, LSS (OAL 51'), MU 8 SECTIONS, (ALL NEW PINS & CONNECTIONS CHECKED), INSTALL FUSIBLE, (START TICKET @ 0900). 12/17!2018 09.15 12/17J201$ 2.50 SLKL PT W/LRS TO 2500, RIH W/ KJ, 3' x 0.0 0.0 11:45 2.125" LR, 2 75" CENT, 7" EXT, X- EQ PRONG (2 x 2.6" TTL PINS @ 10.25" & 13.25" FROM BTM EQ DEVICE), DRIFT FREELY 200 FPM, PU WEIGHT @ 13000' SLM - 800# @ 200 FPM, OUT OF THE SAIL GET PU WEIGHT @ 13600' SLM = 1000# @ 50 FPM, CRIH TO SD @ 14295' SLM, AGAIN PU WEIGHT IS AROUND 1100#, JAR DWN 3 TIMES, POOH, HEAVY 1100 - 1200# UNTILLAROUND 13400' SLM, OOH TTL PINS SHEARED & GOOD MARKS ON EQ PRONG, DROP 5' OF RLR. 12/17/2018 11:45 12/17/2018 2.75 SLKL PT W/ LRS TO 2500, RIH W/ 3.5" 0.0 0.0 14:30 GR, DRIFT FREELY TO SD @ 14292' SLM, HIT 2 OJ LICKS & COME FREE W/ DFCV, POOH, SLOW CATCHING COLLARS & SWABBING IF GET GOING TOO FAST, OOH W! DFCV, DROP OSS & ADD 5' RLR, HARDLINE ON LOC TO FIX IA, 12/17/2018 12/17/2018 14:30 2.50 SLKL PT W/ LRS TO 2500, RIH W/ 3" GS 0.0 0.0 17:00 (3/16" BRASS) & 2.81" XN-CSV (OAL 46" / 2.77" NOLO), BOBBLE THRU X-NIP & CMU, SD @ 14295' SLM, JAR DWN 5 TIMES, BOL LRS TO PRESSURE UP TBG100-1000, IA CLIMBS TO 100-1000, LOOKS GOOD POOH, OOH W/ SHEARED GS, DROP DOWN TO 13'x 2.125" RLR. 12/17/2018 12/17/2018 0.50 SLKL O-RING LEAK DURING PTA BOVE 0.0 0.0 17:00 17:30 WLV'S, SET ON GROUND & C/O, REPEAT O-RING LEAK BUT BELOW WLV'S, C/O O-RING. Page 2/30 RPnnrf Prinfnri• 'Imii n4-a j Operations Summary (Detailed) r x 2S-315 r r ♦' r Rig: PTS Job: TEST-LOG-PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 12/17/2018 12/17/2018 0.75 SLKL PT W/ LRS TO 2500, RIH W/ 3" GS 0.0 0.0 17:30 18:15 (3/16" BRASS) & 2.79" COLLAR STOP CATCHER (OAL 66"), SET @ 3003' SLM, JAR DWN 5 TIMES, POOH, OOH W/ SHEARED GS. 12/17/2018 12/17/2018 0.75 SLKL PT W/ LRS TO 2500, RIH W/ KJ, 0.0 0.0 18:15 19:00 3.5" OM-1 & 7" EXT W/ 1.625" JDC TO ST#1 @ 2919' RKB, LCT & SD @ 2896' SLM, TAP DWN FIVE TIMES, LATCHED, HIT 4 OJ LICKS & COME FREE, POOH, OOH W/ SOV. 12/17/2018 12/17/2018 1.25 SLKL PT W/ LRS TO 2500, RIH W/ KJ, 0.0 0.0 19:00 20:15 3.5" OM-1 & RK RT W/ 1.5" DMY ON RK TO ST#1, LCT & SD @ 2896 SLIM, SET VLV, SEE TRVL, BLEED IA DOWN 800 - 0, (CHANGE OUT FROZEN GAUGE), TBG COMES DOWN 800-650, SHEAR OFF, PRESSURES REMAIN THE SAME, POOH, OOH TOOL INDICATES GOOD SET, (END TICKET @ 2000). 12/17/2018 12/17/2018 0.50 RURD LDFN, FUSIBLE REMOVED, TREE 0.0 0.0 20:15 20:45 CAP SECURE, PJSM, CONTACT DSO, LEAVE LRS TO PERFORM MIT'S. 12/17/2018 12117/2018 0.75 TRAY TRVL TO CWG, TURN IN FILE & 0.0 0.0 20:45 21:30 PAPERWORK, TRVL TO CAMP. 12/18/2018 12118/2018 1.50 TRAV TRVL TO CWG, PU FILE, ONTO 0.0 0.0 06:00 07:30 LOC, CONTACT DSO. 12118/2018 12/18/2018 1.00 RURD ARRIVE / INSPECT, PJSM, JSA, 0.0 0.0 07:30 08:30 LRS PERFORMING MITIA, RU 8 SECTIONS, .125" WIRE, 2.125" RLR TS = 8',KJ,5',OJ,KJ,LSS (CAL 29'), INSTALL FUSIBLE, (START TICKET @ 0800). 12/18/2018 12118/2018 0.50 SLKL PT W/ LRS TO 2500, RIH W/ 3.5" 0.0 0.0 08:30 09:00 GR, SD @ 3003' SLM, LATCH CATCHER, POOH, OOH W/ EMPTY CATCHER, SWAP BACK TO LONG TS = 8',KJ,6',KJ,5',KJ,6',OJ,KJ,LSS (OAL 44.5'). 12/18/2018 12/18/2018 2.50 SLKL PT W/ LRS TO 2500, RIH W/ 3.5" 0.0 0.0 09:00 11:30 GR, SD @ 14286' SLM, LATCHED, T/IA= 700/125, HIT 3 OJ LICKS & COME FREE, TBG/IA600/125, PUH THRU CMU LIGHT OVERPULL & PRESSURES REMAIN THE SAME, POOH, OOH 2/ EMPTY CSV. 12/18/2018 12/18/2018 1.00 SLKL PT W/ LRS TO 2500, HANG IN 0.0 0.0 11:30 12:30 LUBE W/ 20'X 2.69" DMY PERF GUN DRIFT, BLEED TBG BACK 500 - 0, RD LRS & RU TO IA FOR MIT-IA TO 3000, T/IA/OA PRE MIT PSI = 150/20/275, INITIAL MIT PSI 800/3860/380, 15 MIN. PSI 800/3800/380, 30 MIN. PSI 800/3790/380 (PASS) 12/18/2018 12/18/2018 3.50 SLKL RIH W/ 20'X 2.69' DMY. PERF. 0.0 0.0 12:30 16:00 DRIFT, CLEAN DRIFT TO 14,350' SLM, POOH (1600 END TICKET) Page 3130 Report Printed: 3/11/2019 - Operations Summary (Detailed) p S 1 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 12/18/2018 12/1812018 2.00 RURD RIG OFF THE WELL HEAD AND 0.0 0.0 16:00 18:00 RIG LRS UP TO MIT -T, T/IA/OA PRE MIT PSI 0/150/250, INITIAL 3020/260/260, 15 MIN. PSI 2975/260/260, 30 MIN PSI 2960/260/260 (PASS) RIGGED DOWN, MOVE OVER TO 2A PAD 12/21/2018 12/21/2018 1.50 TRAV TRAVEL TO KIC, GET EQUIPMENT. 0.0 0.0 06:30 08:00 MOVE TO 2S-315 12/21/2018 12/21/2018 1.00 RURD ARRIVE ON LOCATION. SPOT 0.0 0.0 08:00 09:00 EQUIPMENT START RIGGING UP. 12/21/2018 12/21/2018 3.00 RURD CRANE ARRIVED ON LOCATION. 0.0 0.0 09:00 12:00 PJSM, CONTINUE RIGGING UP, PLACE WLV'S ON TREE, STACK PCE. PERFORM SLB SHOOTING CHECKS TO CONFIRM SWITCGHES AND TRACTOR SAFETY SWITCH ARE WORKING CORRECTLY. 12/21/2018 12/21/2018 2.00 RURD LAY DOWN RISER FOR WELTEC 0.0 0.0 12:00 14:00 SURFACE CHECKS. 12/21/2018 12/21/2018 1.00 RURD TRACTOR RUNNING CHECKS 0.0 0.0 14:00 15:00 COMPLETE, STACK REST OF PCE AND PRESSURE TEST. 12/21/2018 12/21/2018 2.00 RURD HOTCHECKANDARM. UNABLE 0.0 0.0 15:00 17:00 TO READ SWITCHES. TROUBLESHOOT. SAFETY SUB IN STRING NOT ALLWOING NEGATIVE VOLTAGE TO PASS THROUGH UNTIL IT VOLTAGE REACHES 90V. 60 V IS REQUIRED TO READ SWITCHES. DIFFERENT SAFETY SUB GETTING HOT SHOT OUT. 12/21/2018 12/21/2018 1.00 RURD NO NIGHT RELIEF FOR CRANE 0.0 0.0 17:00 18:00 OPERATOR, DECISION MADE TO LDFN AND RELEASE CRANE OPERATOR, LAY DOWN RISER AND SECURE WELL. 12/21/2018 12/21/2018 1.00 RURD SWAP TO DIFFERENT 0.0 0.0 18:00 19:00 TOOLSTRING CONFIGURATION TO SEE IF SWITCHES CAN BE READ BELOW TRACTOR. ABLE TO READ SWITCHES AND FIRE THROUGHT. 12/21/2018 12/21/2018 0.00 TRAV TRAVEL BACK TO F -WING 0.0 0.0 19:00 19:00 12/22/2018 12/22/2018 1.00 TRAV TRAVEL TO 2S-315 0.0 0.0 05:00 06:00 12/22/2018 12/22/2018 2.50 RURD ARRIVE AT LOCATION, PERFORM 0.0 0.0 06:00 08:30 TRACTOR CHECKS AND RIG UP. 12/22/2018 12/22/2018 1.00 RURD NEW SAFE SUB AND TRACTOR 0.0 0.0 08:30 09:30 PERF CHECKS CHECK OUT GOOD THROUGH TRACTOR. STACK REST OF RISER / WLV. STAND ONTO TREE. 12/22/2018 12/22/2018 1.00 RURD PRESSURE TEST, UNSTAB, HOT 0.0 0.0 09:30 10:30 CHECK AND ARM. Page 4/30 Report Printed: 3/11/2019 Operations Summary (Detailed) � � x Y 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 12/22/2018 12/22/2018 5.50 ELNE SWAB OPEN, RIH W/ HEAD / 0.0 0.0 10:30 16:00 WELLTEC SWIVEL, WRD, TRACTOR, SAFE SUB, SHOCK SUB / UPCT / ATPS / 30' LOADED 2506 HYPERJET. DEVIATE OUTAT 3000', BEGIN TRACTORING DOWN -35 FPM. 12/22/2018 12/22/2018 3.00 ELNE ABLE TO FREE FALL AT 13500' 0.0 0.0 16:00 19:00 CONTINUE RIGH W/O TRACTOR. PERFORATE INTERVAL 14315- 14345', CCL TO TOP SHOT = 6.0 FT, CCL STOP DEPTH = 14309', LOG CORRELATED TO SLB CBL DATED 09 -DEC -2018. TD TAGGED AT 14417' POOH. 12/22/2018 12/22/2018 2.00 RURD SWAB CLOSED, RIG DOWN. 0.0 0.0 19:00 21:00 12/22/2018 12/22/2018 1.00 TRAV TRAVEL TO F -WING 0.0 0.0 21:00 22:00 12/31/2018 12/31/2018 12.00 RURD MOVE IN/RIG UP TREE SAVER, 0.0 0.0 06:00 18:00 FRAC PACKAGE AND TANKS. 1/2/2019 1/2/2019 7.75 RURD RIG UP FRAC EQUIP 0.0 0.0 06:00 13:45 1/2/2019 1/2/2019 0.34 PUMP LRS RIGGED UP IAAND 0.0 0.0 13:45 14:05 PRESSURE TESTED 1/2/2019 1/2/2019 0.59 PUMP PRESSURE TEST TO 6091 PSI 0.0 0.0 14:05 14:40 1/2/2019 112/2019 0.16 PUMP OPEN WELL, BHP START. 2411 0.0 0.0 14:40 14:50 PSI, BHT START: 140F, PUMP DFIT FROM TANK 7 @ 83F, 9 TANKS ON LOCATION, 5 FRAC PUMPS. USABLE WATER ON LOCATION: 3504 BBLS WITH 80 BBL BOTTOMS. LVT USABLE ON LOCATION: 275 BBLS 112/2019 1/2/2019 0.08 PUMP LRS BUMP UP IA TO 2000 PSI 0.0 0.0 14:50 14:55 1/2/2019 1/2/2019 0.25 PUMP CAME ONLINE, DETERMINED 0.0 0.0 14:55 15:10 STINGER WAS DRESSED FOR 3- 1/2" TUBING INSTEAD OF 4-1/2". ISOLATED STINGER, WILL REDRESS POST DFIT. 1/2/2019 1/2/2019 0.04 PUMP OPEN WELL. RAMP UP TO 8 BPM 0.0 0.0 15:10 15:12 1/2/2019 1/2/2019 0.45 PUMP BREAKDOWN PRESSURE: 1692 0.0 0.0 15:12 15:39 PSI SITP, 4128 PSI BHP 1/2/2019 1/2/2019 0.09 PUMP -235 BBLS SEAWATER PUMPED - 0.0 0.0 15:39 15:45 8 BPM, 2719 PSI SITP, 3789 PSI BHP, 106F BHT. GETTING READY TO FREEZE PROTECT IN 10 BBLS. 1/2/2019 1/2/2019 0.50 PUMP SHUT DOWN. ISIP: 3461 PSI BHP, 0.0 0.0 15:45 16:15 1145 PSI SITP, 5 MIN: 3376 PSI BHP, 1099 PSI SITP, BHT. 103.517 1/2/2019 1/2/2019 5.75 PUMP RD FRAC EQUIPMENT 0.0 0.0 16:15 22:00 1/3/2019 1/3/2019 7.34 RURD RU Frac Equip 0.0 0.0 07:00 14:20 1/3/2019 1/3/2019 0.66 PUMP Pre -Job Safety Meeting 0.0 0.0 14:20 15:00 1/3/2019 1/3/2019 0.17 LRS getting hard line rigged up to IA 0.0 0.0 15:00 15:10 1/3/2019 1/3/2019 0.17 Prime up pumps 0.0 0.0 15:10 15:20 Page 5130 Report Printed: 3/11/2019 Operations Summary (Detailed) 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (MB) (ft) 1/3/2019 1/3/2019 0.66 Start mixing gel 0.0 0.0 15:20 16:00 1/3/2019 1/3/2019 0.25 ADP tub level valve feedback cable 0.0 0.0 16:00 16:15 not working, currently replacing it so it can read tub levels. 1/3/2019 1/3/2019 1.09 Pressure testing hard lines to 7245 0.0 0.0 16:15 17:20 psi 1/3/2019 1/3/2019 0.58 Test N2 PRV. Popped at 6737 psi 1st 0.0 0.0 17:20 17:55 try. Popped 6851 psi after re- attempting 2nd try. Pump kickouts: 6000, 6200, 6225 psi 1/3/2019 1/3/2019 0.68 Open well, start pumping mini-frac 0.0 0.0 17:55 18:36 300 bbls 1/3/2019 1/3/2019 0.50 Shut -down to analyze mini-frac. 0.0 0.0 18:36 19:06 ISIP: 3534psi BHP, 1010 psi STP Closure: 3410 psi BHP 1/3/2019 1/3/2019 1.40 Start main-frac, ramp up to 20BPM, 0.0 0.0 19:06 20:30 pump 15405 100 mesh. 1/3/2019 1/3/2019 0.50 C' Shut -down main-frac. J�j'fc�c� 0.0 0.0 20:30 21:00 �14 1/3/2019 1/3/2019 2.00 RD Frac Equip 0.0 0.0 21:00 23:00 1/4/2019 1/4/2019 1.50 TRAV PU CPU / FILE, PU TOOLS @ 0.0 0.0 06:00 07:30 WIRELINE SHOP, TRAVEL TO LOCATION. 1/412019 1/4/2019 2.00 RURD INSPECT LOCATION, CALL FOR 0.0 0.0 07:30 09:30 LOADER TO MOVE SOME FRAC EQUIPMENT. STAND BY. 1/4/2019 1/4/2019 0.75 WOOV LOADER ARRIVED, MOVED SOME 0.0 0.0 09:30 10:15 FRAC EQUIPMENT. 1/4/2019 1/4/2019 2.00 RURD SPOT UNIT, TGSM, RU .125 WIRE 0.0 0.0 10:15 12:15 & 2.125" RLR TS= RS,8,KJ,5,KJ,5,OJ,KJ,LSS. OAL = 33.5'. (TICKET START @ 0900) 1/4/2019 1/4/2019 3.25 SLKL PT W/ LRS (2500) RIH W/ 3' WB, 0.0 0.0 12:15 15:30 2.69" CENT & 1.75" S-BLR (OAL=82") TAGGED @ 14346' SLM, POOH W/ FRAC SAND IN BLR. COT. 1/4/2019 1/4/2019 2.25 SLKL PT W/ LRS (2500) RIH W/ 3' WB, 0.0 0.0 15:30 17:45 BLB & 2.69" GAUGE RING (OAL- 80") LRS ONLINE @ 1.0 BBL/MIN. BRUSH N FLUSH TBG & XN NIPPLE @ 14282' RKB, PUMPED 62 BBLS DSL, POOH, 1/4/2019 1/4/2019 0.50 RURD PJSM, LDFN, SECURE WELL, 0.0 0.0 17:45 18:15 (TICKET END @ 1800) 1/4/2019 1/4/2019 0.75 TRAY TRAVEL TO OFFICE, SYNC CPU / 0.0 0.0 18:15 19:00 TURN IN WELL FILE. 1/5/2019 1/5/2019 1.25 TRAY PU CPU / FILE, PU TOOLS @ 0.0 0.0 06:00 07:15 WIRELINE SHOP, TRAVEL TO LOCATION. 1/5/2019 1/5/2019 1.50 RURD TGSM, RU .125 WIRE & 2.125" LRL 0.0 0.0 07:15 08:45 TS= RS,8',KJ, 5',5',OJ,LSS. OAL=33.5', INSTALL FUSIBLE CAP, CONTACT DSO (TICKET START @ 09:00) Page 6130 Report Printed: 3/11/2019 Operations Summary (Detailed) 4Cg 12S-315 M 4 Rig: PTS Job: TEST-LOG-PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/5/2019 1/5/2019 3.75 SLKL PT W/ LRS (2500) RIH W/ 3.0" X- 0.0 0.0 08:45 12:30 LINE W/ 2.81" PXN PLUG, FILL EXT. & DUAL SPARTEK GAUGES, (OAL=123", GAUGES STARTED @ 08:00 AM) MOVING SLOW STARTING AROUND 3300' SLM, LRS ONLINE @ 0.50 BBL/MIN. TAP THRU 2.81" X-NIPPLE @ 13920' RKB & 14182' RKB (LRS PUMPING @ 1.5 BBL/MIN. TO PASS THRU NIPPLES) LRS OFFLINE, SET PLUG @ 14270' SLM / 14282' RKB, SEE DOUBLE BOBBLE, GOOD PULL TEST, SHEAR OFF, POOH W/O PLUG, COT. 1/5/2019 1/5/2019 3.00 SLKL PT W/ LRS (W500) QUARTER 0.0 0.0 12:30 15:30 TURN LEAKING, SERVICE VALVE, PT W/ LRS (2500) RIH W/ 3" GS W/ 3.5" BAIT SUB & PX PRONG (OAL=98") SET @ 14270' SLM / 14282' RKB, LRS ONLINE PRESURE TUBING UP F/ 1000 - 2000 PSI, HOLDING, POOH W/O PRONG, UNSTAB SURFACE EQUIPMENT. 1/5/2019 1/5/2019 1.50 SLKL LRS PERFORMED MIT-T @ 4000 0.0 00 15:30 17:00 PSI: PRE MIT = 1725 / 1150 / 300 INITIAL = 4000 / 1250 ! 300 15 MIN = 3875 / 1225 / 300 30 MIN = 3850 / 1225, 300 <<PASS» 1/5/2019 1/5/2019 3-50 SLKL PT W/ LRS (2500), RIH W/ 3' WB & 0.0 0.0 17:00 20:30 E.5" 42BO (KEYS FACING UP) ENGAGED CMU @ 14165' SLM / 14182' RKB, LRS BLED TUBING PRESSURE DOWN F/ 1000-500 PSI, 6 TAPS UP PASS THRU CMU, MADE SEVERAL MORE PASSES THRU CMU, POOH W/ SHIFTING TOOL. LOOKS GOOD. 1/5/2019 1/5/2019 075 RURD PJSM, LDFN, REMOVE FUSIBLE 0.0 0.0 20:30 21.15 CAP, CONTACT DSO (TICKET END @ 2100) 1/5/2019 1/5/2019 1 25 TRAY TRAVEL TO OFFICE, SYNC CPU ! 0.0 0.0 21:15 22:30 TURN IN WELL FILE. 1/5/2019 1/5/2019 0.50 PUMP RU LRS TO TREECAP AND PT TO 0.0 0.0 22:30 23:00 4500 PSI. FTN/CVT =PASS PRESSURE FALLS OFF FROM 2500 PSI TO 1900 PSI. INCREASE RATE. CONFIRMED CMU IS OPEN, SD. 1/5/2019 1/6/2019 1.00 PUMP RD 1" GEAR FROM TUBING, 0.0 0.0 23:00 00:00 STANDBY FOR SLICKLINE TO RDMO, SPOT UNIT. Page 7/30 Report Printed: 3/11/2019 a, Operations Summary (Detailed) 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/6/2019 1/6/2019 2.00 PUMP RU TO TREECAP AND PT TO 4500 0.0 0.0 00:00 02:00 PSI. FTN/CVT = PASS START DOWN TUBING 1950 PSI @ 0.5 BPM 2050 PSI @ 1.0 BPM 2100 PSI @ 1.5 BPM 2150 PSI @ 2.0 BPM 2250 PSI @ 2.5 BPM 2300 PSI @ 3.0 BPM 2400 PSI @ 3.5 BPM 2475 PSI @ 4.0 BPM 2550 PSI @ 4.5 BPM 2700 PSI @ 5.0 BPM SD, RDMO. END TICKET 1/6/2019 1/6/2019 4.00 OTHR No Activity 0.0 0.0 02:00 06:00 1/6/2019 1/6/2019 9.17 RURD RU Frac Equip 0.0 0.0 06:00 15:10 1/6/2019 1/6/2019 0.67 PUMP Prime up pumps 0.0 0.0 15:10 15:50 1/6/2019 1/6/2019 0.16 PUMP Pre -Job Safety Meeting 0.0 0.0 15:50 16:00 1/6/2019 1/6/2019 0.25 PUMP Pressure test hard lines to 8100 psi 0.0 0.0 16:00 16:15 1/6/2019 1/6/2019 0.25 PUMP 7600 psi N2 PRV test - Did not pop 0.0 0.0 16:15 16:30 on 1st attempt, 7604 psi on 2nd attempt, 7651 psi on 3rd attempt. 1/6/2019 1/6/2019 0.05 PUMP Start mixing gel 0.0 0.0 16:30 16:33 1/6/2019 1/6/2019 0.45 PUMP Bucket test ongoing. Done. 0.0 0.0 16:33 17:00 1/6/2019 1/6/2019 0.17 PUMP LRS bumping up IA to 3000 psis 0.0 0.0 17:00 17:10 1/6/2019 1/6/2019 0.82 PUMP Open well, start pumping 0.0 0.0 17:10 17:59 o Start pumping DFIT. o Shut down early due to blender 7 issues. Pumped 296 bbls x -link and (f hard shut -down performed. o 80 bbls of x -link in formation. 1r Blender kill switch hit on accident, cov will pump the rest of the job away. o ISIP during 1st shut -down: 3637 psi BHP, 1191 psi STP. o ISIP during 2nd shut -down: 3629 psi BHP, 1063 psi STP. r� o Shut -down 5:44PM YY o Early Analysis - Closure: 3578 psi BHP, FE: 26.58°/x, Time to close: 10 mins approx. 1/6/2019 1/6/2019 1.38 PUMP Start pumps and pump main-frac. 25 0.0 0.0 17:59 19:22 BPM 1/6/2019 1/6/2019 0.50 PUMP Shut -down 0.0 0.0 19:22 19:52 1/6/2019 1/6/2019 2.13 PUMP RD Frac Equip 0.0 0.0 19:52 22:00 1/16/2019 1/16/2019 0.75 TRAV PU WELL FILE, CHECK W/ CWG 0.0 0.0 06:00 06:45 REP, CONTACT DSO, TRAVEL TO LOCATION. Page 8/30 Report Printed: 3/11/2019 '=R Operations Summary (Detailed) .baa .,:�., 2S-315 Rig: PTS Job: TEST-LOG-PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/16/2019 1/16/2019 2.25 RURD PJSM, JSA, CREW TALK, WELL 0.0 0.0 06:45 09:00 WALK, INSPECT EQUIPMNET POST BLOW. RU .125" WIRE AND 2.125" TS=RS,QC,6',QC,KJ,5',QC,KJ,5',QC, KJ,LSS,QC (??) 1/16/2019 1/16/2019 4.25 SLKL (BEGIN TICKET @ 0900) LRS PT 0.0 0.0 09:00 13:15 W/ DIESEL @ 2500 PSI. RIH W/ KJ, 3" OK-6 (CLIMAXED) AND BK LATCH ON OV (1/4") TO ST#2 @ 13,836' SLIM (13,830' RKB) LOCATE AND SET OV. BLEED IA TOO PSI. ATTEMPT TO SHEAR OFF. IA POPS. RESET OV BLEED IA TO 0 PSI. BEGIN PUMPING ON TBG. TBG CLIMBS TO 800 PSI, THEN QUICKLY FALLS TO 450 PSI WITH PUMP ONLINE. IA REMAINS @ 0 PSI. ATTEMPT TO SHEAR OFF. IA POPS. REPEAT 2X MORE. SAME RESULT. POOH. OV WAS NO- GOED. PACKING GOOD. VLV VERY SCRATCHED. 1/16/2019 1/16/2019 2.75 SLKL LRS PT W/ DIESEL @ 2500 PSI. 0.0 0.0 13:15 16:00 RIH W/ SAME TO SAME W/ DIFFERENT LATCH. SET OV. BLEED IA. SHEAR OFF. POOH. 1/1612019 1/16/2019 1.25 SLKL ADD OSS. SAME PT. RIH W/ 3" OM 0.0 0.0 16:00 17:15 AND 1.625" JD TO ST#1 @ 2896' SLM (2919' RKB) UNABLE TO LOCATE OR S/D. BEGIN PUMPING @ 2 BPM WHILE ATTEMPTING TO LOCATE. LATCH DV. SHUT PUMP DOWN. POOH. SWAP TO STEM W/ NEW ROLL PINS. 1/16/2019 1/16/2019 1.25 SLKL DROP OTS, SAME PT. RIH W/ 3'X 0.0 0.0 17:15 18:30 1.875", QC, 3" OM AND RK LATCH ON GLV (3/16" TRO=1803) TO SAME. SET GLV. BLEED IA. TBG/IA=450/0 POOH WHILE PUMPING ON TBG TO HOLD 600 PSI. IA REMAINS @ 0 PSI. 1/16/2019 1/16/2019 1.50 SLKL ADD OYS. SAME PT. RIH W/ 3" GS 0.0 0.0 18:30 20:00 (BR) TO 13,916' SLM (13,920' RKB) LATCH CATCHER. POOH. 1/16/2019 1/16/2019 0.75 RURD (ENDED TICKET @ 2000) FUSIBLE 0.0 0.0 20:00 20:45 REMOVED, BEGIN RD, INSPECT AREA, PJSM, CONTACT DSO. 1/16/2019 1116/2019 0.75 TRAV MOVE UNIT TO YARD, TRAVEL TO 0.0 0.0 20:45 21:30 OFFICE, COMPLETE AND TURN IN REPORTS. 1/17/2019 1/1712019 11.00 MIRU MOVE RURD Complete job walk down with CPF2 0.0 0.0 00:00 11:00 PE, DSO, DSOLT,with PTS crew.HES N2 on location standing by for rig up. 1/17/2019 1/18/2019 13.00 MIRU MOVE RURD Operations signed off on final well 0.0 0.0 11:00 00:00 test walk thru to tie in production header.PTS putting a wrench on all nut and bolts on the flowback tanks to ensure tight . PTS double checking tank vents to ensure they are free of ice.PTS rigging up hardline to well head and ROS. HES N2 rigging up to ROS.Valve crew on site to service wellhead valves and production header valves. Page 9/30 Report Printed: 3/11/2019 Y Operations Summary (Detailed) 2S-315 Rig: PTS Job: TEST-LOG-PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/18/2019 1/18/2019 9.00 MIRU MOVE RURD Completed final rig up. DTH 0.0 0.0 00:00 09:00 completed hooching. 1/18/2019 1/18/2019 12.00 MIRU MOVE PRTS PJSM prior to pressure test. 0.0 0.0 09:00 21:00 Completed pre job safety meeting PTS identified frozen valves on sand trap choke manifold, moved heater into place to thaw manifolds. Start LP test with N2. test was unsusessful on multiple occatiions due to various loose connections. N2 evently created a warming effect on flow iron assisting sealing up connections. LP test successful start LP diesel test sucessful 1/18/2019 1/18/2019 2.99 MIRU MOVE RURD Pressure test complete. Wrap hard 0.0 0.0 21:00 23:59 line. Test pressure pliots and cycle SSV. 1/19/2019 1/19/2019 3.00 MIRU MOVE RURD Continued to attempt PT with diesel. 0.0 0.0 00:00 03:00 Inlet bypass valve at test seperator fails internally. 1/19/2019 1/19/2019 3.00 MIRU MOVE PRTS Valve crew on location to service 0.0 0.0 03:00 06:00 valve. Attempted to PT valve unsuceesfully. Re-attempted servicing valve. Still unable to get passing test. PTS does not have replacement parts. 1/19/2019 1/19/2019 7.00 MIRU MOVE PRTS Inlet bypasss valve is unrepairable 0.0 0.0 06:00 13:00 and no replacement valves available. Decision made to reroute flow path. Continue with high pressure test. Additional manifold rigged up and hootched in tank farm for tank suction lines. 1/19/2019 1/19/2019 4.00 MIRU MOVE PRTS Completed high pressure test to 0.0 0.0 13:00 17:00 4100 psi on PTS surface equipment. Wrap and heat all surface lines. 1/19/2019 1/19/2019 6.99 MIRU FLOWT OTHR Stand by for Operations to complete 0.0 0.0 17:00 23:59 final MOC paperwork. 1/20/2019 1/20/2019 6.00 MIRU MOVE RURD Wrapping and heating of PTS 0.0 0.0 00:00 06:00 surface equipment complete. Function test presser pilots. Function test SSV. 1/21/2019 1/21/2019 6.00 MIRU MOVE RURD PTS troubleshooting SSV issue (15 0.0 0.0 00:00 06:00 minutes to fully close both SSV). Replace outside Hydraulic hoses, Replace Hydraulic fluid with new fluid, Add additional quick exhaust to safety loop return line function test 3 times..Both safety valves close now close in 1 minute 30 secounds.Hard line crew arrived on location rigged up swab valve on top of flow cross. DTH roustabouts repositioning equipment, scraping pad and setting up stairs over flow line. PTS employees working on house keeping and tidying up work area prior to flowing. 1/21/2019 1/21/2019 6.00 SURPRD MOVE RURD Cycle SSV on multiple occations to 0.0 0.0 06:00 12:00 ensure proper function prior to operations walk down. 1/21/2019 1/21/2019 3.00 SURPRD MOVE RURD Safety stand down. 0.0 0.0 12:00 15:00 Page 10/30 Report Printed: 3/11/2019 Operations Summary (Detailed) 2S-315 Rig: PTS Job: TEST-LOG-PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/21/2019 1/21/2019 8.59 SURPRD MOVE RURD Complete MOC walk down with CPF- 0.0 0.0 15:00 23:35 2 operations. It was agreed to open well in the morning after crew change. Hold safety meeting with both PTS crews to disscuss recent MOC findings. 1/22/2019 1122/2019 6.00 MIRU FLOWT RURD Held a safety meeting with PTS 0.0 OA 00:00 06:00 employees reviewing MOC findings.PTS employees working on house keeping and tidying up work area prior to opening well.DTH roustabouts shoveling snow and building stairs over pipe where needed, Review zone 2 clean up procedure with PTS crew and HES N2 operator. 1/22/2019 1/22/2019 9.00 SURPRD FLOWT RURD Safety stand up to review the power 0.0 0.0 06:00 15:00 point (January incident focus and learning opertunities) Final job walk down complete. Received the finial MOC paper work and well commissioning check list from operations. 1/22/2019 1/22/2019 3.99 SURPRD FLOWT RURD Open well per procedure.intial TIO 0.0 0.0 15:00 18:59 equal 270/31/240 BH guage 2658. LRS pump 10 bbl MEOH spear down IA (Sample taken of MEOH). N2 on line at 350 scf/d. Fluid returns to tanks 100% diesel. 1/22/2019 1/22/2019 2.00 SURPRD FLOWT RURD 18164 choke setting. 0.0 0.0 18:59 20:59 T/1/0=207/1567/240 Temp=51 deg F, Flow rate= 0 BFPD (shipping in batches), N2 Rate=350 scfm (500 mscf/d). BS&W 100% diesel. 24 bbls returned so far. 1/22/2019 1/22/2019 3.00 SURPRD FLOWT RURD 18/64 choke setting. 0.0 0.0 20:59 23:59 T/1/0=564/1660/240 Temp=46 deg F, Flow rate= 192 BFPD (shipping in batches), N2 Rate=350 scfm (500 mscf/d). BS&W 14.9% water/gel, .1 % solids, 85% diesel. 28 bbls returned so far. 1/23/2019 1/23/2019 1.00 SURPRD FLOWT RURD 18/64 choke setting, 0.0 0.0 00:00 01:00 T/1/0=893/1649/240 Temp=51 deg F, Flow rate= 96 BFPD (shipping in batches), N2 Rate=350 scfm (500 mscf/d). BSW 98.95% water, .05% solids, 1% diesel. 28.5 bbls returned so far. 1/23/2019 1/23/2019 2.00 SURPRD FLOWT OTHR 22/64 choke setting, 0.0 0.0 01:00 03:00 T/1/0=644/1654/240 Temp=47 deg F, Flow rate= 0 BFPD (shipping in batches), N2 Rate=350 scfm (500 mscf/d). BSW 98.95% water, .05% solids, 1 % diesel. 46 bbls returned so far. 1/23/2019 1/23/2019 2.00 SURPRD FLOWT OTHR 22/64 choke setting, 0.0 0.0 03:00 05:00 T/1/0=893/1654/240 Temp=48 deg F, Flow rate= 0 BFPD (shipping in batches), N2 Rate=350 scfm (500 mscfld). BSW 99.25% water, .75% solids, 52 bbls returned so far. Page 11130 Report Printed: 3/11/2019 Operations Summary (Detailed) 2S-315 Rig: PTS Job: TEST-LOG-PROFILE Time Log Depth Progress Start Time End Time our (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/23/2019 1/23/2019 2.00 SURPRD FLOWT OTHR 22/64 choke setting, 0.0 0.0 05:00 07:00 T/1/0=948/1684/240 Temp=59 deg F, Flow rate= -96 BFPD (shipping in batches), N2 Rate=350 scfm (500 mscf/d). 1/23/2019 1/23/2019 5.00 SURPRD FLOWT OTHR Increased to 28/64 choke setting, 0.0 0.0 07:00 12:00 T/1/0=532/1710/240 Temp=46° F, DHP= 2650 psi. DHT= 135° F. Flow rate= 672 BFPD (shipping in batches), N2 Rate= 500 scfm. PTS working on data transfer/client reprt due to errors in reporting. DHD Shot IA FL at 7766'. 1/23/2019 1/23/2019 2.50 SURPRD FLOWT OTHR 28/64 choke setting, 0.0 0.0 12:00 14:30 T/1/0=328/1719/240 Temp=52° F, Flow rate= 816 BFPD (shipping in batches), N2 Rate increased to =550 scfm (500 mscf/d). 1/23/2019 1/23/2019 3.50 SURPRD FLOWT OTHR Increased choke settings to 30/64, 0.0 0.0 14:30 18:00 T/I/0= 450/1730/240 Temp=45° F DHP= 2574 psi. DHT= 138° F. N2 Rate=600 scfm (864 mscf/d).. DHD shot IA FL at 8647' (881' below previous shot) 1/23/2019 1/23/2019 2.00 SURPRD FLOWT OTHR 30/64 choke setting, TWO= 0.0 0.0 18:00 20:00 686/1748/240 Temp=47° F DHP= 2475 psi. DHT= 139° F. Increase the N2 Rate=650 scfm (936 mscf/d). Increase N2 temperature to 107°, was previously 98°. Monitoring IA/OA pressure closely. 1/23/2019 1/23/2019 2.00 SURPRD FLOWT OTHR 30/64 choke setting, T/I/0= 0.0 0.0 20:00 22:00 670/1746/338 Temp=43° F DHP= 2448 psi. DHT= 140° F. Decrease the N2 Rate=625 scfm (900 mscf/d).N2 unit can pump for 14 hours at current rate. 1/23/2019 1/23/2019 1.99 SURPRD FLOWT OTHR 30/64 choke setting, T/1/0= 0.0 0.0 22:00 23:59 645/1749/347 Temp=47° F DHP= 2436 psi. DHT= 140° F. 1/24/2019 1/24/2019 3.00 SURPRD FLOWT OTHR 30/64 choke setting, T/I/0= 0.0 0.0 00:00 03:00 625/1752/351 Temp=52° F DHP= 2421 psi. DHT= 140° F. N2 Rate=625 scfm (900 mscf/d). 1/24/2019 1/24/2019 3.00 SURPRD FLOWT OTHR 30/64 choke setting, T/I/0= 0.0 0.0 03:00 06:00 625/1752/351 Temp=52° F DHP= 2421 psi. DHT= 140° F. N2 Rate=625 scfm (900 mscf/d). 1/24/2019 1/24/2019 4.00 SURPRD FLOWT OTHR 30/64 choke setting, T/1/0= 0.0 0.0 06:00 10:00 725/1728/342 Temp=70° F DHP= 2340 psi. DHT= 140° F. N2 Rate=625 scfm (900 mscf/d). DHD Shot IA FL at 10,161' (1513' decrease in -12 hours) 1/24/2019 1/24/2019 5.00 SURPRD FLOWT OTHR Opened choke settings to 32/64, 0.0 0.0 10:00 15:00 T/I/0= 388/1755/347 Temp= 57° F DHP= 2359 psi. DHT= 141 ° F. N2 Rate=625 scfm (900 mscf/d). 1/24/2019 1/24/2019 0.50 SURPRD FLOWT OTHR Opened choke settings to 34/64, 0.0 0.0 15:00 15:30 T/I/0= 328/1769/366 Temp= 59° F DHP= 2339 psi. DHT= 141° F. N2 Rate=625 scfm (900 mscf/d). Page 12/30 Report Printed: 3/11/2019 - ` h: ' Operations Summary (Detailed) y 2S-315 s • ♦ . s Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/24/2019 1/24/2019 3.00 SURPRD FLOWT OTHR Opened choke settings to 36/64, 0.0 0.0 15:30 18:30 T/1/0= XXXX Temp= XX' F DHP= XXX psi. DHT= XXXX° F. Reduced N2 Rate to -350 scfm (500 mscf/d). 1/24/2019 1/24/2019 2.50 SURPRD FLOWT OTHR Choke setting at 36164, T/1/0= 0.0 0.0 18:30 21:00 287/1755/384 Temp= 54° F DHP= 2080 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1/24/2019 1/24/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 21:00 23:00 287/1755/384 Temp= 54° F DHP= 2080 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1124/2019 1/25/2019 1.99 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 23:00 00:59 230/1764/373 Temp= 51° F DHP= 2275 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1/25/2019 1/25/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 00:00 02:00 233/1759/366 Temp= 58° F DHP= 2219 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1/25/2019 1/25/2019 1.99 SURPRD FLOWT OTHR Choke setting at 36164, T/1/0= 0.0 0.0 02:00 03:59 222/1774/366 Temp= 57° F DHP= 2296 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1/25/2019 1/25/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 03:59 05:59 218/1770/367 Temp= 58° F DHP= 2237 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1/25/2019 1/25/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 05:59 07:59 181/1886/368 Temp= 59° F DHP= 2231 psi. DHT= 142°F. N2 Rate at -350 scfm (500 mscf/d). IA FL at 13,756'. 1/25/2019 1/25/2019 1.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/I/0= 0.0 0.0 07:59 08:59 224/1762/365 Temp= 56° F DHP= 2124 psi. DHT= 141T. N2 Rate at -350 scfm (500 mscf/d). IA FL at 13,786'. 1/25/2019 1/25/2019 1.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 08:59 09:59 243/1759/364. Temp= 53° F DHP= 2071 psi. DHT= 142° F. N2 Rate at -350 scfm (500 mscf/d). IA FL at 113,830' 1/25/2019 1125/2019 1.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 09:59 10:59 255/1755/364. Temp= 56° F DHP= 2035 psi. DHT= 142° F. N2 Rate at -350 scfm (500 mscf/d). IA FL at 13,830' 1/25/2019 1/25/2019 5.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 10:59 15:59 230/1761/372. Temp= 56° F DHP= 2076 psi. DHT= 142° F. N2 Rate at -350 scfm (500 mscf/d). 1/25/2019 1/25/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 15:59 17:59 516/1775/370. Temp= 57° F DHP= 2131 psi. DHT= 142° F. N2 Rate at -350 scfm (500 mscf/d). 1/25/2019 1/25/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 17:59 19:59 222/1765/369. Temp= 58° F DHP= 2161 psi. DHT= 142° F. N2 Rate at -350 scfm (500 mscf/d). 1/25/2019 1/25/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 19:59 21:59 229/1766/373. Temp= 59° F DHP= 2169 psi. DHT= 142° F. N2 Rate at -350 scfm (500 mscf/d). Page 13/30 Report Printed: 3/11/2019 Operations Summary (Detailed) t } 2S-315 NMI Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/25/2019 1125/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 21:59 23:59 224/1777/378. Temp= 58° F DHP= 2190 psi. DHT= 142° F. N2 Rate at -350 scfm (500 mscf/d). 1/26/2019 1/26/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/l/0= 0.0 0.0 00:00 02:00 235/1730/335 Temp= 58° F DHP= 2433 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1/26/2019 1/26/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/1/0= 0.0 0.0 02:00 04:00 228/1774/372 Temp= 56° F DHP= 2212 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1/26/2019 1/26/2019 2.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/l/0= 0.0 0.0 04:00 06:00 228/1774/372 Temp= 56° F DHP= 2212 psi. DHT= 141° F.N2 Rate at -350 scfm (500 mscf/d). 1/26/2019 1/2612019 6.00 SURPRD FLOWT OTHR Choke setting at 36/64, T/I/0= 0.0 0.0 06:00 12:00 353/1563/450Temp= 70° F DHP= 1801 psi. DHT= 143° F.N2 Rate at -350 scfm (500 mscf/d). BS&W 93% H2O, 7% Oil 1/26/2019 1/26/2019 2.50 SURPRD FLOWT OTHR Increase choke setting to 38/64, 0.0 0.0 12:00 14:30 T/I/0= 283/1619/430Temp= 70° F DHP= 1891 psi. DHT= 143° F.N2 Rate at -350 scfm (500 mscf/d). BS&W 90% H2O, 10% Oil 1/26/2019 1/26/2019 0.50 SURPRD FLOWT OTHR Choke setting to 38/64, T/1/0= 0.0 0.0 14:30 15:00 277/1649/420 Temp= 70° F DHP= 1909 psi. DHT= 143° F. N2 Rate at -500 scfm (720 mscf/d). BS&W 90% H2O, 10% Oil 1/26/2019 1/26/2019 3.00 SURPRD FLOWT OTHR Choke setting to 38/64, T/I/0= 0.0 0.0 15:00 18:00 475/1581/460 Temp= 70° F DHP= 1687 psi. DHT= 142° F. N2 Rate at -500 scfm (720 mscf/d). BS&W 91 % H2O, 10% Oil 1/26/2019 1/26/2019 3.00 SURPRD FLOWT OTHR Choke setting to 38/64, T/1/0= 0.0 0.0 18:00 21:00 367/1497/464 Temp= 69° F DHP= 1691 psi. DHT= 142° F. N2 Rate at -500 scfm (720 mscf/d). BS&W 96% H2O, 10% Oil 1/26/2019 1/26/2019 2.99 SURPRD FLOWT OTHR Choke setting to 38/64, T/1/0= 0.0 0.0 21:00 23:59 368/1501/467 Temp= 74° F DHP= 1663 psi. DHT= 142° F. N2 Rate at -500 scfm (720 mscf/d). BS&W 95% H2O, 10% Oil 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 00:00 02:00 350/1516/463 Temp=73° F DHP= 1660 psi. DHT= 142° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 02:00 04:00 351/1560/461 Temp=72° F DHP= 1657 psi. DHT= 142° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/I/0= 0.0 0.0 04:00 06:00 375/1560/453 Temp=72° F DHP= 1657 psi. DHT= 142° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/l/0= 0.0 0.0 06:00 08:00 412/1444/436 Temp=78° F DHP= 1598 psi. DHT= 142° F.N2 Rate at - 500 scfm (.720 mscf/d). Page 14/30 Report Printed: 3/11/2019 Operations Summary (Detailed) 4_ 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time our (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/27/2019 1127!2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 08:00 10:00 361/1400/432 Temp=71° F DHP= 1567 psi. DHT= 142° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 10:00 12:00 352/1415/434 Temp=71 ° F DHP= 1588 psi. DHT= 142° F.N2 Rate at - 500 scfm (.720 mscf/d). Gas gravity 93.39 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 12:00 14:00 352/1415/434 Temp=71°F DHP= 1588 psi. DHT= 142° F.N2 Rate at - 500 scfm (720 mscf/d). Gas gravity 93.39 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 14:00 16:00 352/1415/434 Temp=71 ° F DHP= 1588 psi. DHT= 142° F.N2 Rate at - 500 scfm (.720 mscf/d). Gas gravity 93.39 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 16:00 18:00 361/1392/423 Temp=73° F DHP= 1552 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). Gas gravity 93.39 1/27/2019 1127/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 18:00 20:00 359/1388/419 Temp=73° F DHP= 1547 psi. DHT= 143° F.N2 Rate at 500 scfm (.720 mscf/d). Gas gravity 93.39 1/27/2019 1/27/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 20:00 22:00 366/1435/413 Temp=73° F DHP= 1594 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). Gas gravity 93.39 1/27/2019 1/27/2019 1.99 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 22:00 23:59 396/1371/419 Temp=75° F DHP= 1512 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). Gas gravity 93.39 1/28/2019 1/28/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38164, T/1/0= 0.0 0.0 00:00 02.00 365/1357/409 Temp=75° F DHP= 1526 psi. DHT= 142° F.N2 Rate at 500 scfm (.720 mscf/d). 1/28/2019 1/28/2019 3.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 02:00 05.00 371/1372/409 Temp=75° F DHP= 1521 psi. DHT= 142° F.N2 Rate at - 500 scfm (720 mscf/d). 1/28/2019 1/28/2019 1.00 SURPRD FLOWT OTHR Choke setting at 38164, T/1/0= 0.0 0.0 05:00 06.00 374/1349/401 Temp=74° F DHP= 1507 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/28/2019 1128/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 06:00 08:00 T/1/0=362/1352/403 Temp=72° F DHP= 1500 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/28/2019 1/28/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 08:00 10:00 T/1/0=354/1349/401 Temp=71° F DHP= 1503 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/28/2019 1/28/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 10:00 12:00 T/1/0=397/1355/401 Temp=71° F DHP= 1500 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). Gas gravity .952 Page 15/30 Report Printed: 3/11/2019 Operations Summary (Detailed) e }, } 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time our (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/28/2019 1/28/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 12:00 14:00 T/1/0=372/1316/399 Temp=71° F DHP= 1469 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). API gravity of 35.7 1/28/2019 1/28/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 14:00 16:00 T/1/0=323/1351/399 Temp=70° F DHP= 1496 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). API gravity of 35.7 1/28/2019 1/28/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 16:00 18:00 T/I/0=361/1378/398 Temp=72° F DHP= 1496 psi. DHT= 143° F.N2 Rate at - 500 scfm (720 mscf/d). API gravity of 35.7 1/28/2019 1/28/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 18:00 20:00 T/1/0=375/1372/397 Temp=68° F DHP= 1372 psi. DHT= 143° F.N2 Rate at - 500 scfm (720 mscf/d). API gravity of 35.7 1/28/2019 1/28/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 20:00 22:00 T/1/0=378/1359/393 Temp=69° F DHP= 1458 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). API gravity of 35.7 1/28/2019 1128/2019 1.99 SURPRD FLOWT OTHR Choke setting at 38/64, 0.0 0.0 22:00 23:59 T/1/0=369/1351/391 Temp=67° F DHP= 1455 psi. DHT= 143° F.N2 Rate at - 500 scfm (.720 mscf/d). API gravity of 35.7 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 00:00 02:00 369/1345/490 Temp=69° F DHP= 1345 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 02:00 04:00 365/1339/389 Temp=67° F DHP= 1339 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (720 mscf/d). 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 04:00 06:00 363/1319/385 Temp=67° F DHP= 1319 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 06:00 08:00 362/1319/385 Temp=67° F DHP= 1319 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 08:00 10:00 363/1316/385 Temp=67° F DHP= 1430 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 10:00 12:00 364/1312/382 Temp=67° F DHP= 1418 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (720 mscf/d). 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 12:00 14:00 368/1306/381 Temp=67° F DHP= 1410 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 14:00 16:00 366/1301/380 Temp=74° F DHP= 1409 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). Page 16/30 ReportPrinted: 3/11/2019 Operations Summary (Detailed) 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Start Time End Time our (hr) Phase Cp Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) Depth Progress (ft) 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38164, T/1/0= 0.0 0.0 16:00 18:00 366/1297/380 Temp=69° F DHP= 1403 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/29/2019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 18:00 20:00 368/1296/378 Temp=71°F DHP= 1395 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/2912019 1/29/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 20:00 22:00 367/1292/377 Temp=69° F DHP= 1391 psi. DHT= 143 ° F.N2 Rate at 500 scfm (.720 mscf/d). 1/29/2019 1/29/2019 1.99 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 22:00 23:59 370/1287/376 Temp=73° F DHP= 1383 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 00:00 02:00 370/1284/375 Temp=75° F DHP= 1380 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 02:00 04:00 369/1282/375 Temp=67° F DHP= 1377 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 04:00 06:00 368/1277/374 Temp=67° F DHP= 1371 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 06:00 08:00 364/1272/373 Temp=67° F DHP= 1368 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscftd). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 08:00 10:00 362/1271/373 Temp=67° F DHP= 1366 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 10:00 12:00 368/1269/372 Temp=67° F DHP= 1361 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 12:00 14:00 366/1265/373 Temp=67° F DHP= 1356 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 14:00 16:00 362/1262/370 Temp=67° F DHP= 1353 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1130/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 16:00 18:00 363/1260/369 Temp=67° F DHP= 1349 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). Page 17/30 Report Printed: 3/11/2019 `k Operations Summary (Detailed) a3' , 2S-315 Rig: PTS Job: TEST-LOG-PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 18:00 20:00 363/1259/369 Temp=67° F DHP= 1349 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 20:00 22:00 363/1257/367 Temp=66° F DHP= 1344 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/30/2019 1/30/2019 1.99 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 22:00 23:59 368/1258/366 Temp=65° F DHP= 1346 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 00:00 02:00 363/1258/365 Temp=68° F DHP= 1343 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/110= 0.0 0.0 02:00 04:00 367/1254/364 Temp=71 ° F DHP= 1338 psi. DHT= 143 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38164, T/1/0= 0.0 0.0 04:00 06:00 364/1254/364 Temp=65° F DHP= 1340 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 06:00 08:00 364/1254/363 Temp=72° F DHP= 1340 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 08:00 10:00 366/1252/362 Temp=63° F DHP= 1336 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (720 mscf/d). 1/31/2019 1/3112019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 10:00 12:00 360/1249/361 Temp=63° F DHP= 1334 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 12:00 14:00 360/1249/361 Temp=55° F DHP= 1335 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 14:00 16:00 363/1247/361 Temp=60° F DHP= 1333 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 16:00 18:00 363/1247/360 Temp=60° F DHP= 1336 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 18:00 20:00 370/1251/361 Temp=62° F DHP= 1334 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). Page 18130 Report Printed: 3/11/2019 Operations Summary (Detailed) k 2S-315 s • a' s Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 1/31/2019 1/31/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 20:00 22:00 368/1252/360 Temp=60° F DHP= 1334 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 1/31/2019 1/31/2019 1.99 SURPRD FLOWT OTHR Choke setting at 38164, TWO= 0.0 0.0 22:00 23:59 356/1248/358 Temp=61°F DHP= 1332 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 2/1/2019 2/1/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/I/0= 0.0 0.0 00:00 02:00 359/1254/357 Temp=61 ° F DHP= 1334 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 2/1/2019 2/1/2019 2.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 02:00 04:00 369/1252/356 Temp=61 ° F DHP= 1331 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 mscf/d). 2/1/2019 2/1/2019 1.00 SURPRD FLOWT OTHR Choke setting at 38/64, T/1/0= 0.0 0.0 04:00 05:00 366/1250/355 Temp=61°F DHP= 1331 psi. DHT= 144 ° F.N2 Rate at - 500 scfm (.720 2/1/2019 2/1/2019 1.00 SURPRD FLOWT OTHR Shut in well at 6000 -bbl total returns - 0.0 0.0 05:00 06:00 2/1/2019 2/1/2019 1.00 SURPRD FLOWT OTHR SLICKLINE: PU CPU/ WELL INFO, 0.0 0.0 06:00 07:00 TRAVEL TO LOCATION (STUCK BEHIND RIG MOVE) 2/1/2019 2/1/2019 1.75 SURPRD FLOWT OTHR SLICKLINE: WAITING FOR RIG 0.0 0.0 07:00 08:45 MOVE ((TICKET START @ 08:00) 2/1/2019 2/112019 1.75 SURPRD FLOWT OTHR SLICKLINE: CHECK IN W/ 0.0 0.0 08:45 10:30 COMPANY MAN & SIMOPS W/ PTS, SPOT UNIT, TGSM, RU .125 WIRE & 2.125" RLR TS= RS, 6', KJ , 5', KJ, 5', KJ, 5', OJ, KJ, LSS. OAL= 37.5', 7 SECTION LUBRICATOR, INSTALL FUSIBLE CAP, CONTACT DSO. 211/2019 2/1/2019 3.00 SURPRD FLOWT OTHR SLICKLINE: PT W/LRS ( 2500) RIH 0.0 0.0 10:30 13:30 W/ 2.68" CENT & 5'X 2.25" DD-BLR (OAL= 82") TAGGED @ 14167' SLM / 14184' RKB (( ROUGHLY 2' BELOW CMU, GOING OFF OF CF= 17' FROM 1/05/19)) POOH W/ TOOLS COVERED IN PARAFFIN, TRACE AMOUNTS OF FRAC SAND. COT. 2/1/2019 2/1/2019 2.00 SURPRD FLOWT OTHR SLICKLINE: PT W/LRS (2500) RIH 0.0 0.0 13:30 15:30 W/2.64" CENT & 10'X 2.50" P.BLR (OAL= 160") TAGGED @ 14167' SLM, WORKED DOWN TO 14170' SLM, POOH W/ ABOUT 1' OF FRAC SAND IN BLR, CONFER W1 CWG REP. COT 2/1/2019 211/2019 2.75 SURPRD FLOWT OTHR SLICKLINE: PT W/LRS (2500) RIH 0.0 0.0 15:30 18:15 W/ 3' WB & 3 %" 42 BO SHIFTING TOOL (, NOT ENGAGING CMU @ 14165' SLM/ 14182' RKB, POOH WHILE LRS PUMPED 30 BBLS DSL DOWN TBG, TBG PRESSURE DROPPED f/ 1050 - 650 PSI, OOH IW/42 BO, CONFER W/ CWG REP. Page 19130 Report Printed: 3/11/2019 Operations Summary (Detailed) •;, � t 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 2/1/2019 2/1/2019 0.75 SURPRD FLOWT OTHR SLICKLINE: PJSM, LDFN, REMOVE 0.0 0.0 18:15 19:00 FUSIBLE CAP, CONTACT DSO ( TICKET END @ 18:00) 2/1/2019 2/1/2019 4.99 SURPRD FLOWT OTHR Prep for CT FCO. 0.0 0.0 19:00 23:59 2/2/2019 2/2/2019 2.00 SURPRD FLOWT OTHR WS WAS RIGGING UP THE FB FOR 0.0 0.0 00:00 02:00 THE CT FCO. SAID THE DAYSHIFT WILL BE OUT IN THE A.M. TO FINISH THE RU. 2/2/2019 2/2/2019 4.00 SURPRD WS PREP FLUIDS AND 0.0 0.0 02:00 06:00 FLOWBACK FOR CT FCO. 2/2/2019 2/2/2019 1.00 SURPRD SLICKLINE: PU LAPTOP AND 0.0 0.0 06:00 07:00 FOLDER F -WING, TRAVEL TO LOCATION. 2/2/2019 2/2/2019 1.50 SURPRD SLICKLINE: PJSM. RU 0.125" WIRE 0.0 0.0 07:00 08:30 & 2.125 RLR. TS: RS,6', KJ,5', KJ,5',OJ, KJ, LSS. OAL=37.5'. SEVEN SECTIONS OF LUBRICATOR. INSTALL FUSIBLE CAP. CONTACT DSO. 2/2/2019 2/2/2019 4.25 SURPRD SLICKLINE: PT WITH LRS 3000 -PSI 0.0 0.0 08:30 12:45 HIGH. RIH W/ 3' WB & 3-1/2" 4260. TAG @ 14166' SLM. JAR DOWN FOR ABOUT 10 MINUTES. APPEAR TO BE TAGGING @ 14168' SLM. PUH 200'. LRS ONLINE PUMPED 25 -BBL DSL. TBG PRESSURED f/ 1150-2000 PSI. WATCH FOR 10 - MIN DOWN TO 1800 -PSI. TAP DOWN FOR ANOTHER 10 -MIN @ 14166' SLM. POOH. 2/2/2019 2/2/2019 1.00 SURPRD SLICKLINE: LRS PERFORMED MIT- 0.0 0.0 12:45 13:45 T. PRE -MIT PRESSURES 1900/1050/0. INITIAL = 3000/1050/0 15 -MIN = 2925/1050/0 30 -MIN = 2925/1050/0 -PASS BLED TBG BACK TO 1500 -PSI 2/2/2019 2/2/2019 0.50 SURPRD SLICKLINE: PJSM. RDMO. 0.0 0.0 13:45 14:15 REMOVE FUSIBLE CAP. CONTACT DSO. 2/2/2019 2/2/2019 5.75 SURPRD COIL TUBING: SPOT UP CTU#4 ON 0.0 0.0 14:15 20:00 WELL. TROUBLESHOOTING COMPUTER/DATAAQUISITION ISSUE. 2/2/2019 2/2/2019 3.99 SURPRD PTS MONITORING DH GAUGES 0.0 0.0 20:00 23:59 AND LOCATION. 2/3/2019 2/3/2019 6.00 SURPRD PTS MONITORED LOCATION FOR 0.0 0.0 00:00 06:00 HSE. STILLACQUIRING DATA FROM DH GAUGES. 2/3/2019 2/3/2019 2.00 SURPRD COIL TUBING: ATTEND SLB 0.0 0.0 06:00 08:00 WEEKLY SAFETY MEETING 2/3/2019 2/3/2019 2.00 SURPRD COIL TUBING: TRAVEL TO 2S-315 0.0 0.0 08:00 10:00 LOCATION. TRAFFIC SLOW/STOPPED DUE TO RIG MOVE. Page 20130 Report Printed: 3/11/2019 Operations Summary (Detailed) _ p 3 2S-315 r s" Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 2/3/2019 213/2019 2.00 SURPRD COIL TUBING: RU CTU ON WELL. 0.0 0.0 10:00 12:00 MAKE UP BHA#1 CONSISTING OF: CT CONNECTOR, 1.75" OD, .125', DOWNHOLE CHECK VALVE, 2.00" OD, 1.00'; WEIGHT BAR, 2.00" OD, 3.75' DOWN JET NOZZLE, 2.00" OD, 0.50' LENGTH TOTAL OVERALL LENGTH = 9.125' PT RISER 300 PSI LOW, 4000 PSI HIGH 213/2019 2/3/2019 2.00 SURPRD COIL TUBING: RIH WITH 2" JET 0.0 0.0 12:00 14:00 NOZZLE CHECKING WEIGHT 2/3/2019 2/3/2019 2.00 SURPRD COIL TUBING: TAG FILLAT 14.105' 0.0 0.0 14:00 16:00 CTMD. ENGAGED PUMPS PUMPING SLICK DIESEL @ 2.5 BBL/MIN WASH DOWN TO 14,190' CTMD PUMP TWO 15 BBL DIESEL GEL SWEEPS AROUND STACK WEIGHT WHILE PUMPING @ 2.5 BBL/MIN AND ATTEMPT TO RUN INTO OBSTRUCTION CONSULT WITH OFFICE. CALL LRS WITH HOT OIL PUMP 2/3/2019 2/3/2019 1.00 SURPRD COIL TUBING: RU LRS UPON 0.0 0.0 16:00 17:00 ARRIVAL. PT LINES. HEAT UP SLICK DIESEL TO 140 DEGS. 2/3/2019 2/3/2019 1.50 SURPRD COIL TUBING: PUMP 114 BBLS OF 0.0 0.0 17:00 18:30 140 DEG SLICK DIESEL DOWN CT. PUMP 110 BBLS OF 140 DEG SLICK DIESEL, 50 BBLS @ 1.5 BBL/MIN ACROSS THE NOZZLE. RIH TO 14,190' CTMD AND REPEATEDLY TAGGED OBSTRUCTION. NO PENETRATION. 2/3/2019 2/3/2019 1.50 SURPRD COIL TUBING: POOH WITH 1.75" 0.0 0.0 18:30 20:00 OD CT W/JET NOZZLE 2/3/2019 2/3/2019 0.50 SURPRD COIL TUBING: RACK BACK 0.0 0.0 20:00 20:30 INJECTOR 2/3/2019 2/3/2019 3.49 SURPRD PTS MONITORED LOCATION FOR 0.0 0.0 20:30 23:59 HSE. STILLACQUIRING DATA FROM DH GAUGES. 2/4/2019 2/4/2019 6.00 SURPRD PTS MONITORED LOCATION FOR 0.0 0.0 00:00 06:00 HSE. STILLACQUIRING DATA FROM DH GAUGES. 2/4/2019 2/4/2019 1.00 SURPRD COIL TUBING: TRAVEL TO 2S-315 0.0 0.0 06:00 07:00 LOCATION Page 21/30 Report Printed: 3/11/2019 w Operations Summary (Detailed) 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 2/4/2019 2/4/2019 1.50 SURPRD COIL TUBING: RIG UP CTU ON 0.0 0.0 07:00 08:30 WELL. MAKE UP BHA#2 CONSISTING OF: CT CONNECTOR 2.38" OD, 1.40' _ DOWNHOLE CHECK VALVE 2.13" OD, 1.70' HAI LEY ACCELERATOR 2.25" OD, 4 16' = WEIGHT BAR 2.13" OD, 4.92' HAILEY BI -DI JAR (9/16" BALL DRIFT) 2.25" OD, 3.88' TJ DISCONNECT (9/16" BALL DRIFT, 1/2" BALL) 2.125" OD, 1.58' X -OVER 1.5" MT X 2.375" PAC 2.72" OD, .43' = 3" G SPEAR 2.72" OD, 1.56' TOTAL OVERALL LENGTH = 19.63' = PT RISER 300 PSI LOW, 4000 PSI HIGH 2/4/2019 2/4/2019 4.50 SURPRD COIL TUBING: RIH WITH 3" G 0.0 0.0 08:30 13:00 SPEAR. CHECKING WEIGHT. RIH TO 14,260' CTMD. SET DOWN 1 O DOWN. ENGAGE PRONG. JAR 5 TIMES AT 12K OVER PICKUP WEIGHT (28K) SPEAR RELEASED. POOH WITH 3" G SPEAR AND PRONG. PRONG RECOVERED. 2/4/2019 2/4/2019 0.50 SURPRD COIL TUBING: MAKE UP BHA#3 0.0 0.0 13:00 13:30 CONSISTING OF: CT CONNECTOR 2.38" OD, 1.40' _ DOWNHOLE CHECK VALVE 2.13" OD, 1.70' HAILEY ACCELERATOR 2.25" OD, 4.16' = WEIGHT BAR 2.13" OD, 4.92' HAILEY BI -DI JAR (9/16" BALL DRIFT) 2.25" OD, 3.88' TJ DISCONNECT (9/16" BALL, DRIFT 1/2" BALL) 2.125" OD, 1.58' X -OVER 1.5" MT X 2.375" PAC 2.72" OD, .43' = 3" G SPEAR 2.72" OD, 1.56' TOTAL OVERALL LENGTH = 19.63' = PT QTS 2/4/2019 2/4/2019 4.00 SURPRD COIL TUBING: RIH WITH 3" G 00 0.0 13:30 17:30 SPEAR. CHECKING WEIGHT RIH TO 14,268' CTMD. LATCH 2.81" PXN PLUG W/SPARTEK GAUGES. PU OBSERVE OVERPULL OF 1 OK. PLUG RELEASED. POOH WITH 3" G SPEAR AND 2.81" PXN PLUG W/SPARTEK GAUGES. PLUG BODY AND GAUGES RECOVERED. 2/4/2019 2/4/2019 0.75 SURPRD COIL TUBING: RACK BACK 0.0 0.0 17:30 18:15 INJECTOR 2/4/2019 2/4/2019 5.74 SURPRD PTS MONITORED LOCATION FOR 0.0 0.0 18:15 23:59 HSE. 2/5/2019 2/5/2019 6.00 SURPRD PTS MONITORED LOCATION FOR 0.0 0.0 00:00 06:00 1 1 1 HSE, 2/5/2019 2/5/2019 1.00 SURPRD COIL TUBING: TRAVEL TO 2S-315 001 0.0 06:00 07:00 1 LOCATION Page 22/30 Report Printed: 3/11/2019 Operations Summary (Detailed) =F 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress StartTime End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 2/5/2019 2/5/2019 1.00 SURPRD COIL TUBING: RIG UP CTU ON 0.0 0.0 07:00 08:00 WELL. MAKE UP BHA#4 CONSISTING OF: COILED TUBING CONNECTOR 2.38" OD, 1.40', DOWN HOLE CHECK VALVE, 2.13" OD, 1.70'; HAI LEY ACCELERATOR 2.25" OD, 4.16'; WEIGHT BAR 2.13" OD, 4.92' , HAILEY BI -DI JAR (9/16" BALL DRIFT) 2.25" OD, 3.88'; TJ DISCONNECT (9/16" BALL; DRIFT /z' BALL) 2.125" OD, 1.58'; 42BO SHIFTING TOOL 3.18"OD, 1.83', X - OVER SUB 2.13"OD, .25'; JET SWIRL NOZZLE 2.13" OD, .38' TOTAL OVERALL LENGTH = 18.52'; PRESSURE TEST QTS 300 PSI LOW, 4,000 PSI HIGH. 2/5/2019 2/5/2019 4.00 SURPRD COIL TUBING: RIH WITH 42BO 0.0 0.0 08:00 12:00 SHIFTING TOOL. CHECKING WEIGHT. TAG AT 13,790' CTMD. (GLM AT 13,829'). PU AND LINE UP TO PUMP SLICK DIESEL. SURGE PUMP AND WORK THROUGH GLM AREA. RIH TO 14,260' CTMD. NO INDICATION OF SHIFTING TOOL LOCATING IN SLIDING SLEEVE. PICK UP SLOWLY NO EXTRA WEIGHT/DRAG OBSERVED TILL ABOVE SLIDING SLEEVE. POOH WITH 42BO SHIFTING TOOL. SHUT IN WELL. REMOVE FUSIBLE LOCK -OUT CAP. 2/5/2019 2/5/2019 0.50 SURPRD COIL TUBING: RIG UP 0.0 0.0 12.00 12:30 HALLIBURTON NITROGEN UNIT. PRESSURE TEST LINES 2/5/2019 2/5/2019 1.00 SURPRD COIL TUBING: DISPLACE 1.75" 0.0 0.0 12:30 13:30 COILED TUBING REEL WITH NITROGEN TAKING 36 BBLS. OF SLICK DIESEL RETURNS TO THE TIGER TANK. BLEED OFF ALL PRESSURES. 2/5/2019 2/5/2019 1.50 SURPRD COIL TUBING: LAY DOWN BHA#4 0.0 0.0 13:30 15:00 WITH SHIFTING TOOL. RIG DOWN CTU AND PREPARE FOR TRAVEL. 2/5/2019 2/5/2019 2.00 SURPRD COIL TUBING: TRAVEL TO BASE 0.0 0.0 15:00 17:00 WITH CTU #4. 2/5/2019 2/5/2019 1.00 SURPRD SVS TECH'S DID STATE TEST ON 0.0 0.0 17:00 18:00 THE TREE SSV - PASSED 2/5/2019 2/5/2019 1.00 SURPRD VALVE CREW SERVICED WELL 0.0 0.0 18:00 19:00 HEAD VALVES AND ISO VALVES ON THE RO SKID 2/5/2019 2/512019 4.99 SURPRD PTS CREW RE -CONNECTED FB 0.0 0.0 19:00 23:59 HARDLINE TORO SKID. PT'D 01 WITH DIESEL TO 4000 PSI - $ PASSED. PUMPED 5 BBLS OF METH IN THE IA IN PREP TO RE -POP WELL. 2/6/2019 2/6/2019 2.00 SURPRD / 'k PTS RE -POP WELL AT 12:15am. 0.0 0.0 00:00 02:00 (•' MONITORING FLOWBACK AT 02:00am > Choke setting at 20/64, T/1/0 = 425/1397/269, Temp=40° F, BHP=2112, BHT=143 degs ° F.N2 Rate at - 400 scfm (.576 mscf/d). Page 23/30 Report Printed: 3/11/2019 Operations Summary (Detailed) �s4 i f s 2S-315 f Rig: PTS Job: TEST-LOG-PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) M 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 20164, T/1/0 = 0.0 0.0 02:00 04:00 690/1588/293, Temp=40° F, BHP=2041, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 24/64, T/1/0 = 0.0 0.0 04:00 06:00 585/1713/320, Temp=36° F, BHP=2010, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 26/64, T/1/0 = 0.0 0.0 06:00 08:00 451/1689/305, Temp=41° F, BHP=1979, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 30/64, T/1/0 = 0.0 0.0 08:00 10:00 729/1667/355, Temp=51° F, BHP=1869, BHT=144 F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 32/64, TWO = 0.0 0.0 10:00 12:00 714/1645/375, Temp=60° F, BHP=1849, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 216/2019 2/6/2019 2.00 SURPRD Choke setting at 34/64, T/1/0 = 0.0 0.0 12:00 14:00 615/1605/394, Temp=54° F, BHP=1763, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 34/64, T/1/0 = 0.0 0.0 14:00 16:00 579/1605/382, Temp=53° F, BHP=1794, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 36/64, T/1/0 = 0.0 0.0 16:00 18:00 520/1575/415, Temp=58° F, BHP=1709, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 36/64, T/1/0 = 0.0 0.0 18:00 20:00 464/1558/422, Temp=61 ° F, BHP=1698, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 2.00 SURPRD Choke setting at 36/64, T/1/0 = 0.0 0.0 20:00 22:00 428/1554/419, Temp=62° F, BHP=1694, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/6/2019 2/6/2019 1.99 SURPRD Choke setting at 38/64, T/1/0 = 0.0 0.0 22:00 23:59 405/1534/442, Temp=58° F, BHP=1646, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/7/2019 2/7/2019 2.00 SURPRD Choke setting at 40/64, T/1/0 = 0.0 0.0 00:00 02:00 362/1525/450, Temp=61° F, BHP=1604, BHT=144 degs ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/7/2019 2/7/2019 2.00 SURPRD Choke setting at 40/64, T/1/0 = 0.0 0.0 02:00 04:00 355/1511/459, Temp=61° F, BHP=1581, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). Page 24130 Report Printed: 3/11/2019 i Operations Summary (Detailed) J 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 2/7/2019 2/7/2019 3.00 SURPRD Choke setting at 38/64, T/I/O = 0.0 0.0 04:00 07:00 331/1489/458, Temp=73° F, BHP=1489, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/7/2019 2/7/2019 2.00 SURPRD Choke setting at 38/64, T/I/O = 0.0 0.0 07:00 09:00 356/1476/438, Temp=70° F, BHP=1561, BHT=144 ° F.N2 Rate at — 400 scfm (576 mscf/d). Corrected API 38.3 2/7/2019 2/7/2019 2.00 SURPRD Choke setting at 38/64, T/I/O = 0.0 0.0 09:00 11:00 343/1472/439, Temp=66° F, BHP=1545, BHT=144 ° F.N2 Rate at — 400 scfm (576 mscf/d). 2/7/2019 2/7/2019 2.00 SURPRD Choke setting at 38/64, T/1/0 = 0.0 0.0 11:00 13:00 314/1465/433, Temp=68° F, BHP=1465, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/7/2019 2/7/2019 2.00 SURPRD Choke setting at 38/64, T/I/O = 0.0 0.0 13:00 15:00 346/1471/412, Temp=61° F, BHP=1547, BHT=144 ° F.N2 Rate at — 400 scfm (576 mscf/d). 2/7/2019 2/7/2019 2.00 SURPRD Choke setting at 38/64, T/I/O = 0.0 0.0 15:00 17:00 35811469/427, Temp=62° F, BHP=1559, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/7/2019 2/7/2019 1.00 SURPRD Choke setting at 38/64, T/I/O = 0.0 0.0 17:00 18:00 346/1463/429, Temp=62° F, BHP=1506, BHT=144 ° F.N2 Rate at — 400 scfm (.576 mscf/d). 2/7/2019 2/7/2019 5.99 SURPRD SI WELLAT 6:30PM DUE TO SAND 0.0 0.0 18:00 23:59 DUMP LINE TO SPARGE TANK PLUGGED. SEE SUMMARY. DUE TO PLUGGED LINE, AND PLAN FORWARD PER TYSON, FP'D TBG WITH 30 BBLS DIESEL AND SURFACE PIPING WITH 19 BBLS DIESEL, WHICH INCLUDED PROD FLOWLINE. PTS WORKING ON THE PLUGGED SAND DUMP LINE. 2/8/2019 2/8/2019 6.00 SURPRD PTS DISCONNECTED THE 0.0 0.0 00:00 06:00 PLUGGED SECTION OF THE SAND DUMP LINE (-140') AND REPLACING IT WITH EXTRA PIPE INORDER TO GET THE LINE BACK IN SERVICE. 2/8/2019 2/8/2019 2.00 SURPRD HES SLICKLINE: TRVL TO CWG, 0.0 0.0 06:00 08:00 PU FILES, GRAB TOOLS @ W/L SHOP, ONTO CPF-2 & STANDBY IN UNIT FOR DIRECTION, GET CALL TO GO TO 2S, ONTO LOC, CONTACT DSO. 2/8/2019 2/8/2019 1.00 SURPRD HES SLICKLINE: SIM OPS W/ PTS 0.0 0.0 08:00 09:00 & HAL N2, MOVE TRIPLEX, SOURCE TANK, BLEED TANK, SPOT UNIT, TRACK DOWN WELL FILE & JOB SCOPE. Page 25130 Report Printed: 3/11/2019 Operations Summary (Detailed) g 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 2/8/2019 2/8/2019 1.00 SURPRD HES SLICKLINE: INSPECT, PJSM, 0.0 0.0 09:00 10:00 JSA, MIRU .125" WIRE, 2.125" RLR TS = 5',KJ,5',KJ,5',KJ,5',OJ,KJ,LSS (CAL 36'), INSTALL FUSIBLE, (START TICKET @ 0900). 2/8/2019 2/8/2019 3.00 SURPRD HES SLICKLINE: PT W/ LRS TO 0.0 0.0 10:00 13:00 2500, RIH W/ KJ, 3'x1.875", 3.5" 42BO (SR KEYS UP), SEE F/L AROUND 5200' SLM, BOL LRS FOR 35 BBLS WHILE RIH, STARTING TO PRESSURE UP, SD LRS & CONTINUE RIH, BOBBLING AROUND 12050' SLM, BOL LRS TOTAL 51 BBLS BUT PRESSURING UP TO 3000, ABLE TO WORK DWN TO 12110' SLM, UNABLE TO WORK DEEPER, POOH, BLEED TBG BACK TO 2000, OOH W/ 42BO (SMALL AMOUNT OF PARAFFIN ON SHIFTING TOOL). 2/8/2019 2/8/2019 4.75 SURPRD HES SLICKLINE: PT W/ LRS TO 0.0 0.0 13.00 17:45 2500, RIH W/ 3'x 1.875", 2.79" GAUGE RING, SD @ 12212' SLM BOL LRS @35 BPM TO SLOWLY PRESSURE UP TBG TO 3500 AFTER 8.5 BBLS AWAY, SD LRS & WORK GAUGE DOWN TO 12372' SLM, PULL UP & BOL LRS AGAIN FOR 2 BBLS TO PRESSURE UP TO 3500, SD LRS & WORK DWN TO 12590' SLM, BOL LRS AGAIN TO PRESSURE UP 2.9 BBLS AWAY, WORK DOWN TO 13328'& FINALLY BREAKS THRU, DRIFT FREELY TO TAG X -NIP, DRIFT FROM 12000'-13000' SLM, POOH, OOH GAUGE RING (VERY SMALL AMOUNT OF PARAFFIN ON GAUGE RING), WINDS INCREASED TO 37 MPH, CONTACT CWG, (END TICKET @ 1800). 2/8/2019 2/8/2019 0.75 SURPRD HES SLICKLINE: LAY DWN DUE TO 0.0 0.0 17:45 18:30 HIGH WINDS, FUSIBLE REMOVED, TREE CAP SECURE, PJSM, CONTACT DSO. 2/8/2019 2/8/2019 1.50 SURPRD HES SLICKLINE: TRVL TO CWG, 0.0 0.0 18:30 20:00 TURN IN FILE & PAPERWORK, TRVL TO CAMP. 2/8/2019 2/8/2019 3.99 SURPRD PHASE II WEATHER CONDITIONS 0.0 0.0 20:00 23:59 DELCARED AT 8:OOPM. PTS SECURED LOCATION. CONVOYED BACK TO CAMP 2/9/2019 2/9/2019 6.00 SURPRD PHASE II WEATHER CONDITIONS 0.0 0.0 00:00 06:00 DECLARED. LOCATION SECURED, PTS NIGHT CREW AT CAMP FROM 12A - 6A. 2/9/2019 2/912019 1.00 SURPRD HES SLICKLINE 765: TRVL TO 0.0 0.0 06:00 07:00 CWG, PU FILE, ONTO LOC, CONTACT DSO, VERIFY LOC CLEAR FOR RU & PHASE LIFTED. Page 26/30 Report Printed: 3/11/2019 Operations Summary (Detailed) 4 ' � 2S-315 a Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 219/2019 2/9/2019 1.00 SURPRD HES SLICKLINE 765: INSPECT, 0.0 0.0 07:00 08:00 PJSM, JSA, MIRU .125" WIRE, 2.125" RLR TS = 5',KJ,5',KJ,5',l',OJ,1',KJ,1',LSTJ,1' ( OAL 37'), INSTALL FUSIBLE, (START TICKET @ 0800). 2/912019 2/9/2019 1.00 SURPRD HES SLICKLINE 765: STANDBY 0.0 0.0 08:00 09:00 FOR LRS,LRS ON LOC, RU & PT. 2/9/2019 2/9/2019 2.00 SURPRD HES SLICKLINE 765: PT W/ LRS TO 0.0 0.0 09:00 11:00 3500, RIH W/2.68" CENT, 5'x 2.5" DD BAILER (MULE BALL), DRIFT FREELY TO TAG @ 14035' SLM, WORK BAILER FOR 10 MINS TO 14042' SLM, NOT GETTING STICKY, POOH, F/L @ 2900' SLM, OOH W/ 2/9/2019 2/9/2019 3.00 SURPRD HES SLICKLINE 765: PT W/ LRS TO 0.0 0.0 11:00 14:00 3500, RIH W/ SAME, BOL LRS FOR 20 BBLS, LRS STARTS TO PRESSURE UP TO 3000 PSI, SD @ 14040' SLM, WORK BAILER FOR 10 MINS NOT REALLY MAKING HOLE BUT GETTING REAL STICKY HAVE TO HIT ASPANG LICK UP TO GET OUT, POOH, F/L @ 1700' SLM, OOH W/A FOOT OF FRAC SAND IN BAILER, TUBE JARS LOCKED UP, CUT 250' WIRE. 2/9/2019 2/9/2019 2.50 SURPRD HES SLICKLINE 765: PT W/ LRS TO 0.0 0.0 14:00 16:30 3500, RIH W/ 2.68"CENT, 10' x 2.5" DD BAILER (MULE BALL), SD @ 14038' SLM, WORK BAILER FOR 10 MINS NOT MAKING ANY HOLE, NOT GETTING STICKY, POOH, OOH W/ V OF FRAC SAND. 2/9/2019 2/9/2019 2.00 SURPRD HES SLICKLINE 765: PT W/ LRS TO 0.0 0.0 16:30 18:30 3500, RIH W/ 2.68"CENT, 10' x 2" DD BAILER (MULE BALL), SD @ 14036' SLM, WORK BAILER FOR 10 MINS GETTING STICKYA FEW TIMES, NOT MAKING HOLE, POOH, OOH W/ 3' OF FRAC SAND IN BAILER, (END TICKET @ 1800). 2/9/2019 2/9/2019 1.00 SURPRD HES SLICKLINE 765: RDMO, 0.0 0.0 18:30 19:30 FUSIBLE REMOVED, TREE CAP SECURE, PJSM, CONTACT DSO. 2/9/2019 2/9/2019 1.00 SURPRD HES SLICKLINE 765: TRVL TO 0.0 0.0 19:30 20:30 CWG, TURN IN FILES & PAPERWORK, ORION, TRVL TO CAMP. 2/9/2019 2/9/2019 3.49 SURPRD PTS PT'D THE SAND DUMP LINE 0.0 0.0 20:30 23:59 THAT WAS REPLACED. WS RU FB TANKS/HARDLINE FOR THE CT FCO. 2/10/2019 2/10/2019 8.00 SURPRD PTS MONITORED LOCATION FOR 0.0 0.0 00:00 08:00 HSE. PTS PRE -CHARGED VESSEL IN PREP FOR BLOWDOWN. STANDING BY FOR OPS TO PERFORM EIP TO RE -RIG FB HARDLINE FROM PROD FLOWLINE TO THE TEST HEADER. 2/10/2019 2/10/2019 2.00 SURPRD CTU #14: Travel to 2S-315 (Cairn) 0.0 0.0 08:00 10:00 Location from Schlumberger Yard Deadhorse. Page 27/30 Report Printed: 3/11/2019 Operations Summary (Detailed) 2S-315 F Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (ftKB) (ft) 2/10/2019 2/10/2019 2.75 SURPRD CTU #14: Rig Up CTU on well. Make 0.0 0.0 10:00 12:45 Up BHA#1 Consisting of: Coiled Tubing Connector 1.75" OD, .125', Down Hole Check Valve, 2.00" OD, 1.075'; Weight Bar 2.00" OD, 3.50'; Weight Bar 2.00" OD, 4.00', Down Jet Nozzle 2.00" OD, 0.50' Length. Total Overall Length = 9.20' Pressure Test Riser 300 psi low, 4,000 psi high. 2/10/2019 2/10/2019 2.25 SURPRD CTU #14: RIH with 2" OD Down Jet 0.0 0.0 12:45 15:00 Nozzle. Checking weight. Tag at 14,371' CTMD. (Bottom Perforation 14,345 RKB.) 2/10/2019 2/10/2019 1.00 SURPRD CTU #14: Wash with Slick Diesel @ 0.0 0.0 15:00 16:00 2.5 bbl./min. with 50% fluid returns with gas. Sweep with 10 bbls of Diesel Gel. Attempt to wash deeper. Stacking weight on bottom. Pump Bottoms up 80 bbls. Sweep hole with 25 bbls pill of Diesel Gel. POOH Observed overpull on Coiled Tubing @ 14,237' CTMD, 20K over CT Weight. Vary Pump Rates and CT weight normalized. Pump coming out of hole getting 50% of returns to surface. 2/10/2019 2/10/2019 2.00 SURPRD CTU #14: POOH with 1.75" OD 0.0 0.0 16:00 18:00 Coiled Tubing with 1.75" OD Down. SWFN. 2/10/2019 2/10/2019 1.00 SURPRD CTU #14: Stack Back Injector. Break 0.0 0.0 18:00 19:00 down BHA. Change Coiled Tubing Pack Off. 2/10/2019 2/1012019 1.00 SURPRD CTU #14: Travel to Base. 0.0 0.0 19:00 20:00 2/10/2019 2/10/2019 3.99 SURPRD PTS/LRS FLUSHED SAND HOG / 0.0 0.0 20:00 23:59 MANIFOLD WITH DIESELTO CLEAN OUT THE REMAINING SAND IN PREP FOR THE NEXT FB PHASE TO PRODUCTION PTS MONITOR LOCATION FOR HES. 2/11/2019 2/11/2019 10.50 SURPRD PHASE CONDITIONS REQUIRED 0.0 0.0 00:00 10:30 CREW TO LEAVE LOCATION AT 02:30AM. (TURNED TO PHASE 3) 2/11/2019 2/11/2019 1.00 SURPRD CTU #14: Travel to 2S-315 (Cairn) 0.0 0.0 10:30 11:30 Location. 2/11/2019 2/11/2019 1.50 SURPRD CTU #14: Rig Up CTU on well. Make 0.0 0.0 11:30 13:00 Up BHA#2 Consisting of: Coiled Tubing Connector 2.38" OD, 1.40', Down Hole Check Valve, 2.13" OD, 1.70'; Hailey Bi -Di Jar (9/16" Ball Drift) 2.25" OD, 3.88'; TJ Disconnect (9/16" Ball; Drift 1/2" Ball) 2.13" OD, 1.58'; Fluted Centralizer 2.78" OD, .82"; Extension 2" OD 1.00'; 42BO Shifting Tool 3.18"OD, 1.86', X -Over Sub 2.13"OD, .25'; Extension 2" OD 1.50'; Fluted Centralizer 2.78" OD, .82", Down Jet Nozzle 2.13" OD, .37' Total Overall Length = 15.18'; Pressure Test QTS 300 psi low, 4,000 psi high. Page 28/30 Report Printed: 3/11/2019 - z { > Operations Summary (Detailed) ' 2S-315 Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (ftKB) End Depth (WB) (ft) 2/11/2019 2/11/2019 2.50 SURPRD CTU #14: RIH with 42BO Shifting 0.0 0.0 13:00 15:30 Tool. Checking weight. RIH to 14,220' CTMD. (Sliding Sleeve @ 14,182 RKB) PU and engage sliding sleeve with 42BO Shifting Tool. Pick up to 14,140' CTMD and observe 6K overpull to indicate sliding sleeve opened. No pressure change observed on well head pressure. 2/11/2019 2/11/2019 1.75 SURPRD CTU #14: POOH with 42BO Shifting 0.0 0.0 15:30 17:15 Tool. Observed overpull periodically, engage pump and RIH as needed to continue POOH. Shut in Well. Remove Fusible Lock -out cap. 2/11/2019 2/11/2019 1.25 SURPRD CTU #14: Lay down BHA#2 with 0.0 0.0 17:15 18:30 Shifting Tool. Rig Down CTU and prepare for travel. 2/11/2019 2/11/2019 5.49 SURPRD PTS / HES N2 BLEWDOWN THE 0.0 0.0 18:30 23:59 SURFACE LINES WITH N2. PTS RE -RIGGED THE FB HARDLINE FROM THE PROD FLOWLINE TO THE TEST LINE. 2/12/2019 2/12/2019 12.00 SURPRD PTS COMPLETED THE RE -RIG OF 0.0 0.0 00:00 12:00 THE FB HARDLINE FROM THE PROD FLOWLINE TO THE TEST LINE, PTS / OPS DID THE WALKDOWN TO CONFIRM THE RU WAS CORRECT PTS / HES N2 / LRS DID THE PT ON THE FB HARDLINE (LOW PT WITH N2, HIGH PT WITH DIESEL) LRS FP'D THE PROD FLOWLINE FOR OPS, AND PUMPED 5 BBLS METH IN THE IA IN PREP FOR POP. OPS FAC ENG WALKED DOWN THE JOB, COMPLETED THE MOC. 2/12/2019 2/12/2019 11.99 SURPRD PTS MONITORING LOCATION FOR 0.0 0.0 12:00 23:59 HSE HOLDING OFF ON POP UNTIL TOMORROW MORNING DUE TO WEATHER FORECAST OF PHASE CONDITIONS TONIGHT. 2/13/2019 2/13/2019 12.00 SURPRD PTS POP WELL AT 11:15AM. 0.0 0.0 00:00 12:00 ROUTING GAS THROUGH THE TEST LINE / MPM, TAKING FLUIDS TO TANKS UNTIL SOLIDS CRITERIA IS MET. PTS MONITORING FLOW FOR SOLIDS PRODUCTION 2/13/2019 2/13/2019 11.99 SURPRD PTS MONITORING FLOW FOR 0.0 0.0 12:00 23:59 SOLIDS PRODUCTION. RELEASED JACOBS VAC TRUCKS NIGHT CREW DRIVERS. Page 29/30 Report Printed: 3/11/2019 Operations Summary (Detailed) 2S-315 I Rig: PTS Job: TEST -LOG -PROFILE Time Log Depth Progress Start Time End Time Dur (hr) Phase Op Code Activity Code Operation Start Depth (W[3) End Depth (ftKB) (ft) 2/14/2019 2/14/2019 12.00 SURPRD PTS SEEN A LITTLE SOLIDS 0.0 0.0 00:00 12:00 PRODUCTION, BACKED CHOKE DOWN A LITTLE. SUBSIDED. WORKED CHOKE BACK UP SLOWLY. EXPRO COLLECTED THE REQUESTED SAMPLES AT 02:OOAM. ONCE SOLIDS CRITERIA WAS MET, PTS DIVERTED PROD FLUIDS FROM TANKS TO THE TEST LINE / MPM AT 5:OOAM WHEN FLOW WAS DIVERTED, THEY BACKED OUT HES N2 AND STARTED MI GAS LIFT. RELEASED HES N2 AT 05:30AM TO RDMO. MI GAS LIFT ORIFICE PLATE TOO BIG, G/L RATE WILL NOT HOLD STEADY UNLESS OVER 1.0 MMSCFD. CPF-2 PROD ENG ADVISED TO INCREASE G/L RATE TO 1.25 MMSCFD. THEN ADVISED TO INCREASE TO 2.0 MMSCFD. 2114/2019 2/14/2019 11.99 SURPRD CONTINUE TO FLOW WELL TO 0.0 0.0 12:00 23:59 TEST LINE / MPM. MONITOR FOR SOLIDS PER PROD ENG REQUEST, INCREASED CHOKE FROM 32 TO 34, TO 36 BEANS. 2/15/2019 2115/2019 12.00 SURPRD CONTINUED TO FLOW WELL TO 0.0 0.0 00:00 12:00 TEST LINE / MPM. MONITOR FOR SOLIDS. SI WELLAT 10:15AMAND HAD LRS FP TBG W/30 BBLS METH. (A SMALL HYDRATE PLUG HAD STARTING FORMING IN THE TBG. THE METH CUT THROUGH IT) HES N2 BLOWDOWN ALL SURFACE LINES. PTS / DTH BEGAN RD OF THE TEST SPREAD. 2/15/2019 2115/2019 11.99 SURPRD RELEASED TANKS, EQUIPMENT 0.0 0.0 12:00 23:59 THAT IS READY TO BE PICKED UP / HAULED AWAY. PTS / DTH CONTINUE RD OF THE TEST SPREAD. 2/16/2019 2/16/2019 12.00 SURPRD PTS / DTH CONTINUE RD OF THE 0.0 0.0 00:00 12:00 TEST SPREAD. 2/16/2019 2/16/2019 11.99 SURPRD PTS / DTH CONTINUE RD OF THE 0.0 0.0 12:00 23:59 1TEST SPREAD. 2/17/2019 2/17/2019 12.00 SURPRD PTS / DTH FINISHED RD OF THE 0.0 0.0 00:00 12:00 TEST SPREAD DTH LOADER SCRATCHED THE TEST SPREAD AREA TO CLEAN UP / LEVEL THE AREA. 2/17/2019 2/17/2019 11.99 SURPRD DTH, WELL SUPPORT, ETC WILL 0.0 0.0 12:00 23:59 CONTINUE HAULING EQUIPMENT OFF PAD. Page 30/30 Report Printed: 3/11/2019 21 01 10 30 44 3 Bell, Abby E (DOA) From: Bell, Abby E (DOA) Sent: Wednesday, March 13, 2019 4:40 PM To: Conoco Phillips Transmittals (Tom.Osterkamp@conocophillips.com) Subject: AOGCC Transmittal Request and Packaging Reminder Hi Tom, I just received some confidential data (PTD# 2181100) that was submitted with a Report of Sundry Well Operations (404). Since these types of data are handled by different people, the AOGCC asks that this data is packaged separately. They can be delivered at the same time, but they must be placed in separate envelopes or similar. Also, whenever data is submitted to me for entry, I need some form of transmittal sheet outlining what is being delivered, by whom, to whom, and any other relevant information. I did not receive a transmittal for this data, just a CD and flash drive. This time, I will use this email correspondence as the transmittal, but future deliveries will be rejected, resulting in a delay for both parties. Finally, I have had a few instances of data being improperly labeled as "Confidential" when it is not, and vice -versa the past few weeks. Proper labeling helps all who handle the data follow proper protocol. If you have questions about any of this, please do not hesitate to ask. Thank you— Abby Bell Natural Resource Technician II Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue 907-793-1225 NVIDD AL i IAN 14 2019 STATE OF ALASKA CONFIDENTIAL ALASr\A OIL AND GAS CONSERVATION COMMioSION WN LLCOMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ' C)il'Rl `Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory � Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 12/13/2018 14. Permit to Drill Number / Sundry: 218-110 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 11/16/2018 15. API Number: , 50-103-20776-00-00 4a. Location of Well (Governmental Section): Surface: ' 3087' FNL, 1614' FEL, Sec 17, T1 ON, R08E, UM Top of Productive Interval: 4230' FNL, 1518' FEL, Sec 29, T10N, R08E, UM Total Depth: 4669' FNL, 1369' FEL, Sec 29, TI ON, R8E, UM 8. Date TD Reached: 12/2/2018 16. Well Name and Number: KRU 2S-315 9. Ref Elevations: KBA59.4 GL:120 BF: 17. Field / Pool(s): (,(jak� Kuparuk River Field/Exploratory 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: 9 ADL 25603, ADL 25608 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 480956.55 y- 5929961.45 Zone- 4 TPI: x- 481058 y- 5918259 Zone- 4 Total Depth: x- 481207 y- 5917820 Zone- 4 11. Total Depth MD/TVD: 1465416009� 19. DNR Approval Number: 931899000/931903000 12. SSSV Depth MD/TVD: NONE 20. Thickness of Permafrost MD/TVD: 1455/1434 5. Directional or Inclination Survey: Yes [I (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) I 21. Re-drill/Lateral Top Window MD/TV1 N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/NEU/DEN/NMR/MicroScope, Muo��°ys 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16 62.5 H-40 40 119 40 119 42 Stage 1:72 sx 15.7 ppg Conduct cement. 10 314 45.5 L-80 40 3571 40 2636 13 112 1436 sx 11.Oppg Class G, 306sx 15.8 ppq Class G 75/8 29.7 L-80 38 14558 38 5941 97/8 893sx 15.8 Class G 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): PERFORATIONS @: ,C?i`�1P� ET{Oh; 14173-14203 MD and 5669 - 5690 TVD ... 12/10/2018 14315-14345 MD and 5757 - 4541 TVD... 12/22/2018 DATE 1Z) i3�IPl _aEL 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD 31/2 14300 14030/5569,14266/5734 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: WAITING FOR HOOKUP Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period -11110. Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 1 Flow Tubing Press. Casing Press: Calculated 24 -Ho ate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Fo rm evise ., . �kmi F�on ly �.:�,,n.� M� J: ,, ... 1 Q i -19u 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME + MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1454 1434 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 13998 5547 information, including reports, per 20 AAC 25.071. Formation @ TPI -Top Cairn Ugnu C 1198 1190 j b-1/0'4 s L'A1 f)td West Salk Top 1930 1853 West Sak Base 2938 2472 C-90 3644 2655 C-80 4688 2916 Campanian SS 4881 2965 C-40 11611 4626 C-37 (Top Iceberg) 12466 4836 T-6 (Base Iceberg) 13735 5363 T-4 14045 5579 C-35 14515 5910 TD 14654 6009 Formation at total depth: Base Cairn 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical rer)ort, r)roduction or well test results, er 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. 4,1L j/ Authorized Name: G.L. Alvord Contact Name: Nick Lehman ( 1 Authorized Title: Alaska Drillinq-Monacier P Contact Email: Nick. R. Lehman co .com C�Contact Phone: 263-4951 Authorized/�Ll Signature: Date:0/ IN RUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. 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. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only DePin Dawm. 16' 62.5# H40 Conductor 3902 RKB�120'aMve MBL= 119'MD/ND 59 11 Base Perma Frost -1455' MD 11434' ND . . . . . . . . . . . . . . . . . . . 13-112"Open Hole ,0-3,4..45 5# L80 HY0563 Surface Casing 3571' MD / 2636' TVD 9718 " 7/e" Open Hole from 3,571' to 14,459' 8%, Open Hot, from 14,459'to 14,654' 75/6' 29.7# LBO TXP Production Casing From 0-14558' Top C-3712466' / 4835' MD / ND . . . . . . . . . . . . . . . . . . . . . . . . Top Caim13gg8'/5547'MD/ND " aang wa., mNve^.'ivirz nn.s Conductor Cemented to Surface Base Caim —14409' MD / 5834' ND . . . . . . . . . . . . TD - 14654' / 6009' MD / ND 45deg (Tangent 76deg) , . Ngk• •Lower Perf Interval - 14315'-14345' 3 %"9.3# EUE Tubing. End of Tubing 1429866'MD Surface Cement Job „ , , , , " Lead off 1 0 PPG'G', Tail of 15.8 PPG'G' Lead from Surface to 3071', 2875" DS Nipple 52TMD Tail from 307 'to 3571' Total of 1436 sacks 11.Oppg lead ant 3176 sacks 15.8ppg fail pumped. Observed 170.5 bible of good 11.Oppg Cement returned to surface V V 1.5"MMG GLM w/DCR-1 SOV pinned to 2000psi-2919'MD i 3%'9.3# EUE Tubing. End of Tubing 14298 66M Production Cement Job 15.8 PPG 'G' from TD to 250 ND above C-37, 1" KBMG GLM (Dummy) 13829.78' MDTotal of 893 sacks of 15.8ppg cement pumped. CBL results showed TOC 11,300' MD/4,549'ND 2813"X Nipple 13920 MD DH gauge 13972' MD 3 W. 7-7/8" Baker Premier Packer @ 14 034MD SSD w/ 2.813X profile" 14182' MD Perls: 14173'- 14203' 3 W. 7-79" Baker Premier Packer ® 14,266 MD 2,813" XN Nipple .12.75" No go 14282' MD 3-12" x 7-5/8" Trailblazer Casing Scraper Tool or VVLEG @ 14293' Base Caim —14409' MD / 5834' ND . . . . . . . . . . . . TD - 14654' / 6009' MD / ND 45deg (Tangent 76deg) , . Ngk• •Lower Perf Interval - 14315'-14345' 3 %"9.3# EUE Tubing. End of Tubing 1429866'MD KUP PROD WELLNAME 2S-315 Well Attributer ConoeoPhillips Fie d Name Wellbore APVUWI Wellbe Alaska, Inc - _; TRACT OPERATION GAIRNTRI 501032077600 PROC WELLBORE 2S-315 Max AngleP TD ncl (°) MD I.., 6.26 3,123.81 Act Bill(RKB) 14,654.0 End Date I K11 -(3'd (ft) 39.42 Rig Release Date 12/13/2018 SLANT -2S-315, 1/11/20199: 27: 05 AM Last Tag Verecal schematic (actual) Annotation Depth (ftK8) End Date Wellbore Last Mod By Last Tag: RKB 14,337.0 12118/2018 2S-315 zem baej I ............................................................................................. banger; 356- Last Rev Reason Annotation End Date Wellbore Last Mod By ...................... .................... Rev Reason: Pulled DFCV 8 Replaced SOV w/ DV 12/1812018 2S-315 Izembaej Casing Strings Casing Description OD (in) ID (in) Top (RKB) Set Depth (RKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR 16 15.25 40.5 119.0 119.0 62.50 H-40 Welded """"""""""""""""""" " " "' """ Casing Description OD (in)ID (in) Top (ftK8) Set Depth (RKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread Surface 10 3/4 9.95 40.5 3,570.9 2,635.8 45.50 L-80 Hydril 563 Casing Description OD (in) ID (in) Top (RKB) Set Depth (ftK8) ISet Depth (TVD)... WtlLen (I... Grade Top Thread Production 75/8 6.88 I I 37.8 14,558.4 5,940.8 29.70 L80 TXP-m Tubing Strings Tubing Description IString Ma... ID (in) Top (ftK8) Set Depth (ft.. Set Depth (TVD) (... Wt (lb/ft) Grade Top Connection Tubing - Production 131/2 2.99 35.6 14,300.0 5,758.2 9.30 L-80 EUE-m Completion Details Top (TVD) Topincl Nominal Top (ftK8) (RKB) (°) Item Des Co. ID (in) 35.6 35.6 0.00 Hanger Hanger, 4-112" x 10-3/4" Gen 5, FMC TC -1A EMS TYPE H BPV 3.860 527.1 527.1 1.69 Nipple 3-1/2" Nipple, Carrico, 2.875" DS Profile, SN:T091412 (4.9° 2.875 CONDUCTOR, 40.4-119.0 hole angle) 13,920.1 5,492.0 45.48 Nipple 3-1/2" X Nipple, Carrico, 2.813", SN:2662-15 (45.48° 2.813 hole angle) 13,972.6 5,528.8 45.48 Gauge/ Pump Gauge Carrier, SLB, SGM with Sapphire tubing pressure gauge, 2.896 Sensor SN:Cl6GM-0460 14,030.2 5,569.2 45.52 Packer Packer, Baker 31/2" x 7 5/8" Premier CN 106290353-02 2.880 14,182.2 5,675.7 45.52 Sliding Sleeve Baker 2.81"X profile CMU Sliding Sleeve (1443308) 2.810 14,266.2 5,734.5 45.52 Packer Packer, Baker 3 1/2" x 7 5/8" Premier SN 106749821 2.870 Mandrel, 2,919 9 14,282.4 5,745.9 45.51 Nipple 3-1/2" GXN Nipple, Carrico, 2.813", 2.812" 2.75 no-go) SN:2610- 2.812 3 (45.5° hole angle) 14,293.7 5,753.8 45.51 Casing Scraper 13 112" X 7 5/8" Trailblazer Casing scraper Tool SN 0131349 2.810 14,298.7 5,757.3 45.51 Mule Shoe 3.5" WLEG Mule 3.010 Shoe --� Surface; 40.4-3,570.9 en Perforations lar Slots Shot Den Top (TVD) Btm(TVD) (shots/ft Top (RKB) St. (RKB) (RKB) (ftK8) Linked Zone Date ) Type Co. 14,173.0 14,203.0 5,669.2 5,690.2 12/10/2018 6.0 Perforate d 14,315.0 14,345.0 5,768.7 5,789.7 12/22/2018 6.0 IPERF 2.5" HSD, HyperJet 2506, 6SPF, 60 -deg Phasing, 10.5g RDX. WeIITec Tractor Deployed Inserts Mandrel; 13,829,8 -Mandrel St .ti N Top(ftKB) Top (TVD) (RKB) Make Model DID (in) Sery Valve Type Latch Type PortSize (in) TRO Run (psi) Run Date Co. 1 2,919.8 2,465.2 Carrico PN: 1 112 GAS LIFT DMY RK 0.000 0.0 12/17/2018 100009 9369, ser# 265AGO 7 2 13,829.8 5,428.7 Camco PN: 1 GAS LIFT Dumm BK 12/12/2018 Gauge/ Pump Sensor, 13,972.6 11131- y 01_VC S, ser # 19436- 13 Packer 14,030.2 Sliding Sleeve: 14,182.2 Padorated, 14,173.0-14,203.0 i Packer; 14,266.2 Mule Shoe; 14,298.7 PERF; 14,3150-14,345.0- 4,3150-14,345.0Production; Product-37.B-14, 558.4 operations Summary (with Timelog uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/15/2018 11/15/2018 2.00 MIRU MOVE MOB P Skid rig floor to moving position. Raise 0.0 0.0 00:00 02:00 stompers. Move pipeshed and rockwasher from 3S pad to 3G pad. 11/15/2018 11/15/2018 0.50 MIRU MOVE MOB P Pull sub off 3S-612. 0.0 0.0 02:00 02:30 11/15/2018 11/15/2018 4.50 MIRU MOVE MOB P Transport all modules from 3S pad to 0.0 02:30 07:00 CPF 2. 21 miles traveled. 11/15/2018 11/15/2018 0.25 MIRU MOVE MOB P Change out PEAK crew. Discover 0.0 0.0 07:00 07:15 failed axle bearing on pump module. 11/15/2018 11/15/2018 2.50 MIRU MOVE MOB P Transport pipeshed, pits, motors and 0.0 0.0 07:15 09:45 sub from CPF 2 to 2S pad. Total of 33.5 miles traveled. 11/15/2018 11/15/2018 1.75 MIRU MOVE MOB P Stage sub for spotting over well. Set 0.0 0.0 09:45 11:30 composite mats and wellhead equpment. in cellar. Set rig mats for sub. 11/15/2018 11/15/2018 1.25 MIRU MOVE MOB P Spot and set sub over 2S-315. 0.0 0.0 11:30 12:45 Remove tow bar from sub. Sim- ops/Transport pump mod from CPF 2 to 2S pad. Pump module on location at 12:30 hrs. 11/15/2018 11/15/2018 1.50 MIRU MOVE MOB P Set stompers. Skid rig floor to drilling 0.0 0.0 12:45 14:15 position. Sim-ops/Set rig mats for pump and power modules. 11/15/2018 11/15/2018 0.25 MIRU MOVE MOB P Spot pit module to sub. Berm cellar. 0.0 0.0 14:15 14:30 11/15/2018 11/15/2018 0.50 MIRU MOVE MOB P Spot pump module. 0.0 0.0 14:30 15:00 11/15/2018 11/15/2018 0.50 MIRU MOVE MOB P Spot power module. 0.0 0.0 15:00 15:30 11/15/2018 11/15/2018 0.75 MIRU MOVE MOB P Spot pipeshed. 0.0 0.0 15:30 16:15 11/15/2018 11/15/2018 0.75 MIRU MOVE MOB P Spot rockwasher and cuttings tank. 0.0 0.0 16:15 17:00 Berm cuttings tank and set super sucker landing. Sim-ops/Hook up electrical lines in innerconnects. Swap to rig gen power at 17:00 hrs. 11/15/2018 11/15/2018 6.00 MIRU MOVE RURD P Rig up high pressure mud lines, 0.0 0.0 17:00 23:00 steam, water and air lines. Rig up skate rail. Install skate rail cables and function test skate. Work on rig acceptance check list. Sim-ops/Load 43 joints of 10 3/4" casing into pipeshed. Rig up Geolog mud loggers. Accept rig at 23:00 hrs 11/15/18 11/15/2018 11/16/2018 1.00 MIRU MOVE NUND P Nipple up diverter system. Obtain 0.0 0.0 23:00 00:00 RKB's. Install flow nipple and mousehole. Sim-ops/Take on spud mud and load BHA into pipehsed. Sim -ops/Rig up Geolog mud loggers. 11/16/2018 11/16/2018 2.00 MIRU MOVE NUND P Continue to nipple up diverter. Install 0.0 0.0 00:00 02:00 riser, turnbuckles and 4" conductor outlet valves. Tighten diverter bolts. Obtain diverter measurements. Sim- ops/Continue to rig up mud logging unit. 11/16/2018 11/16/2018 1.25 MIRU MOVE SLPC P Slip and cut drilling line. 0.0 0.0 02:00 03:15 11/16/2018 11/16/2018 0.50 MIRU MOVE SVRG P Service top drive, blocks and crown 0.0 0.0 03:15 03:45 Perform pre -spud derrick inspection. Page 1/27 Report Printed: 12/26/2018 operations Summary (with Timelog uepths) 7) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/16/2018 11/16/2018 1.75 MIRU MOVE BHAH P Mobilize BHA components to rig floor. 0.0 0.0 03:45 05:30 Sim-ops/Strap and tally tubulars in pipeshed. PU 4 jts DP and tag bottom at 99' MD. 11/16/2018 11/16/2018 0.75 MIRU MOVE BOPE P Diverter test waived by AOGCC rep 0.0 0.0 05:30 06:15 Lou Laubenstein 11-14-18 @ 08:48 hrs. Tested diverter with a joint of 5" DP . Annular Closing time=41 Sec's. Knife Valve open fully=7 Secs. Drawdown test performed. Initial Psi=3000, After function 1950 Psi, 200 Psi Built in 8 secs. Full PSI= 41 secs. 6 Bottles AVG @ 2183 psi. Test H2S, LEL gas alarms, PVT and flow show. 11/16/2018 11/16/2018 0.75 MIRU MOVE SFTY P Conduct pre spud safety meeting with 0.0 0.0 06:15 07:00 all personnel 11/16/2018 11/16/2018 2.50 MIRU MOVE BHAH P Make up clean out BHA to 40' MD. 0.0 99.0 07:00 09:30 Pick up one stand DP to 99' MD. 11/16/2018 11/16/2018 0.50 MIRU MOVE SEQP P Flood lines. Test lines and surface 99.0 99.0 09:30 10:00 equipment to 3500 psi. Good test. 11/16/2018 11/16/2018 0.25 MIRU MOVE DRLG P Clean out conductor from 99' MD to 99.0 119.0 10:00 10:15 119' MD. 450 gpm, 530 psi, 30% FO, 4K tq, PU 57K SO 56K Rot 55K. 11/16/2018 11/16/2018 2.25 MIRU MOVE BHAH P Stand back DP. Make up BHA #1. 119.0 119.0 10:15 12:30 11/16/2018 11/16/2018 4.00 SURFAC DRILL DDRL P Directional drill 13 1/2" surface hole 119.0 303.0 12:30 16:30 section from 119' MD to 303' MD, 303' TVD, 451 gpm, 740 psi, FO 24%, 45 rpm, Tq 2K, WOB 8K, OFF BTM 540 psi, PU 58K, SO 65K, ROT 65K, Tq 13K, ADT 1.6 hrs, Bit hrs=1.6, Jars hrs=N/A. Total footage 184'. 11/16/2018 11/16/2018 2.00 SURFAC DRILL BHAH P POOH standing back HWDP. Make up 303.0 303.0 16:30 18:30 remainder of BHA #1 to 303' MD. 11/16/2018 11/16/2018 1.00 SURFAC DRILL BHAH T Gas alarms malfunctioning. POOH 303.0 93.0 18:30 19:30 with BHA from 303' MD to 93' MD. 11/16/2018 11/16/2018 2.50 SURFAC DRILL RGRP T Troubleshoot rig floor gas sensors. 93.0 93.0 19:30 22:00 Sim-ops/Load DP into pipeshed. Replace damaged jet line valve in mezzanine. 11/16/2018 11/16/2018 1.50 SURFAC DRILL BHAH T RIH with BHA#1 from 93' MD to 303' 93.0 303.0 22:00 23:30 MD. Circulate and test gas alarm system. 450 gpm, 640 psi, 40 rpm,23% FO 11/16/2018 11/17/2018 0.50 SURFAC DRILL SVRG P Service rig. 303.0 303.0 23:30 00:00 11/17/2018 11/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13 1/2" surface hole 303.0 841.0 00:00 06:00 section from 303' MD to 841' MD, 839' TVD, 500 gpm, 1147 psi, FO 31%, 50 rpm, Tq 5K, WOB 15K, OFF BTM 830 psi, PU 79K, SO 87K, ROT 83K, Tq 2K, Max Gas 25 units. ADT= 2.86 hrs, AST= .64 Bit hrs=4.45, Jars hrs=91.56. Total footage 536'. Page 2/27 Report Printed: 12/26/2018 uperations Summary (with Timelog Uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/17/2018 11/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13 1/2" surface hole 841.0 1,411.0 06:00 12:00 section from 841' MD to 1411' MD, 1393' TVD, 500 gpm, 1270 psi, FO 28%, 50 rpm, Tq 6K, WOB 15K, OFF BTM 965 psi, PU 91 K, SO 96K, ROT 92K, Tq 2K, Max Gas 25 units. ADT= 2.55 hrs, AST= 1.27 Bit hrs=7, Jars hrs=94.11. Total footage 570'. 11/17/2018 11/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13 1/2" surface hole 1,411.0 1,878.0 12:00 18:00 section from 1411' MD to 1878' MD, 1813' TVD, 550 gpm. 1420 psi, FO 30%, 50 rpm, Tq 6.5K, WOB 9K, OFF BTM 1275 psi, PU 135K, SO 100K, ROT 103K, Tq 1.8K, Max Gas 65 units. ADT= 2.92 hrs, AST= .98 Bit hrs=9.92, Jars hrs=97.03. Total footage 467'. Rig on high line power at 16:40 hrs 11/17/2018 11/18/2018 6.00 SURFAC DRILL DDRL P Directional drill 13 1/2" surface hole 1,878.0 2,465.0 18:00 00:00 section from 1878' MD to 2465' MD, 2294' TVD, 600 gpm, 1663 psi, FO 32%, 50 rpm, Tq 7K, WOB 12K, OFF BTM 1455 psi, PU 116K, SO 108K, ROT 106K, Tq 3K, Max Gas 78 units. ADT= 2.75 hrs, AST= 1.53 Bit hrs=12.67, Jars hrs=99.78. Total footage 587'. 11/18/2018 11/18/2018 6.00 SURFAC DRILL DDRL P Directional drill 13 1/2" surface hole 2,465.0 2,974.0 00:00 06:00 section from 2465' MD to 2974' MD, 2488' TVD, 600 gpm, 1760 psi, FO 32%, 50 rpm, Tq 9K, WOB 14K, OFF BTM 1538 psi, PU 126K, SO 101K, ROT 105K, Tq 5K, Max Gas 560 units. ADT= 3.65 hrs, AST= 2.24 Bit hrs=16.32, Jars hrs=103.43. Total footage 509'. 11/18/2018 11/18/2018 5.00 SURFAC DRILL DDRL P Directional drill 13 1/2" surface hole 2,974.0 3,578.0 06:00 11:00 section from 2974' MD to 3578' MD, 2638' TVD, 700 gpm, 2390 psi, FO 34%, 60 rpm. Tq 8K, WOB 14K, OFF BTM 2105 psi, PU 117K, SO 99K, ROT 104K, Tq 5K, Max Gas 658 units. ADT= 2.86 hrs, AST= .35 Bit hrs=19.63, Jars hrs=106.74. Total footage 604'. 11/18/2018 11/18/2018 1.00 SURFAC CASING CIRC P Obtain survey and torque and drag. 3,578.0 3,492.0 11:00 12:00 CBU while BROOH from 3578' MD to 3492' MD. 700 gpm, 2055 psi, 43% FO with flow line jets running, 60 rpm, 5.5K tq. Total 6935 strokes pumped. 11/18/2018 11/18/2018 0.50 SURFAC CASING OWFF P Monitor well. Static. 3,492.0 3,492.0 12:00 12:30 Page 3/27 Report Printed: 1 2/2 612 01 8 Operations Summary (with Timelog Depths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WS) End Depth (ftKB) 11/18/2018 11/18/2018 8.50 SURFAC CASING BKRM P BROOH from 3492' MD to 1697' MD. 3,492.0 1,697.0 12:30 21:00 700 gpm, 1875 psi, 39% FO with flow line jets running, 60 rpm, 4K tq. PU 104K SO 97K 11/18/2018 11/18/2018 1.25 SURFAC CASING BKRM P BROOH from 1697' MD to 1507' MD 1,697.0 1,507.0 21:00 22:15 circulating 1 bottoms up per stand. 700 gpm, 1616 psi, 39% FO with jets on. 60 rpm, 2K tq. PU 97K SO 94K- 11/18/2018 11/19/2018 1.75 SURFAC CASING TRIP P OWFF/5 mins. POOH on elevators 1,507.0 562.0 22:15 00:00 from 1507' MD to 562' MD. Monitor displacement on pit #1. 11/19/2018 11/19/2018 4.00 SURFAC CASING BHAH P Lay down BHA as per SLB DD. 562.0 0.0 00:00 04:00 11/19/2018 11/19/2018 0.75 SURFAC CASING BHAH P Clean and clear rig floor. 0.0 0.0 04:00 04:45 11/19/2018 11/19/2018 0.75 SURFAC CASING RURD P Rig up to run 10 3/4" casing. 0.0 0.0 04:45 05:30 11/19/2018 11/19/2018 0.50 SURFAC CASING SVRG P Service rig. Lube washpipe and 0.0 0.0 05:30 06:00 traveling blocks 11/19/2018 11/19/2018 7.00 SURFAC CASING PUTB P Verify pipe count in pipe shed. Make 0.0 1,859.0 06:00 13:00 up 10 3/4" shoe track as per running order to 174' MD. Fill pipe and check floats. RIH picking up 10 3/4" 45# L-80 HYD 563 casing to 1859' MD. Joints 4 through 19 are doped pipe and remainder is dopeless. Torque doped connections to 16.21K ft/lbs and dopeless connections to 23K ft/lbs. SO 67K 11/19/2018 11/19/2018 1.50 SURFAC CASING CIRC P Circulate and condition mud while 1,859.0 1,896.0 13:00 14:30 reciprocating from 1859' MD to 1896' MD. Stage pump rate up to 7 bpm, 160 psi, 16% FO. 4394 total strokes pumped with 2500 strokes at 6-7 bpm. PU 120K SO 107K 11/19/2018 11/19/2018 1.50 SURFAC CASING PUTB P RIH picking up 10 3/4" 45# L-80 HYD1,896.0 2,627.0 14:30 16:00 563 casing from 1896' MD to 2627' MD. SO 110K. 11/19/2018 11/19/2018 0.50 SURFAC CASING CIRC P Circulate and condition mud while 2,627.0 2,668.0 16:00 16:30 reciprocating from 2627 MD to 2668' MD. Stage pump rate up to 6 bpm, 185 psi, 19% FO. 1000 total strokes pumped at 6 bpm. PU 135K SO 115K. 11/19/2018 11/19/2018 2.00 SURFAC CASING PUTB P RIH picking up 10 3/4" 45# L-80 HYD 2,668.0 3,526.0 16:30 18:30 563 casing from 2668' MD to 3526' MD. PU 179K SO 110K. 11/19/2018 11/19/2018 0.50 SURFAC CASING HOSO P Make up hanger & landing joint as per 3,526.0 3,571.0 18:30 19:00 FMC Tech. & continue in the hole from 3526 to 3571' MD, PU 179K, SO 119K. 11/19/2018 11/19/2018 0.75 SURFAC CEMENT CIRC P Circulate and condition mud for 3,571.0 3,571.0 19:00 19:45 cement job. Reciprocate 20' strokes. Stage pump rate up to 5 bpm. 1800 strokes pumped. 11/19/2018 11/19/2018 0.75 SURFAC CEMENT RURD P Rig up cement lines. 3,571.0 3,571.0 19:45 20:30 11/19/2018 11/19/2018 2.00 SURFAC CEMENT CIRC P Circulate and condition mud for 3,571.0 3,571.0 20:30 22:30 cement job. Reciprocate 20' strokes. Stage pump rate up to 8 bpm. 11300 strokes pumped. Sim-ops/Conduct PJSM on cement job while circulating. Page 4/27 Report Printed: 1 212 6/2 01 8 Operations Summary (with Timelog Depths) 2S-315 oil's Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/19/2018 11/20/2018 1.50 SURFAC CEMENT CMNT P Line up & SLB pump 5 bbls water. 3,571.0 3,571.0 22:30 00:00 Pressure test lines to 3500 psi, good. Pump 40.2 bbls of CW100 @ 4.8 bpm, 153 psi, FO 14%, PU 170K, SO 125K, Pump 78.4 bbls of 10.5 ppg MP II @ 4.5 bpm, 116 psi, FO 12%. Drop bottom plug & start batching lead. Pump 35 bbls of 11.0 ppg lead cement 5 bpm, 150 psi, 14% FO. 11/20/2018 11/20/2018 2.00 SURFAC CEMENT CMNT P Dowell continue pumping a total of 3,571.0 0.0 00:00 02:00 488.5 bbls of 11.0 ppg lead cement@ 5.3-5.8 bpm w/ 120- to 238 psi 5.3- 5.8 bpm, 150 psi, 14-17% FO. Batch tail cement, Pump 63.3 bbls @ 3-5.1 bpm w/ 132-350 psi w/ 10-16% flow out. Mud push at surface w/ 10 bbls of tail pumped. Set on hanger w/ 20 bbls of tail pumped, Last Pickup wt 200k, slack off weight of 62k. 11/20/2018 11/20/2018 1.00 SURFAC CEMENT CMNT P Drop top plug. Dowell kick out plug w/ 0.0 0.0 02:00 03:00 10.2 bbls of water, Rig displaced cement w/ 9.6 ppg mud.lnitial pump rate of 8 bpm w/ 498 psi, returns interface thick after pumping 50 bbls and slowed to 4 bpm w/ 185 psi. Able to continue at 8 bpm after good 11 ppg returns at surface after 84.5 bbls of mud pumped, and raised rate back up to 8 bpm w/ 540- 1040 psi, pumping 272 bbls, loss of returns, slowed rate to 6 bpm, then 5 bpm w/ 880-914 psi, slowed to 3 bpm at 310 bbls pumped. and bumped plug after pumping 325 bbls. Pressured to 1600 psi, held 5 minutes, bled off pressure and floats held. CIP 0300 hrs 11/20/2018. 170.5 bbls of 11 ppg cement circulated out of well. Lost 70 bbls total during job. Hole static while holding pressure on float. 11/20/2018 11/20/2018 0.50 SURFAC CEMENT OWFF P Monitor well -static. Sim Ops:Rig down 0.0 0.0 03:00 03:30 pumping lines. 11/20/2018 11/20/2018 0.50 SURFAC CEMENT RURD P Drain stack. Rig down casing running 0.0 0.0 03:30 04:00 tool. 11/20/2018 11/20/2018 0.50 SURFAC CEMENT RURD P Drainstack, break and lay down FMC 0.0 0.0 04:00 04:30 10-3/4" landing joint. 11/20/2018 11/20/2018 1.50 SURFAC CEMENT WWWH P Make up stack washing tool. Wash 0.0 0.0 04:30 06:00 stack and riser w/ black water pill, pumping 675 gpm. Work 20" annular three times. Lay down stack washing tool. Blow down top drive. Service cement valves. Begin cleaning pits. 11/20/2018 11/20/2018 1.00 SURFAC CEMENT RURD P Clear and clean floor: Lay down GBR 0.0 0.0 06:00 07:00 casing running tool. Clean out mud/cuttings in flow box. 11/20/2018 11/20/2018 4.00 SURFAC CEMENT NUND P Lay down riser and mousehole. 0.0 0.0 07:00 11:00 Remove bell nipple, Nipple down 20" annular and diverter tee, lay down same. Remove FMC diverter adapter. 11/20/2018 11/20/2018 1.00 SURFAC WHDBOP WWWH P Clean cement from flutes on hanger 0.0 0.0 11:00 12:00 and top of hanger. Top of cement 2.4' below bottom of flutes (Cut on conductor). Nipple up FMC wellhead assembly. Page 5/27 Report Printed: 12/26/2018 Operations Summary (with Timelog Depths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/20/2018 11/20/2018 2.00 SURFAC WHDBOP NUND P N/U & orient well head, Obtain RKB's 0.0 0.0 12:00 14:00 (Top of well head - 35.44', ULDS - 35.57', LLDS - 37.80') Test seals to 1000 psi for 10 min and witnessed by CPAI rep. 11/20/2018 11/20/2018 4.00 SURFAC WHDBOP NUND P N/U adaptor and extensions, Pick and 0.0 0.0 14:00 18:00 set BOP stack, Torque all flanges, N/U RCD head and set trip nipple, for measurements N/D and sent to shop for extension, (2" to short) 11/20/2018 11/20/2018 5.50 SURFAC WHDBOP NUND P Continue torqing all flanges, Hook up 0.0 0.0 18:00 23:30 Kill and Choke lines, Set trip nipple and bring up BOP test equipment to rig floor. 11/20/2018 11/21/2018 0.50 SURFAC WHDBOP BOPE P R/U and test BOPE with 5" test joint, 0.0 0.0 23:30 00:00 Test 1- Choke maniflod valve 1,12,13,14 and 4" Kill line on mud manifold, 4-1/2 IF Dart Valve. Test 2 - Top Rams Choke manifold with valves 9 & 11, Mezz. Kill line and 41/2 IF FOSV. (Test witnessed by Alaska State Rep.Adam Earl) 11/21/2018 11/21/2018 3.50 SURFAC WHDBOP BOPE P Cont. testing BOPE, test -3: Choke 0.0 0.0 00:00 03:30 manifold valves 8,10 and HCR Kill. Test-4:valves 6 and 7. Test-5:Super choke manual choke, test to 2000 psi. Test -6: Choke manifold valves 2 and 5, Manual Kill. Test -7: HCR choke and upper IBOP valve. Test -8: Manual choke and lower IBOP valve. Test -9: Lower rams and perform Koomey draw down test. Test - 10: Blinds choke manifold valves 3,4 and 6. All tested to 250 low and 3500 high and hold each for 5 min. 11/21/2018 11/21/2018 2.50 SURFAC WHDBOP RURD P Clean and clear rig floor, R/D BOP test 0.0 0.0 03:30 06:00 equipment and R/U to test MPD equipment Test to 500 psi low and 1200 psi high and hold each test for 5 min. Wear ring on rig floor with 9-7/8" ID 11/21/2018 11/21/2018 1.00 SURFAC WHDBOP MPDA P Pull MPD test cap and install trip 0.0 0.0 06:00 07:00 1 nipple Pull test plug and drain stack. 11/21/2018 11/21/2018 1.50 SURFAC CEMENT RURD P Install wear ring, RILDS X 2 ID = 9- 0.0 0.0 07:00 08:30 13/16" OD = 10-3/4" Lenght 2.17' Mobilize BHA to rig floor.(SIMOPS) remove 3.5" tbg from shed and load, strap and tally 5" dp. 11/21/2018 11/21/2018 1.00 SURFAC CEMENT BHAH P M/U 9-7/8" Clean Out BHA to 303' 0.0 303.0 08:30 09:30 MD, Monitordisplacement via Trip tank. 11/21/2018 11/21/2018 2.50 SURFAC CEMENT PULD P RIH picking up sinlges from shed F/ 303.0 2,196.0 09:30 12:00 303'T/ 2196' MD, P/U= 85K, S/O= 79K 11/21/2018 11/21/2018 0.50 SURFAC CEMENT CIRC P Fill Pipe staging pumps up to 8 -BPM 2,196.0 2,196.0 12:00 12:30 with 270 psi, Blow down top drive and lines. 11/21/2018 11/21/2018 1.50 SURFAC CEMENT PULD P Continue single in hole F/ 2196' 2,196.0 3,332.0 12:30 14:00 T/3332' MD 11/21/2018 11/21/2018 1.00 SURFAC CEMENT CIRC P CBU staging pumps up to 337 gpm, 3,332.0 3,332.0 14:00 15:00 295 psi, circ 2700 strokes, P/U=113K, S/O= 86K, ROT= 102K, 6K torque B/D top drive. Page 6/27 ReportPrinted: 12/26/2018 Operations Summary (with Timelog Depths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/21/2018 11/21/2018 1.00 SURFAC CEMENT PRTS P Rig up to test casing @ 3332' MD, 3,332.0 3,332.0 15:00 16:00 tested 10-3/4" casing and lower inside OA valve, test to 3000 psi for 30 min and charted same. R/D test equipment and blow down same. 11/21/2018 11/21/2018 2.00 SURFAC CEMENT COCF P Wash down @ 4 bpm to 3435' MD, 3,332.0 3,518.0 16:00 18:00 Tag TOC @ 3474' MD with 399 gpm and 460 psi, 24% F/0, 80 rpms 6K torque. Drill out cement with 399 gpm 493 psi, 24% F/0, 80 rpms and 7K torque with 5K WOB, drillplugs @ 216 gpm 230 psi, 17% F/0, 60 rpms 6-1 OK & 18-22 WOB. Drill FC with 400 gpm 400 psi, 24% F/0, with 80 rpms 22-25K WOB, Drill cement to 3518' MD with 504 gpm, 660 psi, 28% F/0, 80 rpm, 7-9K WOB, 20K torque, TOC @ 3474' MD, Plugs @ 3478' MD F/C @ 3480' MD 11/21/2018 11/21/2018 1.00 SURFAC CEMENT COCF P Continue to drill cement F/ 3518'T/ 3,518.0 3,571.0 18:00 19:00 3568' MD with 500 gpm, 643 psi, 29% F/O, 80 rpm and 10 K WOB. Drill float shoe F/ 3568 T/ 3571' MD, 500 gpm, 653 psi, 29% F/0, 80 rpm 10-20K WOB. 11/21/2018 11/21/2018 0.50 SURFAC CEMENT DDRL P Drill F/ 3571'T/ 3598' MD, 500 gpm, 3,571.0 3,598.0 19:00 19:30 650 psi, 28% F/0, 80 rpm, 20K WOB. 11/21/2018 11/21/2018 1.00 SURFAC CEMENT CIRC P Circ. and cond. mud for FIT test 9.6 3,598.0 3,598.0 19:30 20:30 ppg in and out. 11/21/2018 11/21/2018 2.00 SURFAC CEMENT LOT P Rig up and perform FIT, EMW 13.5 3,598.0 3,598.0 20:30 22:30 ppg with 535 psi, bled back .8 bbls to trip tank..Rig down. 11/21/2018 11/21/2018 0.50 PROD1 DRILL OWFF P Blow down top drive and Monitor well 3,598.0 3,598.0 22:30 23:00 11/21/2018 11/22/2018 1.00 PROD1 DRILL TRIP P POOH F/3522' T/ 2670' MD, rack pipe 3,598.0 2,670.0 23:00 00:00 in derrick, Monitor well via Trip Tank. 11/22/2018 11/22/2018 0.50 PROD1 DRILL TRIP P POOH F/2670' T/1439' MD 2,670.0 1,439.0 00:00 00:30 11/22/2018 11/22/2018 1.00 PROD1 DRILL TRIP T Improper hole fill, switch from trip tank 1,439.0 1,439.0 00:30 01:30 to pit 1 and trnsfer pump to fill hole, Pump with MP1 to fill hole, Then R/U to top fill hole and monitor hole via pit # 1. ( Trip nipple was not lined up correctly to fill hole) 11/22/2018 11/22/2018 2.25 PROD1 DRILL BHAH P Cont. to POOH F/ 1439'to surface, 1,439.0 0.0 01:30 03:45 stand back pipe in derrick, L/D BHA # 2. 11/22/2018 11/22/2018 0.75 PROD1 DRILL BHAH P Clear and clean off rig floor of BHA # 0.0 0.0 03:45 04:30 2. (SIMOPS) adjust trip nipple for proper hole filling. Bring up tools and stage on rig floor for BHA# 3 11/22/2018 11/22/2018 1.50 PROD1 DRILL BHAH P PJSM and P/U BHA # 3 T/ 111' MD 0.0 111.0 04:30 06:00 11/22/2018 11/22/2018 1.50 PROD1 DRILL PULD P PJSM, Load sources, Cont. to M/U 111.0 431.0 06:00 07:30 8.5" X 9-7/8" BHA # 3. F/ 11 1' T/ 431' MD, P/U 69K, S/0 76K, Montitor displacement via pit # 1 11/22/2018 11/22/2018 2.25 PROD1 DRILL PULD P RIH picking up singles of 5" dp from 431.0 1,840.0 07:30 09:45 shed F/ 431'T/ 1,840' MD, Monitor displacement via Pit # 1. Page 7/27 Report Printed: 12/26/2018 vperations Summary (with Timelog L,epths) 2S-315 ICA* 111111 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/22/2018 11/22/2018 0.50 PROD1 DRILL DHEQ P Pulse test MWD tools staging pumps 1,840.0 1,840.0 09:45 10:15 up to 450 gpm, 840 psi, 25% F/0, P/U 101 K, S/O 95K, Blow down Top Drive. 11/22/2018 11/22/2018 1.75 PROD1 DRILL PULD P Cont. to RIH picking up singles of 5" 1,840.0 3,551.0 10:15 12:00 dp from shed F/ 1,8401'T/ 3551' MD, Monitor displacement via Pit # 1. 11/22/2018 11/22/2018 0.75 PROD1 DRILL CIRC P Fill pipe & break circ. satging pumps 3,551.0 3,551.0 12:00 12:45 up to227 gpm, 460 psi, 17% F/0, S/0 79K,P/U 119K. 11/22/2018 11/22/2018 0.50 PROD1 DRILL SVRG P Service and inspect Top Drive and 3,551.0 3,551.0 12:45 13:15 Blocks. 11/22/2018 11/22/2018 0.50 PROD1 DRILL CIRC P Stage pumps up and wash to btm F/ 3,551.0 3,598.0 13:15 13:45 3,551'T/ 3598', 207 gpm, 385 psi, 23% F/O. 11/22/2018 11/22/2018 1.75 PROD1 DRILL DDRL P Displace well to 9.2 ppg LSND while 3,598.0 3.740.0 13:45 15:30 control drilling 8.5" hole F/ 3598' T/3740' MD, 2676' TVD, with 480 gpm, 920 psi, 26% F/0, 80 rpm, 6.8K Torque, 6K wob, ECD's 10.09 ppg, off btm 910 psi, P/U 117K, S/O 85K, ROT 96K. 5.4 K torque, Max Gas 49 units.ADT= 1.54 11/22/2018 11/22/2018 1.00 PROD1 DRILL CIRC P With the bit at 3729' MD and Rhino 3,740.0 3,740.0 15:30 16:30 reamer at 3590' MD, activate reamer as per SLB Rep. with positve indication of opening (480 gpm, 926 psi, 26% F/0, TRPM 4000) (At 310 gpm, 467 psi, for 2 min, at 480 gpm. 780 psi, TRPM 3440) Slack off noting 12K reduction in S/O wt F/ 83K T/ 71 K. 11/22/2018 11/22/2018 1.50 PROD1 DRILL DDRL P Control drill 8-1/2" hole F/ 3740'T/ 3.740.0 3,835.0 16:30 18:00 3835' MD, TVD 2702' at 480 gpm, 920 psi, 26% F/0, 80 rpm, 6.8K torque, 6K WOB, ECD's 10.09 ppg, Off btm 910 psi, P/U 113K, S/O 91 K, Rot 103 K. Max gas 51 units, ADT= 3.43 hrs, Bit hrs= 3.43 hrs, Jar hrs= 127.62 hrs. SPR's @ 3641' MD, 2661' TVD, MW= 9.2 ppg, @ 14:20 hrs with reamer shut. MP #1 30 spm= 150 psi, 40 spm= 200 psi. MP #2 30 spm= 150 psi, 40 spm= 200 psi. SPR's @ 3735' MD, 2676' TVD, MW= 9.2 ppg, @ 16:20 with reamer open, MP #1 30 spm= 160 psi, 40 spm= 220 psi. MP #2 30 spm= 160 psi, 40 spm= 220 psi. 11/22/2018 11/23/2018 6.00 PROD1 DRILL DDRL P Cont. to control drill 8.5" hole F/ 3835' 3,835.0 4,311.0 18:00 00:00 T/ 4311' MD, 2821' TVD, @ 650 gpm, 1355 psi, 33% F/0, 110 rpm 9K torque, 20K WOB, ECD's 11. 10, Off btm 1230 psi, P/U 120K, S/O 92K, ROT 103K, 6K torque, Max gas 103 units ADT- 4.22 hrs, bit hrs= 7.64, Jar hrs= 131.84. Page 8/27 Report Printed: 12/26/2018 Operations Summary (with Timelog Depths) 2S-315 .. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/23/2018 11/23/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" Hole F/ 4311' T/4781' MD, 4,311.0 4,781.0 00:00 06:00 2941' TVD, 650 gpm, 1506 psi, 30% F/0, 110 rpm,9K torque, 18K WOB, ECD's 11.77, Off Btm 1366 psi, P/U 124K, SO 95K, Rot 108K, 6K torque, Max Gas 19 units, ADT= 3.26 hrs, Bit hrs = 10.9, Jar hrs= 135.1 11/23/2018 11/23/2018 6.00 PROD1 DRILL DDRL P Control Drill due to high vibration and 4,781.0 5,111.0 06:00 12:00 MWD shocks 8-1/2" X 9-7/8" Hole F/ 478 1' T/ 511 VIVID, 3022' TVD, 650 gpm, 1527 psi, 31 % F/O, 105 rpm, 1 OK torque, ECD's 11.36, Off Btm 1434 psi, P/U 126K, S/O 94K, Rot 108K, 6.5K torque, Max Gas 54 units, ADT= 4.44 hrs, Bit= 15.34 hrs, Jar - 139.54 hrs. Spr's @ 4873' MD, 2964' TVD, MW= 9.5 ppg Hrs= 06:55 MP# 1) 30 spm= 250 psi, 45 spm= 300 psi. MP #2) 30 spm= 230 psi, 40 spm= 280 psi. 11/23/2018 11/23/2018 6.00 PROD1 DRILL DDRL P Control Drill due to high vibration and 5,111.0 5,445.0 12:00 18:00 MWD shocks adjusting parameters as needed, 8-1/2" X 9-7/8" Hole F/ 5111 T/ 5445' MD, 3104' TVD, 650 gpm, 1740 psi, 32% F/0, 120 rpm, 9K torque, ECD's 10.96, Off Btm 1690 psi, P/U 125K, S/O 105K, Rot 114K, 6K torque, Max Gas 29 units, ADT= 4.26 hrs, Bit= 19.60 hrs, Jar= 143.804 hrs. 11/23/2018 11/24/2018 6.00 PROD1 DRILL DDRL P Control drill due to vibration 8-1/2" X 9 5,445.0 5,935.0 18:00 00:00 -7/8" hole F/ 5445'T/ 5935' MD, 3224' TVD, 650 gpm, 1685 psi, 33% F/0, 100 RPM, 7K Torque, 13K WOB, ECD's 11.18, Off Btm 1674 psi,P/U 127K, S/O 108K, Rot 115K, 6K torque, Max Gas 73 units, ADT= 4.80 hrs, Bit= 24.40 hrs, Jar= 148.60 hrs. 11/24/2018 11/24/2018 2.00 PROD1 DRILL DDRL P Control drill due to high vibrations and 5,935.0 6,062.0 00:00 02:00 MWD shocks 8-1/2" X 9-7/8" hole F/ 5935' T/6062' MD, 3265' TVD, 650 gpm, 1717' psi, 32% F/0, 100 rpm, 7K torque, 12K WOB, ECDs= 11.16, Off Btm= 1664 psi, P/U 127K, S/O 108K, ROT 115K, 6K torque, Max Gas 23 units, ADT= 1.30 hrs, Bit hrs 25.70, Jar hrs 149.9. 11/24/2018 11/24/2018 2.00 PROD1 DRILL RGRP T Trouble shoot Top Drive encoder fault 6,062.0 6,062.0 02:00 04:00 11/24/2018 11/24/2018 0.50 PROD1 DRILL SVRG P Service Rig and Top Drive 6,062.0 6,062.0 04:00 04:30 11/24/2018 11/24/2018 1.50 PROD1 DRILL DDRL P Control drill due to high vibrations and 6,062.0 6,154.0 04:30 06:00 MWD shocks 8-1/2" X 9-7/8" hole F/ 6062'T/ 6154 MD, 3278' TVD, 650 gpm, 1714' psi, 31% F/0, 100 rpm, 7.5K torque, 12K WOB, ECDs= 10.91, Off Btm= 1616 psi, P/U 127K, S/0 108K, ROT 115K, 6K torque, Max Gas 46 units, ADT= 1.00 hrs, Bit hrs 26.70, Jar hrs 150.9. 11/24/2018 11/24/2018 2.75 PROD1 DRILL RGRP T Trouble shoot Top Drive encoder fault 6,154.0 6,154.0 06:00 08:45 1 1 I Page 9/27 Report Printed: 12/26/2018 Operations Summary (with Timelog Depths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/24/2018 11/24/2018 1.25 PROD1 DRILL DDRL P Control drill due to high vibrations and 6,154.0 6,249.0 08:45 10:00 MWD shocks 8-1/2" X 9-7/8" hole F/ 6154'T/ 6249' MD, 3302' TVD, 650 gpm, 1750' psi, 31% F/O, 100 rpm, 9K torque, 17K WOB, ECDs= 11.08, Off Btm= 1695 psi, P/U 129K, S/O 112K, ROT 119K, 6K torque, Max Gas 4 units, ADT= .84 hrs, Bit hrs 27.54, Jar hrs 151.74 11/24/2018 11/24/2018 0.50 PROD1 DRILL RGRP T Rack one stand back F/ 6249 T/ 6202' 6,249.0 6,249.0 10:00 10:30 MD to bring Top Drive down thaw out encoder from being frozen, Run stand back in 11/24/2018 11/24/2018 1.25 PROD1 DRILL DDRL P Control drill due to high vibrations and 6,249.0 6,338.0 10:30 11:45 MWD shocks 8-1/2" X 9-7/8" hole F/ 6249'T/ 6338' MD, 3323' TVD, 650 gpm, 1740' psi, 31% F/O, 100 rpm, 9K torque, 18K WOB, ECDs= 11 -25, Off Btm= 1695 psi, P/U 129K, S/O 112K, ROT 119K, 6K torque, Max Gas 4 units, ADT= .85 hrs. Bit hrs 28.39. Jar hrs 152.59 (Total losses for tour 20 bbl) 11/24/2018 11/24/2018 0.75 PROD1 DRILL RGRP T Trouble shoot Top Drive encoder fault 6,338.0 6,338.0 11:45 12:30 11/24/2018 11/24/2018 3.50 PROD1 DRILL DDRL P Control drill due to high vibrations and 6,338.0 6,625.0 12:30 16:00 MWD shocks 8-1/2" X 9-7/8" hole F/ 6338'T/ 6625' MD, 3395' TVD, 650 gpm, 1972' psi, 31% F/O, 105 rpm,10K torque, 22K WOB, ECDs= 11.75, Off Btm= 1875 psi, P/U 129K, S/O 108K, ROT 116K, 6K torque, Max Gas 11 units, ADT= .2.545 hrs, Bit hrs 30.93, Jar hrs 155.13 11/24/2018 11/24/2018 0.50 PROD1 DRILL SVRG P Service Top Drive 6,625.0 6,625.0 16:00 16:30 11/24/2018 11/24/2018 1.50 PROD1 DRILL DDRL P Control drill due to high vibrations and 6,625.0 6,770.0 16:30 18:00 MWD shocks 8-1/2" X 9-7/8" hole F/ 66625'T/ 6770' MD, 3431' TVD, 650 gpm, 2000' psi. 31 % F/O, 110 rpm, 10.5K torque, 22K WOB, ECDs= 11.78, Off Btm= 1940 psi, P/U 132K, S/O 109K, ROT 117K, 6.5K torque, Max Gas 11 units, ADT= .1.16 hrs, Bit hrs 32.09, Jar hrs 156.29 11/24/2018 11/25/2018 6.00 PROD1 DRILL DDRL P Control drill due to high vibrations and 6,770.0 7.260.0 18:00 00:00 MWD shocks 8-1/2" X 9-7/8" hole F/6770' T/ 7260' MD, 3552' TVD, 650 gpm, 2045' psi, 31% F/O, 110 rpm, 1OK torque, 25K WOB, ECDs= 11.43, Off Btm= 1936 psi, P/U 135K, S/O 110K, ROT 117K, 7K torque, Max Gas 45 units, ADT= .4.15 hrs, Bit hrs 36.24, Jar hrs 160.44, (Total losses for tour 29 bbls.) 11/25/2018 11/25/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/7260' T/ 7,260.0 7,621.0 00:00 06:00 7621' MD. 3638' TVD, 650 gpm, 2130' psi, 31 % F/O, 130 rpm,1 OK torque, 29K WOB, ECDs= 11.69, Off Btm= 1936 psi, P/U 140K, S/O 120K, ROT 110K, 6K torque, Max Gas 27 units, ADT= .5.84 hrs, Bit hrs 42.08, Jar hrs 166.28. Page 10127 Report Printed: 12/26/2018 operations Summary (with Timelog Uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/25/2018 11/25/2018 1.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/7621' T/ 7,621.0 7,666.0 06:00 07:00 7666' MD, 3653' TVD, 650 gpm, 2230' psi, 32% F/O, 140 rpm, 1OK torque, 28K WOB, ECDs= 11.70, Off Btm= 2100 psi, P/U 140K, S/O 100K, ROT 120K, 6K torque, Max Gas 9 units, ADT= .1.09 hrs, Bit hrs 43.17, Jar hrs 167.37 11/25/2018 11/25/2018 0.50 PROD1 DRILL SVRG P Service Top Drive 7,666.0 7,666.0 07:00 07:30 11/25/2018 11/25/2018 0.25 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/7666' T/ 7,666.0 7,672.0 07:30 07:45 7672' MD, 3655' TVD, 650 gpm, 1970' psi, 30% F/O, 130 rpm,8.5K torque, 25K WOB, ECDs= 11 A0, Off Btm= 2100 psi, P/U 140K, S/O 110K, ROT 120K, 6K torque, Max Gas 9 units, ADT= .0.20 hrs, Bit hrs 43.37, Jar hrs 167.67 11/25/2018 11/25/2018 0.75 PROD1 DRILL RGRP T Install Insulation on top of encoder 7,672.0 7,672.0 07:45 08:30 and secure guard. 11/25/2018 11/25/2018 3.50 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/7672' T/ 7,672.0 7,811.0 08:30 12:00 7811 MD, 3685' TVD, 650 gpm, 1980' psi, 30% F/O, 130 rpm, 10K torque, 30K WOB, ECDs= 11.40, Off Btm= 1850 psi, P/U 145K, S/O 116K, ROT 127K, 11 K torque, Max Gas 11 units, ADT= .2.35 hrs, Bit hrs 45.72, Jar hrs 169.92 SPR's @ 7713' MD, 3666' TVD, MW= 9.2 ppg, hrs= 09:40 MP #1) 30 spm= 160 psi, 40 spm= 240 psi MP #2) 30 spm= 160 psi, 40 spm= 240 ps 11/25/2018 11/25/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/7811' T/ 7,811.0 8,126.0 12:00 18:00 8126 MD, 3768 TVD, 650 gpm, 1980' psi, 30% F/O, 130 rpm, 10K torque, 30K WOB, ECDs= 11.40, Off Btm= 1850 psi, P/U 145K, S/O 116K, ROT 127K, 11 K torque, Max Gas 11 units, ADT= 5.11 hrs, Bit hrs 50.83, Jar hrs 175.03 11/25/2018 11/26/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/8126' T/ 8,126.0 8,568.0 18:00 00:00 8568' MD, 3768 TVD, 650 gpm, 1980' psi, 31 % F/O, 145 rpm, 12K torque, 30K WOB, ECDs= 11.80, Off Btm= 2140 psi, P/U 139K, S/O 114K, ROT 123K, 7K torque, Max Gas 34 units, ADT= 4.63 hrs, Bit hrs 55.46, Jar hrs 179.66 SPR's @ 8189' MD, 3783' TVD, MW= 9.2 ppg, hrs= 19:00 MP #1) 30 spm= 270 psi, 40 spm= 340 psi MP #2) 30 spm= 270 psi, 40 spm= 340 ps 11/26/2018 11/26/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/8568' 8,568.0 9,041.0 00:00 06:00 T/9041' MD, 3993' TVD, 650 gpm, 2356 psi, 31 % F/O, 145 rpm, 12.7K torque, 30K WOB, ECDs= 12.03, Off Btm= 2214 psi, P/U 155, S/O 114K, ROT 128K, 8.1 K torque, Max Gas 30 units, ADT= 3.95 hrs, Bit hrs 59.41, Jar hrs 183.47 Page 11/27 Report Printed: 12/26/2018 uperations Summary (with Timelog uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/26/2018 11/26/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/9041' 9,041.0 9,488.0 06:00 12:00 T/9488' MD, 4103' TVD, 700 gpm, 2665 psi, 32% F/0, 145 rpm, 12K torque, 26K WOB, ECDs= 12,.25 Off Btm= 2530 psi, P/U 162 S/O 118K, ROT 133K, 9K torque, Max Gas 18 units, ADT= 4.86 hrs, Bit hrs 64.27, Jar hrs 188.47 SPR's @ 9136' MD, 4016' TVD, MW= 9.2+ Hours= 07:30 MP1) 30 spm= 300 psi, 40 spm= 380 psi MP2) 30 spm= 300 psi, 40 spm= 380 psi. 11/26/2018 11/26/2018 2.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/9488' 9,488.0 9,585.0 12:00 14:00 T/9585' MD, 4128' TVD, 700 gpm, 2555 psi, 32% F/0,145 rpm, 12K torque, 26K WOB, ECDs= 11.91, Off Btm= 2480 psi, P/U 162 S/0 118K, ROT 133K, 9K torque, Max Gas 18 units, ADT= 1.48 hrs, Bit hrs 65.75, Jar hrs 189.95 11/26/2018 11/26/2018 1.00 PROD1 DRILL OWFF T Monitor well for 30 min, due to 56 bbl 9,585.0 9,585.0 14:00 15:00 loss in 30 min,Observed intial flow back with diminishing trend to static (40 bbl flowed back) circ @ 650 gpm untill LCM was put in the pits. 11/26/2018 11/26/2018 3.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/9585' 9,585.0 9,773.0 15:00 18:00 T/9773' MD, 4172' TVD, 650 gpm, 2300 psi, 31% F/0,130 rpm, 13K torque, 24K WOB, ECDs= 11.60, Off Btm= 2220 psi, P/U 162 S/0 118K, ROT 133K, 9K torque, Max Gas 18 units, ADT= 2.43 hrs, Bit hrs 68.18, Jar hrs 192.38 11/26/2018 11/26/2018 4.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole F/9773' 9,773.0 10,018.0 18:00 22:00 T/10,018' MD, 4172' TVD, 650 gpm, 2300 psi, 31% F/0,130 rpm, 13K torque, 24K WOB, ECDs= 11.1.70, Off Btm= 2220 psi, P/U 162 S/O 116K, ROT 13K, 9K torque, Max Gas 18 units, ADT= 3.31 hrs, Bit hrs 71.49, Jar hrs 195.69 11/26/2018 11/27/2018 2.00 PROD1 DRILL REAM P Back ream F/ 10,018'T/9841" with 10,018.0 9,841.0 22:00 00:00 647 gpm, 2150 psi, 9K torque, 120K rotating up weight with 30% flow. SPR's @10,018' MD 4230' TVD, MW= 9.3 ppg, Hours = 22:00 MP1) 30 spm= 325 psi, 40 spm= 400 psi MP2) 30 spm= 325, 40 spm= 400 psi. 11/27/2018 11/27/2018 1.50 PROD1 DRILL BKRM P Back ream from 9841' MD to 9706' 9,841.0 9,706.0 00:00 01:30 MD with 647 gpm, 2050 psi, 9K torque, 120K rotating up weight with 30% flow. Close underreamer 11/27/2018 11/27/2018 1.25 PROD1 DRILL OWFF T Monitor well. Slight flow at .097 bph 9,706.0 9,706.0 01:30 02:45 diminishing to .054 bph. 11/27/2018 11/27/2018 0.75 PROD1 DRILL TRIP P POOH on elevators from 9706' MD to 9,706.0 9,233.0 02:45 03:30 9233' MD. PU 153K SO 108K. 11/27/2018 11/27/2018 1.25 PROD1 DRILL TRIP T Phase 3 conditions declared for KRU 9,233.0 9,990.0 03:30 04:45 field wide. RIH on elevators from 9233' MD to 9990' MD. PU 153K SO 108K. Page 12/27 Report Printed: 12/26/2018 Uperations Summary (with Timelog Uepths) 2S-315 . . Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 11/27/2018 11/27/2018 6.75 PROD1 DRILL CIRC T Circulate. Rotate and reciprocate from 9,990.0 9,990.0 04:45 11:30 9985' MD to 9890' MD. 600 gpm, 2175 psi, 29% FO, 60 rpm, 9K tq. PU 160K S0117K SPR's @9885 MD 4233' TVD, MW= 9.2+ ppg, Hours = 11:05 MP1) 30 spm= 280 psi, 40 spm= 360 psi MP2) 30 spm= 280 psi, 40 spm= 360 psi. 11/27/2018 11/27/2018 0.50 PROD1 DRILL OWFF T Monitor well. Static. 9,990.0 9,990.0 11:30 12:00 11/27/2018 11/27/2018 1.00 PROD1 DRILL TRIP T POOH on elevators from 9990' MD to 9,990.0 9,040.0 12:00 13:00 9040' MD. PU 155K SO 113K. 11/27/2018 11/27/2018 0.50 PROD1 DRILL CIRC P Pump 20 bbl dry job. Blow down TD. 9,040.0 9,040.0 13:00 13:30 11/27/2018 11/27/2018 2.75 PROD1 DRILL TRIP P POOH on elevators from 9040' MD to 9,040.0 3,554.0 13:30 16:15 3554' MD. PU 106K SO 99K. 11/27/2018 11/27/2018 1.25 PROD1 DRILL CIRC P CBU. Reciprocate from 3554' MD to 3,554.0 3,554.0 16:15 17:30 3459' MD. Stage pump rate up to 550 gpm, 1125 psi, 27% FO. Blow down TD. 11/27/2018 11/27/2018 0.25 PROD1 DRILL OWFF P Monitor well. Static. 3,554.0 3,554.0 17:30 17:45 11/27/2018 11/27/2018 2.25 PROD1 DRILL TRIP P POOH on elevators from 3554' MD to 3,554.0 431.0 17:45 20:00 431' MD. 11/27/2018 11/27/2018 2.50 PROD1 DRILL BHAH P Lay down BHA #3 431.0 0.0 20:00 22:30 11/27/2018 11/27/2018 0.50 PROD1 DRILL BHAH P Clean and clear rig floor 0.0 0.0 22:30 23:00 11/27/2018 11/28/2018 1.00 PROD1 WHDBOP RURD P Pull wear ring and set test plug. Rig up 0.0 0.0 23:00 00:00 to test BOPE. Change out test plug seal. 11/28/2018 11/28/2018 4.00 PROD1 WHDBOP BOPE P Test BOPE with 5" test joint, Test 1- 0.0 0.0 00:00 04:00 Annular preventer, Choke maniflod valve 1,12,13,14 and 4" Kill line on mud manifold, 4-1/2 IF Dart Valve. Test 2- Top Rams Choke manifold with valves 9 & 11, Mezz. Kill line and 41/2 IF FOSW Test -3: Choke manifold valves 8,10 and HCR Kill. Test - 4:valves 6 and 7. Test-5:Super choke manual choke, test to 2000 psi. Test -6: Choke manifold valves 2 and 5, Manual Kill. Test -7: HCR choke and upper IBOP valve. Test -8: Manual choke and lower IBOP valve. Test -9: Lower rams and perform Koomey draw down test. Starting psi= 2950 psi, after closure= 1800 psi, 200 psi attained= 7sec, full pressure attained=48 sec. 6 nitrogen bottles at 2130 psi., Test - 10: Blinds choke manifold valves 3,4 and 6. All tested to 250 low and 3500 high and hold each for 5 min. (Test witness waived by AOGCC Rep Jeff Jones) 11/28/2018 11/28/2018 0.50 PROD1 WHDBOP RURD P Rig down test equipment. Blow down 0.0 0.0 04:00 04:30 1 1 I I lines. Page 13/27 Report Printed: 12/26/2018 uperations Summary (with Timelog vepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/28/2018 11/28/2018 1.00 PROD1 DRILL RURD T Attempt to set wear ring. Wear ring 0.0 0.0 04:30 05:30 would not seat at proper depth. Pull wear ring and flush out well head. Clean wear ring. Makeup upper wear ring and seat at proper depth. Pull upper wear ring and attempt to set lower wear ring. Would not seat at proper depth. Pull wear ring. 11/28/2018 11/28/2018 0.50 PROD1 DRILL BHAH P Make up BHA in mousehole. 0.0 0.0 05:30 06:00 11/28/2018 11/28/2018 0.50 PROD1 DRILL SVRG P Service top drive and traveling blocks. 0.0 0.0 06:00 06:30 Verify drillpipe count in pipe shed. 11/28/2018 11/28/2018 0.50 PROD1 DRILL RURD P Install 9 15/16" ID wear ring. 0.0 0.0 06:30 07:00 11/28/2018 11/28/2018 3.75 PROD1 DRILL BHAH P Make up BHA#4 as per SLB DD. PU 0.0 504.0 07:00 10:45 78K SO 82K 11/28/2018 11/28/2018 1.25 PROD1 DRILL PULD P RIH picking up 5' drill pipe from 504' 504.0 1,450.0 10:45 12:00 MD to 1450' MD. 11/28/2018 11/28/2018 0.50 PROD1 DRILL DHEQ P Fill pipe and shallow hole test MWD. 1,450.0 1,450.0 12:00 12:30 823 psi, 26% FO. Turbine RPM 3160 rpm at 450 gpm, 3280 rpm at 539 gpm with 1104 psi, 20% FO. PU 92K SO 102K. Blow down TD. 11/28/2018 11/28/2018 5.00 PROD1 DRILL PULD P RIH picking up 5' drill pipe from 1450' 1,450.0 5,140.0 12:30 17:30 MD to 5140' MD. Fill every 20 stands. 11/28/2018 11/28/2018 4.00 PROD1 DRILL TRIP P RIH out of derrick from 5140' MD to 5,140.0 9,868.0 17:30 21:30 9868' MD. PU 163K SO 95K. 11/28/2018 11/29/2018 2.50 PROD1 DRILL CIRC P Circulate and condition mud staging 9,868.0 10,018.0 21:30 00:00 pump up to 550 gpm as dictated by shaker capacity. Rotate and reciprocate from 9868' MD to 10018' MD. Verify under reamer is closed. SPR's @9990 MD 4230' TVD, MW= 9.3 ppg, Hours = 21:40 Reamer closed. MP1) 30 spm= 810 psi, 40 spm= 930 psi MP2) 30 spm= 800 psi, 40 spm= 930 psi. 11/29/2018 11/29/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from10018' 10,018.0 10,330.0 00:00 06:00 MD to10330' MD, 4308' TVD, 650 gpm, 2160 psi, 31% F/0, 120 rpm, 1 O torque, 18K WOB, ECDs= 10.71, Off Btm= 2146 psi, P/U 166 S/O 120K, ROT 137K, 9K torque. Max Gas 15 units, ADT= 4.89 hrs, Bit hrs 4.89, Jar hrs 200.58 (Drilled to 10090' MD with reamer closed. Pick up to 10062 MD and open reamer. Set down on shelf at 10075' MD to verify reamer open.) Total footage 312'. Page 14/27 Report Printed: 12/26/2018 operations Summary (with Timelog uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/29/2018 11/29/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from10330' 10,330.0 10,670.0 06:00 12:00 MD tol0670' MD, 4400' TVD, 700 gpm, 2550 psi, 31% F/0, 110 rpm, 13K torque, 20K WOB, ECDs= 10.94, Off Btm= 2520 psi, P/U 168 S/O 118K, ROT 138K, 9.5K torque, Max Gas 15 units, ADT= 4.69 hrs, Bit hrs 9.58, Jar hrs 205.27. Total footage 340'. SPR's @10340 MD 4312' TVD, MW= 9.2 ppg, Hours = 06:20 Reamer open. MP1) 30 spm= 350 psi, 40 spm= 420 psi MP2) 30 spm= 350 psi, 40 spm= 420 psi. 11/29/2018 11/29/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from10670' 10,670.0 11,006.0 12:00 18:00 MD to 11006' MD, 4480' TVD, 696 gpm, 2800 psi, 31% F/0, 110 rpm, 15K torque, 18K WOB, ECDs= 11 -81, Off Btm= 2720 psi, P/U 175 S/O 119K, ROT 137K, 11 K torque, Max Gas 17 units, ADT= 4.83 hrs, Bit hrs 14.41, Jar hrs 210.10. Total footage 336'. 11/29/2018 11/30/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from11006' 11,006.0 11,388.0 18:00 00:00 MD to11388' MD, 4565' TVD, 700 gpm, 2980 psi, 31% F/0,120 rpm, 13K torque, 20K WOB, ECDs= 11.67, Off Btm= 2832 psi, P/U 175 S/O 119K, ROT 137K, 10K torque, Max Gas 17 units, ADT= 4.85 hrs, Bit hrs 19.26, Jar hrs 214.95. Total footage 382'. SPR's @11097 MD 4500' TVD, MW= 9.2+ ppg, Hours = 19:30 Reamer open. MP1) 30 spm= 450 psi, 40 spm= 540 psi MP2) 30 spm= 450 psi, 40 spm= 540 psi. 11/30/2018 11/30/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from11388' 11,388.0 11,775.0 00:00 06:00 MD to 11775' MD, 4662' TVD, 700 gpm, 2700 psi, 31% F/0,120 rpm, 13K torque, 21 K WOB, ECDs= 11.63, Off Btm= 2650 psi, P/U 179 S/O 123K, ROT 141 K, 1 OK torque, Max Gas 18 units, ADT= 4.71 hrs, Bit hrs 23.97, Jar hrs 219.66. Total footage 387'. 11/30/2018 11/30/2018 1.75 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from11775' 11,775.0 11,952.0 06:00 07:45 MD to 11952' MD, 4706' TVD, 700 gpm, 2760 psi, 31% F/0,120 rpm, 16K torque, 21 K WOB, ECDs= 11.42, Off Btm= 2700 psi, P/U 179 S/O 120K, ROT 143K, 11 K torque, Max Gas 31 units, ADT= 1.37 hrs, Bit hrs 25.34, Jar hrs 221.03. Total footage 177'. SPR's @11942' MD 4706' TVD, MW= 9.3 ppg, Hours = 07:30 Reamer open. MP1) 30 spm= 430 psi, 40 spm= 530 psi MP2) 30 spm= 430 psi, 40 spm= 530 psi. 11/30/2018 11/30/2018 1.25 PROD1 DRILL MPDA P Pull flow nipple. Install RCD. Install 11,952.0 11,952.0 07:45 09:00 drain nipple. Calibrate and ramp with NOVOS. Page 15127 Report Printed: 12/26/2018 operations Summary (with Timelog Uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth (ftKB) 11/30/2018 11/30/2018 3.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from11952' 11,952.0 12,239.0 09:00 12:00 MD to 12239' MD, 4781' TVD, 700 gpm, 2760 psi, 31% F/0,120 rpm, 16K torque, 21 K WOB, ECDs= 11.42, Off Btm= 2700 psi, P/U 179 S/O 120K, ROT 143K, 11 K torque, Max Gas 31 units, ADT= 2.22 hrs, Bit hrs 27.81, Jar hrs 223.25. Total footage 287' 11/30/2018 11/30/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from12239' 12,239.0 12,804.0 12:00 18:00 MD to 12804' MD, 4923' TVD, 700 gpm, 2967 psi, 31% F/0,120 rpm, 16K torque, 19K WOB, ECDs= 11.72, Off Btm= 2930 psi, P/U 180 S/O 116K, ROT 138K, 1 OK torque, Max Gas 99 units, ADT= 4.96 hrs, Bit hrs 32.77, Jar hrs 228.46. Total footage 565'. 11/30/2018 12/1/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole froml2804' 12,804.0 13,215.0 18:00 00:00 MD to 13215' MD, 5062' TVD, 700 gpm, 2880 psi, 31% F/0,120 rpm, 16K torque, 19K WOB, ECDs= 11.27, Off Btm= 2850 psi, P/U 182 S/O 115K, ROT 144K, 10K torque, Max Gas 62 units, ADT= 4.26 hrs, Bit hrs 37.03, Jar hrs 232.72. Total footage 411' SPR's @12898' MD 4946' TVD, MW= 9.5 ppg, Hours = 19:37 Reamer open. MPI) 30 spm= 475 psi, 40 spm= 535 psi MP2) 30 spm= 475 psi, 40 spm= 545 psi. 12/1/2018 12/1/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 13215' 13,215.0 13,630.0 00:00 06:00 MD to 13630' MD, 5278' TVD, 700 gpm, 2890 psi, 31% F/0,120 rpm, 16- 18K torque, 19K WOB, ECDs= 11.27, Off Btm= 2850 psi, P/U 192 S/O 108K, ROT 146K, 1 OK torque, Max Gas 40 units, ADT=5.07 hrs, Bit hrs 42. 10, Jar hrs 237.79. Total footage 415'. 12/1/2018 12/1/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from13630' 13,630.0 13,908.0 06:00 12:00 MD to 13908' MD, 5478' TVD, 650 gpm, 2260 psi, 29% F/0,110 rpm, 16K torque, 1 OK WOB, ECDs= 10.87, Off Btm= 2220 psi, P/U 215 S/O 132K, ROT 166K, 12K torque, Max Gas 88 units, ADT=4.73 hrs, Bit hrs 46.83, Jar hrs 242.52. Total footage 278'. SPR's @13747' MD 5368' TVD, MW= 9.3 ppg, Hours = 08:00 Reamer open. MP1) 30 spm= 440 psi, 40 spm= 560 psi MP2) 30 spm= 430 psi, 40 spm= 560 psi. Rig on gen power at 06:30hrs. Page 16/27 Report Printed: 12/26/2018 operations Summary (with Timelog Uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/1/2018 12/1/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from13908' 13,908.0 14,102.0 12:00 18:00 MD to 14102' MD, 5621' TVD, 650 gpm, 2237 psi, 30% F/0,110 rpm, 16K torque, 13K WOB, ECDs= 10.81, Off Btm= 2220 psi, P/U 215 S/O 132K, ROT 166K, 12K torque, Max Gas 92 units, ADT=5.17 hrs, Bit hrs 52.00, Jar hrs 247.69. Total footage 194'. 12/1/2018 12/2/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from14102' 14,102.0 14,325.0 18:00 00:00 MD to 14325' MD, 5774' TVD, 650 gpm, 2270 psi, 30% F/0,110 rpm, 17K torque, 13-17K WOB, ECDs= 10.96, Off Btm= 2365 psi, P/U 231 S/O 133K, ROT 166K, 12K torque, Max Gas 55 units, ADT=5.1 hrs, Bit hrs 57.10, Jar hrs 252.79. Total footage 223'. SPR's @14127 MD 5633' TVD, MW= 9.3 ppg, Hours = 18:30 Reamer open. MP1) 30 spm= 405 psi, 40 spm= 440 psi MP2) 30 spm= 425 psi. 40 spm= 480 psi. 12/2/2018 12/2/2018 6.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from14325' 14,325.0 14,575.0 00:00 06:00 MD to 14575' MD, 5954' TVD, 650 gpm, 2464 psi, 30% F/0,110 rpm, 19K torque, 13-17K WOB, ECDs= 11. 13, Off Btm= 2453 psi, P/U 240 S/O 134K, ROT 169K, 14K torque, Max Gas 67 units, ADT=5.5 hrs, Bit hrs 62.6, Jar hrs 258.29. Total footage 250' 12/2/2018 12/2/2018 2.00 PROD1 DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from14575' 14,575.0 14,654.0 06:00 08:00 MD to 14654' MD, 6011' TVD, 650 gpm, 2577 psi, 30% F/0,110 rpm, 20K torque, 11K WOB, ECDs= 11.27, Off Btm= 2560 psi, P/U 230 S/O 143K, ROT 172K, 16K torque, Max Gas 40 units, ADT=1.74 hrs, Bit hrs 64.34, Jar hrs 260.03. Total footage 79'. SPR's @14648 MD 6010' TVD, MW= 9.4 ppg, Hours = 08:23 Reamer open. MP1) 30 spm= 560 psi, 40 spm= 660 psi MP2) 30 spm= 560 psi, 40 spm= 660 psi. 12/2/2018 12/2/2018 4.00 PROD1 CASING CIRC P CBU x3 while BROOH from 14654' 14,654.0 14,411.0 08:00 12:00 MD to 14411' MD. 700 gpm, 2910 psi, 30% FO, 110 rpm, 16K tq. PU=220K SO=145K Rot=166K. Weight up mud system to 9.6 pps. Rig on high line power at 08:37 hrs. Page 17/27 Report Printed: 12/26/2018 operations Summary (with Timelog uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/2/2018 12/2/2018 0.75 PROD1 CASING OTHR P Close underreamer. Cycle flow rate to 14,411.0 14,411.0 12:00 12:45 550 gpm, 1940 psi, 3160 turbine rpm. Reduce rate to 250 gpm, 1113 psi, 1600 turbine rpm. Increase rate to 550 gpm, 2265 psi, 4120 turbine rpm. SPR's @14411 MD 5838' TVD, MW= 9.6 ppg, Hours = 12:30 Reamer closed. MP1) 30 spm= 565 psi, 40 spm= 650 psi MP2) 30 spm= 550 psi, 40 spm= 620 psi 12/2/2018 12/2/2018 1.75 PROD1 CASING OWFF P Perform MPD exhale test. Stage back 14,411.0 14,411.0 12:45 14:30 pressure down from350 psi to 57 psi. Shut in and observe pressure build to 180 psi. Bleed off/shut in and pressure built to 90 psi. Bleed off/shut in and pressure built to 45 psi. Bleed off/shut in multiple times and pressure built to 45 psi. 12/2/2018 12/2/2018 2.00 PROD1 CASING CIRC P Circulate surface to surface. 550 gpm, 14,411.0 14,411.0 14:30 16:30 2300 psi, 30% FO, 110 rpm, 15K tq, 10.76 ECD, BROOH from 14411' MD to 14321' MD. 12/2/2018 12/2/2018 2.00 PROD1 CASING OWFF P Perform exhale test as per MPD 14,411.0 14,411.0 16:30 18:30 advisor and then remove bull plug on return line and perform vis cup breathing evaluation. Slight flow at .89 bph diminishing to .13 bph. 12/2/2018 12/3/2018 5.50 PROD1 CASING BKRM P BROOH from 14111' MD to 12874' MD 14,411.0 12,874.0 18:30 00:00 laying down DP in mousehole. 110 rpm, 12K tq, 530 gpm, 2080 psi. Hold 11.1 ppg EMW on connections. 141 K rotating up weight. 12/3/2018 12/3/2018 6.00 PROD1 CASING BKRM P BROOH from 12874' MD to 10900' 12,874.0 10,900.0 00:00 06:00 MD laying down DP in mousehole. 110 rpm, 1 O tq, 530 gpm, 1920 psi. Reduce back pressure from 380 to 280 psi on connections to match circulating ECD's.. 12/3/2018 12/3/2018 5.00 PROD1 CASING BKRM P BROOH from 10900' MD to 9173' MD 10,900.0 9,173.0 06:00 11:00 laying down DP in mousehole. 110 rpm, 10K tq, 530 gpm, 1761 psi. Maintain 230 psi back pressure on connections to match circulating ECD's. 12/3/2018 12/3/2018 1.00 PROD1 CASING BKRM P BROOH from 9173' MD to 9167' MD. 9,173.0 9,167.0 11:00 12:00 530 gpm, 1761 psi, 110 rpm. Experience pack off event. Drop down and work stand. Reduce flow rate to 487 bpm, 1640 psi. 12/3/2018 12/3/2018 1.50 PROD1 CASING BKRM P Continue to BROOH from 9167' MD to 9,167.0 9,103.0 12:00 13:30 9103' MD. 487 gpm, 1640 psi, 110 rpm, 10K tq, Once stand fully reamed and hole conditions improved, stage pump rate up to 534 gpm, 1664 psi, 110 rpm, 9K tq. 12/3/2018 12/3/2018 1.50 PROD1 CASING CIRC P Pump 25 bbl low vis/35 bbl hi vis- 9,103.0 9,103.0 13:30 15:00 weighted sweep (11.6 ppg). Reciprocate from 9103 MD to 9205' MD, 534 gpm, 1770 psi, 80 rpm, 8K tq. 10.86 ECD. 12/3/2018 12/3/2018 0.50 PROD1 CASING SVRG P Service top drive. 9,103.0 9,103.0 15:00 15:30 Page 18/27 Report Printed: 12/26/2018 operations Summary (with Timelog uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/3/2018 12/3/2018 2.50 PROD1 CASING BKRM P BROOH from 9103' MD to 8642' MD 9,103.0 8,642.0 15:30 18:00 laying down DP in mousehole. 110 rpm, 9K tq, 540 gpm, 1600 psi. Stage pulling rate up from 350 fph to 500 fph. Maintain 200 psi back pressure on connections to match circulating ECD's. 12/3/2018 12/4/2018 6.00 PROD1 CASING BKRM P BROOH from 8642' MD to 7500' MD 8,642.0 7,500.0 18:00 00:00 laying down DP in mousehole. 110 rpm, 9K tq, 540 gpm, 1600 psi. Stage pulling rate up to 650 fph. Maintain 170 psi back pressure on connections to match circulating ECD's. 12/4/2018 12/4/2018 1.00 PROD1 CASING SVRG P Service drawworks and pipe skate. 7,500.0 7,500.0 00:00 01:00 12/4/2018 12/4/2018 1.00 PROD1 CASING RGRP T Troubleshoot top drive link tilt 7,500.0 7,500.0 01:00 02:00 malfunction. 12/4/2018 12/4/2018 2.75 PROD1 CASING BKRM P BROOH from 7500' MD to 7033' MD 7,500.0 7,033.0 02:00 04:45 laying down DP in mousehole. 110 rpm, 9K tq, 540 gpm, 1400 psi. Rot=95K. Pulling rate dictated by hole conditions 125-600 fph.. Maintain 170 psi back pressure on connections to match circulating ECD's. 12/4/2018 12/4/2018 2.75 PROD1 CASING CIRC T Experience pack off event. Reduce 7,033.0 7,033.0 04:45 07:30 flow rate and stage pump up to 253 gpm, 547 psi, 10 rpm, 6K tq. 12/4/2018 12/4/2018 1.50 PROD1 CASING REAM T Make up stand # 70. Wash and ream 7,033.0 7,119.0 07:30 09:00 from 7033' MD to 7119' MD. Stage flow up from 432 gpm to 665 gpm. 1991 psi, 32% FO, 110 rpm, 6.1 K tq, ECD=11.12 12/4/2018 12/4/2018 2.00 PROD1 CASING CIRC T Pump low-vis/hi-vis weighted tandem 7,119.0 7,119.0 09:00 11:00 sweep. 665 gpm, 2020 psi, 32% FO, 110 rpm, 6.1 K tq. ECD=11.01. CBU after sweep returns to sufrace. Check status of underreamer. 665 gpm, 2054 psi=4240 turbine rpm. Drop flow rate to 230 gpm, 508 psi. Cycle flow rate to 665 gpm, 2294 psi=4600 turbine rpm. Confirm underreamer closed. Record reamer status parameters. 544 gpm, 1630 psi=4000 turbine rpm. 534 gpm, 1578 psi=4000 turbine rpm. 502 gpm, 1415 psi=3760 turbine rpm. 12/4/2018 12/4/2018 1.00 PROD1 CASING BKRM P BROOH from 7119' MD to 7070' MD 7,119.0 7,070.0 11:00 12:00 80 rpm, 6.5K tq, 544 gpm, 1637 psi. 35% FO ECD=10.78. 12/4/2018 12/4/2018 2.00 PROD1 CASING RGRP T Troubleshoot top drive link tilt 7,070.0 7,119.0 12:00 14:00 malfunction. Rotate and reciprocate from 7119' MD to 7070' MD. 544 gpm, 1637 psi, 80 rpm, 6.5K tq, 35% FO, ECD=10.78 PU=144K SO=104K Rot=115K. 12/4/2018 12/4/2018 0.50 PROD1 CASING CIRC P Underreamer cycled open. Recycle 7,119.0 7,119.0 14:00 14:30 flow rates to close reamer. 230 gpm, 530 psi. 544 gpm, 1630 psi=4000 turbine rpm. 534 gpm, 1578 psi=4000 turbine rpm. 502 gpm, 1415 psi=3760 turbine rpm. Page 19127 Report Printed: 1 212 6/2 01 8 "perations Summary (with Timelog uepths) 2S-315 46 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/4/2018 12/4/2018 1.75 PROD1 CASING BKRM P BROOH from 7119 MD to 6895' MD 7,119.0 6,895.0 14:30 16:15 laying down DP in mousehole. 110 rpm, 6.6K tq, 543 gpm, 1622 psi. Reamer opened while back reaming with no flow rate change. Increase flow rate to 673 gpm, 1990 psi, 125 rpm, 7K tq, 33% FO, 12/4/2018 12/4/2018 0.50 PROD1 CASING CIRC P Establish reduced pump rate. 1.5 6,895.0 6,895.0 16:15 16:45 bpm=188 psi, 2 bpm=215 psi, 3 bpm=273 psi, 4 bpm=352 psi, 5 bpm=386 psi, 6 bpm=499 psi, 7 bpm=605 psi, 8 bpm=728 psi, 9 bpm=879 psi, 10 bpm=955 psi. 12/4/2018 12/4/2018 1.25 PROD1 CASING BKRM P BROOH from 6895 MD to 6739' MD. 6,895.0 6,739.0 16:45 18:00 125 rpm, 7K tq, 673 gpm, 1995 psi. 33% FO, ECD=11.31 Pulling rate dictated by hole conditions. 12/4/2018 12/4/2018 5.50 PROD1 CASING BKRM T Experience pack off event at 6739' 6,739.0 6,739.0 18:00 23:30 MD. Reduce flow rate , open chokes and establish flow rate to 670 gpm, 1950 psi. BROOH from 6739' MD to 6669' MD. 80 rpm, 9K tq. Pulling speed dictated by hole conditions. Max pulling speed achieved was 75 fph. Experience another pack off event. Work back down to 6739' MD. Establish flow rate of 670 gpm, 1900 psi. 12/4/2018 12/5/2018 0.50 PROD1 CASING CIRC P Attempt to close reamer as per SLB 6,739.0 6,739.0 23:30 00:00 reamer rep. Unsuccessful after 6 attempts. 12/5/2018 12/5/2018 1.00 PROD1 CASING SMPD P Strip OOH from 6739' MD to 6308' MD 6,739.0 6,308.0 00:00 01:00 as per stripping schedule standing back DP. PU=150K SO=80K. Hold 200 psi back pressure while pulling and 70 psi in slips. 12/5/2018 12/5/2018 1.00 PROD1 CASING OWFF P Perform exhale test. Shut in and bleed 6,308.0 6,308.0 01:00 02:00 in five 5 min cycles. Initial SIP=47 psi Final SIP=31 psi. Perform timed vis cup evaluation. Initial flow out at 5.3 bph diminishing to 2.38 bph in 30 mins. 12/5/2018 12/5/2018 2.25 PROD1 CASING SMPD P Strip OOH from 6308' MD to 4850' MD 6,308.0 4,850.0 02:00 04:15 as per stripping schedule standing back DP. PU=134K. Hold 220 psi back pressure while pulling and 70 psi in slips. Improper pipe displacement occurring. 12/5/2018 12/5/2018 0.75 PROD1 CASING OWFF P Perform exhale test. Shut in and bleed 4,850.0 4,850.0 04:15 05:00 in five 5 min cycles. Initial SIP=26 psi Final SIP=5 psi 12/5/2018 12/5/2018 2.00 PROD1 CASING SMPD P Strip OOH from 4850' MD to 3773' MD 4,850.0 3,773.0 05:00 07:00 as per stripping schedule standing back DP. PU=120K. Hold 240 psi back pressure while pulling and 90 psi in slips. 12/5/2018 12/5/2018 2.00 PROD! CASING SMPD P Attempt to pull underreamer into shoe. 3,773.0 3,721.0 07:00 09:00 Observe 1 OK overpull. Slack off and make several attempts to pull reamer into shoe. Slack off to 3782' MD and attempt to close underreamer. Unsuccessful. Pull underreamer against shoe and bleed jars with 10K overpull. Stage overpull up to 35K and observe weight drop off. Continue to pick up to 3721' MD PU=122K Page 20/27 Report Printed: 12/26/2018 operations Summary (with Timelog uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/5/2018 12/5/2018 0.50 PROD1 CASING SMPD P Strip OOH from 3721' MD to 3527' MD 3,721.0 3,527.0 09:00 09:30 as per stripping schedule standing back DP. PU=116K. Hold 240 psi back pressure while pulling and 90 psi in slips. 12/5/2018 12/5/2018 1.25 PROD1 CASING CIRC P Pump low vis/weighted hi-vis tandem 3,527.0 3,527.0 09:30 10:45 sweep. 700 gpm, 1574 psi, 32% FO, PU=108K SO=94K. Blow down TD. 12/5/2018 12/5/2018 0.75 PROD1 CASING OWFF P Monitor well. Slight flow at .47 bph 3,527.0 3,527.0 10:45 11:30 diminishing to .12 bph. 12/5/2018 12/5/2018 3.50 PROD1 CASING SMPD P Strip OOH from 3527' MD to 504' MD 3,527.0 504.0 11.30 15:00 as per stripping schedule standing back DP. PU=77K. Hold 200 psi back pressure while pulling and 90 psi in slips. 12/5/2018 12/5/2018 1.25 PROD1 CASING OWFF P Monitor well. Slight flow at 1 bph 504.0 504.0 15:00 16:15 diminishing to static. 12/5/2018 12/5/2018 0.75 PROD1 CASING MPDA P Pull RCD and install trip nipple. 504.0 504.0 16:15 17:00 12/5/2018 12/5/2018 4.00 PROD1 CASING BHAH P Monitor well. Static. Lay down BHA#4 504.0 0.0 17:00 21:00 as per SLB DD. Clean and clear rig floor. 12/5/2018 12/5/2018 1.50 COMPZN CASING WWWH P Pull wear ring. Make up stack washer 0.0 0.0 21:00 22:30 and flush BOPE. Set test plug. 12/5/2018 12/5/2018 0.75 COMPZN CASING RURD P Change upper VBR's to 7 5/8" solid 0.0 0.0 22:30 23:15 body rams. 12/5/2018 12/5/2018 0.25 COMPZN WHDBOP RURD P Install test joint and perform body test 0.0 0.0 23:15 23:30 with 7 5/8" test joint. 250/3500 psi. 12/5/2018 12/6/2018 0.50 COMPZN WHDBOP BOPE P Perform BOPE test. All tests at 250 pis 0.0 0.0 23:30 00:00 low/3500 psi high.for 5 min's each. Test #1- 7 5/8" test joint, annular, CV's -1,12,13,14, 4" kill line, 5" dart valve.Witness waived byAOGCC Rep Lou Laubenstein. 12/6/2018 12/6/2018 3.00 COMPZN WHDBOP BOPE P Continue with BOPE test. Test #2-7 0.0 0.0 00:00 03:00 5/8" test joint, upper pipe rams, CV's 9,11, mezzanine kill valve, 5" TIW . Test #3- CV's 8,10, kill HCR. Test #4- CV's 67. Test #5-manual and hydraulic chokes 250/2000 psi. Test #6-CV's 2,5, manual kill, 4" dart. Test #7- Blind rams, CV's 3,4,6, 4" TIW. Test #8- 3 1/2" test joint, annular, choke HCR, upper IBOP. Test #g- lower VBR's, lower IBOP. Test #10- F test joint, annular, choke manual. Test #11- lower VBR's. Koomey draw down test. Starting psi= 2950 psi, after closure= 1450 psi, 200 psi attained= 7sec, full pressure attained=50 sec. 6 nitrogen bottles at 2000 psi, Test gas alarms, PVT and flow show Test witness waived byAOGCC rep Lou Laubenstein. 12/6/2018 12/6/2018 1.00 COMPZN WHDBOP RURD P Rig down test equipment. Blow down 0.0 0.0 03:00 04:00 lines. 12/6/2018 12/6/2018 1.00 COMPZN CASING SLPC P Slip and cut 73' drilling line. 0.0 0.0 04:00 05:00 12/6/2018 12/6/2018 2.25 COMPZN CASING RURD P Rig up to run 7 5/8" casing. Verify joint 0.0 0.0 05:00 07:15 count and running order. Page 21/27 Report Printed: 12/26/2018 uperations Summary (with Timelog Vepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/6/2018 12/6/2018 0.75 COMPZN CASING PUTB P Make up 7 5/8" shoe track. Baker lock 0.0 245.0 07:15 08:00 connections to pin end of joint #5. Make up Hyd 563 connections to 10.3K ft/lbs.Fill pipe and check floates. OK. PU=52K SO=50K. 12/6/2018 12/6/2018 9.25 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 245.0 3,544.0 08:00 17:15 casing as per tally from 245' MD to 3544' MD. Follow running speed program of 2500 fph max. Make up TXP connections to 21.2K ft/lbs. Fill pipe on the fly and top off every 10 jts. Monitor displacement via pit #1. 12/6/2018 12/6/2018 0.75 COMPZN CASING CIRC P CBU. Stage pump rate up to 7 bpm. 3,544.0 3,544.0 17:15 18:00 ICP= 2 bpm, 165 psi, 7% FO. FCP=7 bpm, 228 psi, 16% FO. 12/6/2018 12/6/2018 4.50 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 3,544.0 5,746.0 18:00 22:30 casing as per tally from 3544' MD to 5746' MD. Follow running speed program of 2500 fph max. Make up TXP connections to 21.2K ft/lbs. Fill pipe on the fly and top off every 10 jts. Monitor displacement via pit #1. PU=137K SO=87K 12/6/2018 12/7/2018 1.50 COMPZN CASING CIRC P CBU. Stage pump rate up to 5 bpm. 5,746.0 5,746.0 22:30 00:00 ICP= 3 bpm, 489 psi, 7% FO. FCP=5 bpm, 407 psi. PU=177K SO=73K. At 1300 strokes mud wt out= 10.1 ppg/100 vis. 9.6 ppg/41 vis going in. 12/7/2018 12/7/2018 0.50 COMPZN CASING CIRC P Continue to CBU. Stage pump rate up 5,746.0 5,746.0 00:00 00:30 to 7 bpm, 520 psi, 10% FO. PU=177K SO=73K. MW in=9.7 ppg, MW out=9.8 ppg. 4431 total strokes pumped. 12/7/2018 12/7/2018 0.50 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 5,746.0 5,900.0 00:30 01:00 casing as per tally from 5746' MD to 5900' MD. Follow running speed program of 2500 fph max. Make up TXP connections to 21.2K ft/lbs. Monitor displacement via pit #1. PU=170K SO=82K.Observed improper pipe displacement. 12/7/2018 12/7/2018 0.50 COMPZN CASING OWFF P Monitor well to confirm breathing. Flow 5,900.0 5,900.0 01:00 01:30 at 7 bph diminishing to 4.5 bph. 12/7/2018 12/7/2018 5.25 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 5,900.0 8,324.0 01:30 06:45 casing as per tally from 5900' MD to 8324' MD. Follow running speed program of 2500 fph max. Make up TXP connections to 21.2K ft/lbs. Monitor displacement via pit #1. PU=183K SO=99K. 12/7/2018 12/7/2018 1.75 COMPZN CASING CIRC P CBU. Stage pump rate up to 7 bpm. 8,324.0 8,324.0 06:45 08:30 ICP= 2 bpm, 366 psi, 8% FO. FCP=7 bpm, 442 psi, 16% FO. PU=167K SO=91 K. 12/7/2018 12/7/2018 0.50 COMPZN CASING OWFF P Monitor well. Flowing at 9 bph 8,324.0 8,324.0 08:30 09:00 diminishing to 1.8 bph. 12/7/2018 12/7/2018 3.00 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 8,324.0 9,814.0 09:00 12:00 casing as per tally from 8324' MD to 9814' MD. Follow running speed program of 2500 fph max. Make up TXP connections to 21.2K ft/lbs. Monitor displacement via pit #1. PU=204K SO=102K. Page 22/27 Report Printed: 12/26/2018 Uperations Summary (with Timelog Depths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/7/2018 12/7/2018 1.75 COMPZN CASING CIRC P CBU. Stage pump rate up to 7 bpm. 9,814.0 9,814.0 12:00 13:45 ICP= 2 bpm, 352 psi, 6% FO. FCP=7 bpm, 511 psi, 16% FO. PU=190K SO=100K. 12/7/2018 12/7/2018 0.25 COMPZN CASING OWFF P Monitor well. Flowing at 9 bph 9,814.0 9,814.0 13:45 14:00 diminishing to 4.5 bph. 12/7/2018 12/7/2018 1.75 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 9,814.0 10,686.0 14:00 15:45 casing as per tally from 9814' MD to 10686' MD. Follow running speed program of 2500 fph max. Make up TXP connections to 21.2K ft/lbs. Monitor displacement via pit #1. PU=225K SO=100K. Observe increase in SO drag at 10680' MD. 12/7/2018 12/7/2018 2.25 COMPZN CASING CIRC P Circulate surface to surface.. Stage 10,686.0 10,686.0 15:45 18:00 pump rate up to 7 bpm. ICP= 2 bpm, 360 psi, 7% FO. FCP=7 bpm, 486 psi, 18% FO. PU=206K SO=95K. 12/7/2018 12/8/2018 6.00 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 10,686.0 12,912.0 18:00 00:00 casing as per tally from 10686' MD to 12912' MD. Follow running speed program of 1800 fph max. Make up TXP connections to 21.2K ft/Ibs. Monitor displacement via pit #1. PU=243K SO=104K. 12/8/2018 12/8/2018 1.00 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 12,912.0 13,314.0 00:00 01:00 casing as per tally from 12912' MD to 13314' MD. Follow running speed program of 1800 fph max. Make up TXP connections to 21.2K ft/lbs. Monitor displacement via pit #1. PU=243K SO=99K. 12/8/2018 12/8/2018 2.50 COMPZN CASING CIRC P CBU. Stage pump rate up to 6 bpm. 13,314.0 13,314.0 01:00 03:30 ICP= 1 bpm, 460 psi, 6% FO. FCP=6 bpm, 539 psi, 16% FO. PU=226K SO=110K. 12/8/2018 12/8/2018 3.50 COMPZN CASING PUTB P RIH picking up 7 5/8" 29.7# TXP 13,314.0 14,552.0 03:30 07:00 casing as per tally from 13314' MD to 14552' MD. Follow running speed program of 1800 fph max. Make up TXP connections to 21.2K ft/lbs. Monitor displacement via pit #1. PU=275K SO=126K. Observed string taking weight to 70K. 12/8/2018 12/8/2018 5.50 COMPZN CASING CIRC T Break circulation at 2 bpm, 663 psi, 14,552.0 14,570.0 07:00 12:30 5% FO. Wash down from 14552' MD to 14572' MD. PU=288K, broke over at 310K. SO=100K. Work pipe and observe string weight and pump pressure improve. PU=228K SO=94K. 2 bpm, 576 psi. Stage pump up to 8 bpm, 876 psi, 18% FO. PU=228K SO -=94K. Wash and work pipe to 14582' MD. Pump off PU=305K SO= 123K. Could not work past 14570 with pump off. Discuss options with Drilling Engineer. 12/8/2018 12/8/2018 1.75 COMPZN CASING HOSO -11- ay down 3 jts casing pumping OOH 14,570.0 14,516.0 12:30 14:15 IT with 4 bpm, 422 psi 8% FO.. PU X -O joint and hanger. Page 23/27 Report Printed: 12/26/2018 operations Summary (with Timelog Vepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/8/2018 12/8/2018 1.25 COMPZN CASING HOSO P RIH and land hanger. String taking 14,516.0 14,558.0 14:15 15:30 weight at 14528' MD. Break circulation at 2 bpm, 401 psi, 5% FO. Stage pump rate up to 10 bpm, 980 psi, 21 % FO. Reciprocate with 20' to 30' strokes. Initial PU=330K SO=68K. Final PU=230K SO=97K. 12/8/2018 12/8/2018 0.25 COMPZN CEMENT RURD P Blow down top drive. Rig up cement 14,558.0 14,558.0 15:30 15:45 line. 12/8/2018 12/8/2018 1.50 COMPZN CEMENT CIRC P Circulate and condition for cement job. 14,558.0 14,558.0 15:45 17:15 8 bpm, 886 psi, 17% FO. Sim- ops/PJSM on cement job. 12/8/2018 12/8/2018 3.75 COMPZN CEMENT CMNT P Test lines to 4000 psi. Drop bottom 14,558.0 14,558.0 17:15 21:00 plug #1. Pump 45 bbls 12.5 ppg Mud Push Il. 6 bpm 470 psi. Drop bottom plug #2. Mix and pump 184.4 bbls 15.8 ppg production cement with 1 ppb Cemnet at 5 bpm 240-150 psi. Wash up to bleeder line. Drop top plug and displace with 9.6 ppg NaCl brine. First 50 bbls of brine were corrosion inhibited. 7 bpm, ICP=324 psi. Reduce rate to 6 bpm at 500 bbls away, 735 psi. Reduce rate to 5 bpm at 600 bbls away, 1071 psi. Reduce rate to 3 bpm at 650 bbls away, 1200 psi.. Bump plugs at 6572 stks. Pressure up to 1700 psi and hold for 5 mins.CIP at 21:00 hrs. Full returns throughout job. Reciprocate 25' strokes. Land on hanger at 6150 stks. 12/8/2018 12/8/2018 1.50 COMPZN CEMENT CMNT T Bleed off pressure. Check floats. 14,558.0 14,558.0 21:00 22:30 Slight flow out casing at .27 bph diminishing to .07 bph. Back side static. 12/8/2018 12/8/2018 0.50 COMPZN CEMENT RURD P Lay down landing joint. Rlg down 14,558.0 0.0 22:30 23:00 CRT. Clean and clear rig floor. 12/8/2018 12/9/2018 1.00 COMPZN CEMENT WWSP P Set and energize packoff. 0.0 0.0 23:00 00:00 12/9/2018 12/9/2018 0.50 COMPZN CEMENT WWSP P Test packoff. 250 psi low/5 mins. 5000 0.0 0.0 00:00 00:30 psi high/10 mins. Witnessed by Co Man. 12/9/2018 12/9/2018 4.75 COMPZN EVALWB QEVL P Rig up SLB e-line/WeIITec tractor.. 0.0 0.0 00:30 05:15 Make up CBL tool string. 12/9/2018 12/9/2018 5.50 COMPZN EVALWB QEVL P RIH with SLB e -line to 14431' WLM. 0.0 0.0 05:15 10:45 Monitor well via TT. 12/9/2018 12/9/2018 4.75 COMPZN EVALWB QEVL P Log up with CBL from 14431' WLM to 0.0 0.0 10:45 15:30 10475' WLM. TOC at 11,300' WLM. POOH with e -line. Sim-ops/Lay down DP from derrick. 12/9/2018 12/9/2018 1.00 COMPZN EVALWB QEVL P Rig down SLB e -line. Sim -ops/ Rig up 0.0 0.0 15:30 16:30 LRS and freeze protect 10 3/4" x 7 5/8" annulus. Test lines to 3500 psi. Pump 10 bbls diesel/50 bbls water/150 bbls diesel at 2 bpm. ICP=800 psi FCP=925 psi. 12/9/2018 12/9/2018 1.50 COMPZN RPCOMP BOPE P Pull wear ring and set test plug. 0.0 0.0 16:30 18:00 Change upper pipe rams to 3 1/2" x 6" VBR's 12/9/2018 12/9/2018 1.75 COMPZN RPCOMP BOPE P Test upper VBR's to 250 psi low/3500 0.0 0.0 18:00 19:45 psi high for 5 mins each with 3 1/2" test joint. Rig down test equipment. Pull test plug and set wearring 12/9/2018 12/9/2018 1.00 COMPZN WELLPR PRTS P Test 7 5/8" casing to 3650 psi/30 mins. 0.0 0.0 19:45 20:45 1 1 I Good test. Page 24/27 Report Printed: 12/26/2018 Operations Summary (with Timelog Depths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/9/2018 12/9/2018 2.75 COMPZN PERF ELNE P Rlg up SLB a-line and make up pert 0.0 0.0 20:45 23:30 gun tool string. 12/9/2018 12/10/2018 0.50 COMPZN PERF ELNE P RIH with pert guns on a-line. 0.0 0.0 23:30 00:00 12/10/2018 12/10/2018 7.00 COMPZN PERF ELNE P RIH with pert guns on a-line to 14300' 0.0 0.0 00:00 07:00 WLM. Tie in and shoot perfguns. Perf interval from 14,173'to 14,203' using 3 3/8" HSD Powerjet Nova 3406 HMX 6 spf 60` phase guns. Monitor well. Fluid level dropped 8" in BOPE. Sim- ops/Lay down DP from derrick. 12/10/2018 12/10/2018 3.75 COMPZN PERF ELNE P POOH and rig down a-line. Sim- 0.0 0.0 07:00 10:45 ops/Change out ODS derrick fingers. 12/10/2018 12/10/2018 0.75 COMPZN PERF ELNE P Pull wear ring. Clean and clear rig 0.0 0.0 10:45 11:30 floor. Move a-line unit from obstructing beaver slide. 12/10/2018 12/10/2018 1.50 COMPZN RPCOMP RURD P Rig up to run upper completion. Verify 0.0 0.0 11:30 13:00 joint count in pipe shed. 12/10/2018 12/10/2018 0.25 COMPZN RPCOMP SFTY P PJSM on picking up completion. 0.0 0.0 13:00 13:15 Discuss safety, well control, torque values and running order. 12/10/2018 12/10/2018 1.75 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2" EUE 8rd 0.0 337.0 13:15 15:00 9.3# L-80 completion string to gauge carrier. Install DHG in carrier. 12/10/2018 12/10/2018 0.25 COMPZN RPCOMP PRTS P Test DHG connections to 5000 psi/5 337.0 337.0 15:00 15:15 mins. 12/10/2018 12/10/2018 2.75 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2" EUE 8rd 337.0 2,032.0 15:15 18:00 9.3# L-80 completion string From 337' MD to 2032' MD. Torque 3 1/2" EUE 8rd connections to 2300 ft/lbs. Max running speed 90 fpm. Monitor TEC wire integrity. Install cross collar cannon clamps on each connection. PU=60K SO=66K. 12/10/2018 12/11/2018 6.00 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2" EUE 8rd 2,032.0 5,294.0 18:00 00:00 9.3# L-80 completion string From 2032' MD to 5294' MD. Torque 3 1/2" EUE 8rd connections to 2300 ft/lbs. Max running speed 90 fpm. Monitor TEC wire integrity. Install cross collar cannon clamps on each connection. PU=69K SO=73K. 12/11/2018 12/11/2018 6.50 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2" EUE 8rd 5,294.0 9,558.0 00:00 06:30 9.3# L-80 completion string From 5294' MD to 9558' MD. Torque 3 1/2" EUE 8rd connections to 2300 ft/lbs. Max running speed 90 fpm. Monitor TEC wire integrity. Install cross collar cannon clamps on each connection. PU=87K SO=74K. 12/11/2018 12/11/2018 3.50 COMPZN RPCOMP EQRP T Hydraulic hose failed on tong power 9,558.0 9,558.0 06:30 10:00 unit. Secure well. Change out power unit and hoses. Clean up resulting spill. 12/11/2018 12/11/2018 2.00 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2" EUE 8rd 9,558.0 11,361.0 10:00 12:00 9.3# L-80 completion string From 9558' MD to 11361' MD. Torque 3 1/2" EUE 8rd connections to 2300 ft/lbs. Max running speed 90 fpm. Monitor TEC wire integrity. Install cross collar cannon clamps on each connection. PU=87K 30=76K. Page 25127 Report Printed: 12/26/2018 uperations Summary (with Timelog Vepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/11/2018 12/11/2018 5.25 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2" EUE 8rd 11,361.0 14,303.0 12:00 17:15 9.3# L-80 completion string From 11361' MD to 14303' MD. Torque 3 1/2" EUE 8rd connections to 2300 ft/lbs. Max running speed 90 fpm. Monitor TEC wire integrity. Install cross collar cannon clamps on each connection. PU=116K SO=81 K. 12/11/2018 12/11/2018 0.25 COMPZN RPCOMP RURD P Make up FOSV. 3" ID on valve and X- 14,303.0 14,303.0 17:15 17:30 O. Rig down Tec wire sheave and power tongs. 12/11/2018 12/11/2018 1.50 COMPZN RPCOMP ELNE P Rig up SLB a-line. 14,303.0 14,303.0 17:30 19:00 12/11/2018 12/12/2018 5.00 COMPZN RPCOMP ELNE P RIH with UPCT/Tractor tool string on 14,303.0 14,303.0 19:00 00:00 wireline to 5800' WLM. Engage tractor at 2800' WLM. 12/12/2018 12/12/2018 6.00 COMPZN RPCOMP ELNE P RIH with UPCT/Tractor tool string on 14,303.0 14,303.0 00:00 06:00 wireline from 5800' WLM to 11923' WLM. 12/12/2018 12/12/2018 1.50 COMPZN RPCOMP ELNE P RIH with UPCT/Tractor tool string on 14,303.0 14,303.0 06:00 07:30 wireline FROM 11923' wlm to 14280' WLM. 12/12/2018 12/12/2018 2.50 COMPZN RPCOMP ELNE P Log up and correlate depths from 14,303.0 14,303.0 07:30 10:00 14280' WLM to 13288' WLM. Lower packer at 14264' WLM (14271.62 SLM). POOH with a-line. 12/12/2018 12/12/2018 1.00 COMPZN RPCOMP ELNE P Rig down SLB a-line. 14,303.0 14,303.0 10:00 11:00 12/12/2018 12/12/2018 1.75 COMPZN RPCOMP HOSO P Lay down joints #453 through #450. 14,303.0 14,300,0 11:00 12:45 Pick up joint #456 in place of #450 and 2 pup joints (6.15' & 10.28'). Make up 4 1/2" 12.6# L-80 IBTjoint and X- O. Top of lower packer at 14258.57' WLM (14266.19" SLM) Total of 447 full cross coupling Cannon clamps run, 5 half clamps 3 1/2" and 2 half clamps 4 1/2" run. WLEG at 14299.98' SLM.PU=108K SO=83K. 12/12/2018 12/12/2018 1.50 COMPZN RPCOMP THGR P Makeup 4 1/2" 12.6# L-80 IBT joint 14,300.0 14,300.0 12:45 14:15 and X-O. Make up hanger and landing joint. Terminate TEC wire and test connections to 5000 psi/5 mins. Land hanger. RILDS and torque to spec. (450 ft/lbs). 12/12/2018 12/12/2018 0.50 COMPZN RPCOMP RURD P Rig down and clear floor of tubing 14,300.0 14,300.0 14:15 14:45 running tools. Lay down landing joint. 12/12/2018 12/12/2018 2.00 COMPZN RPCOMP PRTS T Purge lines and pump down tubing 14,300.0 14,300.0 14:45 16:45 through kill line with blind rams closed. At 1889 psi observe increase in flow out of IA and pressure decrease. Shut down pump and observe flow continue and pressure bleed off. Verify valve line up and check surface equipment. Blow down lines and make up landing joint. Page 26/27 Report Printed: 12/26/2018 Uperations Summary (with Timelog Uepths) 2S-315 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/12/2018 12/12/2018 2.25 COMPZN RPCOMP PRTS P Pump down tubing to 1600 psi. 14,300.0 0.0 16:45 19:00 Pressure holding and flow out IA / ceased. Pressure up to 3000 psi with 1 no flow from IA. Pressure up to 4150 psi and hold for 30 min's. Charted. Bleed pressure to 2000 psi. Pressue up to 350ppsi,on_tA and hold for 30 min's. Charted. Bleed tubing to 0 psi and shear SOV. Pump 6 bbls down IA taking returns up tubing. 2 bpm at 160 psi. Lay down landing joint. 12/12/2018 12/12/2018 1.25 COMPZN RPCOMP WWWH P Rig up stack washer. Flush BOPE. 0.0 0.0 19:00 20:15 Drain stack and rig down stack washer. 12/12/2018 12/12/2018 1.00 COMPZN WHDBOP MPSP P Rig up and set HP BPV. Pump down 0.0 0.0 20:15 21:15 IA to test BPV in direction of flow. Hold 2600 psi/10 min's. Charted. 12/12/2018 12/12/2018 1.00 COMPZN WHDBOP MPDA P Blow down lines. Rig down RCD wing 0.0 0.0 21:15 22:15 valve and RCD. Sim-ops/Change out top drive pipe handler 12/12/2018 12/13/2018 1.75 COMPZN WHDBOP NUND P Nipple down BOPE. Sim-ops/Change 0.0 0.0 22:15 00:00 out top drive pipe handler 12/13/2018 12/13/2018 1.50 COMPZN WHDBOP NUND P Nipple down BOPE. Sim-ops/Change 0.0 0.0 00:00 01:30 out top drive pipe handler 12/13/2018 12/13/2018 4.50 COMPZN WHDBOP NUND P Nipple up adapter flange and tree 0.0 0.0 01:30 06:00 Terminate TEC wire. Final DHG readings= 2760 psi BHP and 138.73° F BHT. 12/13/2018 12/13/2018 0.75 COMPZN WHDBOP PRTS P Test upper hanger seal and adapter 0.0 0.0 06:00 06:45 flange void to 5000 psi/10 mins. Witnessed by Co Man. 12/13/2018 12/13/2018 1.25 COMPZN WHDBOP OTHR P Remove blind flange from wing valve 0.0 0.0 06:45 08:00 and install pump in flange. Make up tree cap. 12/13/2018 12/13/2018 1.50 COMPZN WHDBOP PRTS P Test tree to 5000 psi/10 mins. Good 0.0 0.0 08:00 09:30 test 12/13/2018 12/13/2018 1.50 COMPZN WHDBOP MPSP P Dry rod out BPV. 0.0 0.0 09:30 11:00 12/13/2018 12/13/2018 2.50 COMPZN WHDBOP FRZP P Rig up LRS. Test corc lines to 2000 0.0 0.0 11:00 13:30 psi. Pump 130 bbls diesel down IA at 2 bpm taking returns up tubing. ICP=550 psi FCP=600 psi. Blow down lines and rig down LRS. 12/13/2018 12/13/2018 0.50 COMPZN WHDBOP MPSP P Set CIW type H BPV. IA=O psi 0.0 0.0 13:30 14:00 1 1 1 1OA=350 psi Tubing=0 psi. 12/13/2018 12/13/2018 2.50 DEMOB MOVE RURD P Secure tree and cellar. 0.0 0.0 14:00 16:30 Rig released at 16:30 hrs 12/13/18 Page 27/27 Report Printed: 12/26/2018 NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-315 NAD 27 ConocoPhillips Definitive Survey Report 18 December, 2018 ConocoPhilli s p Company: NADConversion Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-315 Wellbore: 2S-315 Design: 2S-315 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2S-315 Actual: 39.42+120 @ 159.42usft Actual: 39.42+120 @ 159.42usft True Minimum Curvature EDT 14 Alaska Production Iroject Kuparuk River Unit, North Slope Alaska, United States Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Aap Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-315 Well Position +N/ -S 0.00 usft Northing: 5,929,961.45 usft Latitude: 70° 13' 11.314 N +E/ -W 0.00 usft Easting: 480,956.55 usft Longitude: 150° 9' 13.070 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 120.00 usft +E/ -W Northing Easting DLS Section Wellbore 2S-315 (I (usft) (usft) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (ft) Survey Tool Name 39.42 (°) (°) (nT) -120.00 BG G M2018 11/21/2018 16.69 80.77 57,418 Design 2S-315 0.00 UNDEFINED 118.69 0.27 Audit Notes: 118.69 -40.73 -0.17 0.07 Version: 1.0 Phase: ACTUAL Tie On Depth: 39.42 162.95 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction -0.48 0.04 (usft) 39.42 (usft) 0.00 (usft) (I 0.00 180.00 0.48 GYD-GC-MS (1) 254.49 0.73 194.71 254.48 95.06 Survey Program Date 5,929,959.96 480,956.28 0.16 From To 0.68 203.77 326.88 (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 118.69 983.79 2S-315 Srvy 1 - SLB_GWD70 (2S-315) GYD-GC-MS Gyrodata gyrocompassing m/s 11/17/2018 8:31 1,042.18 1,136.45 2S-315 Srvy 2 - SLB_MWD+GMAG (2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/17/2018 8:47 1,235.37 1,647.75 2S-315 Srvy 3 - SLB_GWD70 (2S-315) GYD-GC-MS Gyrodata gyrocompassing m/s 11/17/2018 851 1,706.01 3,496.13 2S-315 Srvy 4 - SLB_MWD+GMAG (2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/17/2018 8:54 3,580.83 3,958.95 2S-315 Srvy 5 - SLB_MWD+GMAG (2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/22/2018 11:2, 4,052.53 4,052.53 2S-315 Srvy 6 - SLB_MWD-Inc-Only (2S MWD -INC -ONLY MWD-INC_ONLY_FILLER 11/22/2018 8:54 4,148.08 9,953.43 2S-315 Srvy 7 - SLB_MWD+GMAG (2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/22/2018 11:2' 9,974.71 14,565.99 2S-315 Srvy 8 - SLB_MWD+GMAG (2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/29/2018 11:2: Survey 12/18/2018 12:40:05PM Page 2 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.42 0.00 0.00 39.42 -120.00 0.00 0.00 5,929,961.45 480,956.55 0.00 0.00 UNDEFINED 118.69 0.27 157.29 118.69 -40.73 -0.17 0.07 5,929,961.28 480,956.62 0.34 0.17 GYD-GC-MS (1) 162.95 0.59 199.26 162.95 3.53 -0.48 0.04 5,929,960.97 480,956.59 0.97 0.48 GYD-GC-MS (1) 254.49 0.73 194.71 254.48 95.06 -1.49 -0.27 5,929,959.96 480,956.28 0.16 1.49 GYD-GC-MS (1) 326.89 0.68 203.77 326.88 167.46 -2.33 -0.56 5,929,959.12 480,955.99 0.17 2.33 GYD-GC-MS (1) 418.86 0.65 217.21 418.84 259.42 -3.25 -1.09 5,929,958.21 480,955.45 0.17 3.25 GYD-GC-MS (11 510.53 1.46 159.20 510.50 351.08 -4.75 -0.99 5,929,956.70 480,955.55 1.36 4.75 GYD-GC-MS (1) 605.59 2.78 165.20 605.49 446.07 -8.11 0.03 5,929,953.34 480,956.56 1.41 8.11 GYD-GC-MS (1) 12/18/2018 12:40:05PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-315 Project: Kuparuk River Unit TVD Reference: Actual: 39.42+120 @ 159.42usft Site: Kuparuk 2S Pad MD Reference: Actual: 39.42+120 @ 159.42usft Well: 25-315 North Reference: True Wellbore: 25-315 Survey Calculation Method: Minimum Curvature Design: 2S-315 Database: EDT 14 Alaska Production Survey 12/18/2018 12:40:05PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 700.15 4.91 177.00 699.83 540.41 -14.37 0.82 5,929,947.08 480,957.34 2.39 14.37 GYD-GC-MS (1) 794.68 5.37 175.18 793.98 634.56 -22.82 1.41 5,929,938.63 480,957.90 0.52 22.82 GYD-GC-MS (1) 888.91 6.74 176.03 887.68 728.26 -32.73 2.16 5,929,928.72 480,958.63 1.46 32.73 GYD-GC-MS (1) 983.79 9.72 180.51 981.58 822.16 -46.30 2.48 5,929,915.15 480,958.91 3.21 46.30 GYD-GC-MS (1) 1,042.18 11.00 180.89 1,039.01 879.59 56.80 2.35 5,929,904.65 480,958.75 2.20 56.80 MWD+IFR-AK-CAZ-SC (2) 1,136.45 14.05 180.23 1,131.03 971.61 -77.24 2.16 5,929,884.22 480,958.51 3.24 77.24 MWD+IFR-AK-CAZ-SC (2) 1,235.37 16.44 182.10 1,226.46 1,067.04 -103.24 1.60 5,929,858.22 480,957.89 2.47 103.24 GYD-GC-MS (3) 1,268.21 16.80 181.77 1,257.93 1,098.51 -112.62 1.28 5,929,848.83 480,957.55 1.13 112.62 GYD-GC-MS (3) 1,363.53 19.53 183.01 1,348.49 1,189.07 -142.31 0.02 5,929,819.15 480,956.21 2.89 142.31 GYD-GC-MS (3) 1,458.57 23.46 180.97 1,436.91 1,277.49 -177.10 -1.14 5,929,784.37 480,954.97 4.21 177.10 GYD-GC-MS (3) 1,552.96 23.93 181.31 1,523.34 1,363.92 -215.03 -1.89 5,929,746.45 480,954.12 0.52 215.03 GYD-GC-MS (3) 1,647.75 26.47 180.85 1,609.10 1,449.68 -255.38 -2.64 5,929,706.11 480,953.26 2.69 255.38 GYD-GC-MS (3) 1,706.01 28.54 181.70 1,660.77 1,501.35 -282.27 -3.25 5,929,679.21 480,952.59 3.62 282.27 MWD+IFR-AK-CAZ-SC (4) 1,742.17 28.92 181.97 1,692.48 1,533.06 -299.65 -3.81 5,929,661.84 480,951.99 1.11 299.65 MWD+IFR-AK-CAZ-SC (4) 1,800.98 30.25 180.34 1,743.62 1,584.20 328.67 -4.38 5,929,632.82 480,951.34 2.64 328.67 MWD+IFR-AK-CAZ-SC (4) 1,895.37 32.99 178.95 1,823.99 1,664.57 -378.15 -4.05 5,929,583.35 480,951.54 3.00 378.15 MWD+IFR-AK-CAZ-SC (4) 1,990.04 35.43 180.16 1,902.28 1,742.86 -431.37 -3.66 5,929,530.13 480,951.80 2.68 431.37 MWD+IFR-AK-CAZ-SC (4) 2,084.68 37.23 179.95 1,978.52 1,819.10 -487.44 3.71 5,929,474.07 480,951.61 1.91 487.44 MWD+IFR-AK-CAZ-SC (4) 2,179.47 40.13 181.04 2,052.51 1,893.09 546.67 -4.24 5,929,414.85 480,950.93 3.14 546.67 MWD+IFR-AK-CAZ-SC (4) 2,273.75 45.00 180.74 2,121.93 1,962.51 510.41 -5.22 5,929,351.11 480,949.79 5.17 610.41 MWD+IFR-AK-CAZ-SC (4) 2,368.71 50.10 180.43 2,186.00 2,026.58 580.45 5.93 5,929,281.08 480,948.90 5.38 680.45 MWD+IFR-AK-CAZ-SC (4) 2,463.14 52.68 180.54 2,244.92 2,085.50 -754.23 -6.55 5,929,207.31 480,948.09 2.73 754.23 MWD+IFR-AK-CAZ-SC (4) 2,557.36 54.45 180.72 2,300.88 2,141.46 -830.03 -7.39 5,929,131.53 480,947.07 1.88 830.03 MWD+IFR-AK-CAZ-SC (4) 2,651.98 60.54 179.72 2,351.70 2,192.28 -909.79 -7.67 5,929,051.78 480,946.58 6.50 909.79 MWD+IFR-AK-CAZ-SC (4) 2,747.27 63.88 180.12 2,396.12 2,236.70 -994.07 -7.56 5,928,967.50 480,946.48 3.52 994.07 MWD+IFR-AK-CAZ-SC (4) 2,841.53 66.56 179.82 2,435.63 2,276.21 -1,079.65 -7.51 5,928,881.93 480,946.31 2.86 1,079.65 MWD+IFR-AK-CAZ-SC (4) 2,936.22 69.56 180.15 2,471.00 2,311.58 -1,167.47 -7.49 5,928,794.12 480,946.11 3.18 1,167.47 MWD+IFR-AK-CAZ-SC (4) 3,030.34 74.04 180.14 2,500.39 2,340.97 -1,256.86 -7.72 5,928,704.74 480,945.66 4.76 1,256.86 MWD+IFR-AK-CAZ-SC (4) 3,123.81 76.26 180.47 2,524.34 2,364.92 -1,347.20 -8.20 5,928,614.41 480,944.95 2.40 1,347.20 MWD+IFR-AK-CAZ-SC (4) 3,219.51 75.66 180.15 2,547.56 2,388.14 -1,440.04 -8.70 5,928,521.58 480,944.22 0.71 1,440.04 MWD+IFR-AK-CAZ-SC (4) 3,313.02 76.18 179.46 2,570.31 2,410.89 -1,530.74 -8.39 5,928,430.89 480,944.30 0.91 1,530.74 MWD+IFR-AK-CAZ-SC (4) 3,408.92 75.73 179.83 2,593.58 2,434.16 -1,623.77 -7.82 5,928,337.87 480,944.64 0.60 1,623.77 MWD+IFR-AK-CAZ-SC (4) 3,496.13 74.56 181.11 2,615.94 2,456.52 -1,708.06 -8.51 5,928,253.59 480,943.74 1.95 1,708.06 MWD+IFR-AK-CAZ-SC (4) 3,580.83 74.66 179.77 2,638.42 2,479.00 -1,789.71 -9.13 5,928,171.94 480,942.90 1.53 1,789.71 MWD+IFR-AK-CAZ-SC (5) 3,675.26 75.27 180.10 2,662.92 2,503.50 -1,880.91 -9.03 5,928,080.76 480,942.78 0.73 1,880.91 MWD+IFR-AK-CAZ-SC (5) 3,769.72 75.55 179.55 2,686.71 2,527.29 -1,972.32 -8.75 5,927,989.35 480,942.83 0.64 1,972.32 MWD+IFR-AK-CAZ-SC (5) 3,864.22 75.44 178.40 2,710.38 2,550.96 -2,063.79 -7.11 5,927,897.89 480,944.23 1.18 2,063.79 MWD+IFR-AK-CAZ-SC (5) 3,958.95 75.66 178.44 2,734.02 2,574.60 -2,155.49 -4.58 5,927,806.19 480,946.53 0.24 2,155.49 MWD+IFR-AK-CAZ-SC (5) 4,052.53 75.49 179.34 2,757.33 2,597.91 -2,246.10 -2.83 5,927,715.58 480,948.06 0.95 2,246.10 MWD-INC_ONLY (6) 4,148.08 75.58 180.24 2,781.20 2,621.78 -2,338.62 -2.49 5,927,623.07 480,948.16 0.92 2,338.62 MWD+IFR-AK-CAZ-SC (7) 12/18/2018 12:40:05PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 25-315 Project: Kuparuk River Unit TVD Reference: Actual: 39.42+120 @ 159.42usft Site: Kuparuk 2S Pad MD Reference: Actual: 39.42+120 @ 159.42usft Well: 2S-315 North Reference: True Wellbore: 25-315 Survey Calculation Method: Minimum Curvature Design: 2S-315 Database: EDT 14 Alaska Production Survey 12/la/2018 12:40:05PM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,242.33 75.41 182.09 2,804.81 2,645.39 -2,429.85 -4.34 5,927,531.86 480,946.08 1.91 2,429.85 MWD+IFR-AK-CAZ-SC (7) 4,337.69 75.47 161.97 2,828.78 2,669.36 -2,522.09 -7.61 5,927,439.64 480,942.57 0.14 2,522.09 MWD+IFR-AK-CAZ-SC (7) 4,431.85 75.66 181.15 2,852.25 2,692.83 -2,613.24 -10.10 5,927,348.50 480,939.86 0.87 2,613.24 MWD+IFR-AK-CAZ-SC (7) 4,526.89 75.37 180.24 2,876.03 2,716.61 -2,705.25 -11.21 5,927,256.51 480,938.51 0.98 2,705.25 MWD+IFR-AK-CAZ-SC (7) 4,621.69 75.66 178.03 2,899.74 2,740.32 -2,797.02 -9.83 5,927,164.74 480,939.67 2.28 2,797.02 MWD+IFR-AK-CAZ-SC (7) 4,716.57 75.41 177.38 2,923.44 2,764.02 -2,888.82 5.15 5,927,072.94 480,943.12 0.71 2,888.82 MWD+IFR-AK-CAZ-SC (7) 4,810.43 75.32 175.73 2,947.16 2,787.74 -2,979.46 -0.69 5,926,982.29 480,948.34 1.70 2,979.46 MWD+IFR-AK-CAZ-SC (7) 4,904.92 75.57 175.14 2,970.90 2,811.48 5,070.63 6.59 5,926,891.12 480,955.39 0.66 3,070.63 MWD+IFR-AK-CAZ-SC (7) 5,001.22 75.41 177.22 2,995.03 2,835.61 -3,163.65 12.80 5,926,798.10 480,961.37 2.10 3,163.65 MWD+IFR-AK-CAZ-SC (7) 5,096.02 75.81 178.08 3,018.59 2,859.17 -3,255.39 16.57 5,926,706.35 480,964.90 0.97 3,255.39 MWD+IFR-AK-CAZ-SC (7) 5,189.62 75.83 178.36 3,041.52 2,882.10 5,346.10 19.38 5,926,615.65 480,967.49 0.29 3,346.10 MWD+IFR-AK-CAZ-SC (7) 5,284.83 75.70 180.28 3,064.94 2,905.52 -0,438.37 20.48 5,926,523.38 480,968.35 1.96 3,438.37 MWD+IFR-AK-CAZ-SC (7) 5,379.72 75.73 182.46 3,088.35 2,928.93 -3,530.30 18.28 5,926,431.47 480,965.92 2.23 3,530.30 MWD+IFR-AK-CAZ-SC (7) 5,472.86 75.72 180.28 3,111.32 2,951.90 -0,620.53 16.12 5,926,341.25 480,963.54 2.27 3,620.53 MWD+IFR-AK-CAZ-SC (7) 5,568.47 75.47 181.90 3,135.11 2,975.69 -3,713.11 14.36 5,926,248.68 480,961.54 1.66 3,713.11 MWD+IFR-AK-CAZ-SC (7) 5,662.32 75.84 181.26 3,158.36 2,998.94 -3,804.00 11.86 5,926,157.81 480,958.81 0.77 3,804.00 MWD+IFR-AK-CAZ-SC (7) 5,757.75 75.55 179.50 3,181.94 3,022.52 -3,896.47 11.24 5,926,065.35 480,957.96 1.81 3,896.47 MWD+IFR-AK-CAZ-SC (7) 5,851.75 75.74 177.56 3,205.25 3,045.83 -3,987.50 13.58 5,925,974.33 480,960.07 2.01 3,987.50 MWD+IFR-AK-CAZ-SC (7) 5,948.14 75.96 178.96 3,228.82 3,069.40 -4,080.92 16.42 5,925,880.91 480,962.67 1.43 4,080.92 MWD+IFR-AK-CAZ-SC (7) 6,043.06 75.64 181.16 3,252.10 3,092.68 -4,172.93 16.32 5,925,788.91 480,962.34 2.27 4,172.93 MWD+IFR-AK-CAZ-SC (7) 6,137.24 75.82 182.59 3,275.32 3,115.90 4,264.15 13.33 5,925,697.70 480,959.12 1.48 4,264.15 MWD+IFR-AK-CAZ-SC (7) 6,231.67 75.99 184.23 3,298.32 3,138.90 -4,355.57 7.89 5,925,606.30 480,953.45 1.69 4,355.57 MWD+IFR-AK-CAZ-SC (7) 6,325.89 75.45 185.53 3,321.56 3,162.14 -4,446.55 0.12 5,925,515.36 480,945.45 1.45 4,446.55 MWD+IFR-AK-CAZ-SC (7) 6,420.31 75.87 184.60 3,344.94 3,185.52 4,537.67 -7.96 5,925,424.27 480,937.15 1.05 4,537.67 MWD+IFR-AK-CAZ-SC (7) 6,515.41 75.74 182.32 3,368.27 3,208.85 4,629.69 -13.52 5,925,332.27 480,931.35 2.33 4,629.69 MWD+IFR-AK-CAZ-SC (7) 6,609.75 75.52 181.96 3,391.68 3,232.26 -4,721.02 -16.93 5,925,240.96 480,927.71 0.44 4,721.02 MWD+IFR-AK-CAZ-SC (7) 6,704.42 75.87 180.97 3,415.07 3,255.65 4,812.72 -19.28 5,925,149.27 480,925.13 1.08 4,812.72 MWD+IFR-AK-CAZ-SC (7) 6,795.53 75.52 179.60 3,437.59 3,278.17 4,901.00 -19.72 5,925,061.00 480,924.47 1.51 4,901.00 MWD+IFR-AK-CAZ-SC (7) 6,894.43 75.84 179.33 3,462.05 3,302.63 -4,996.82 -18.82 5,924,965.19 480,925.12 0.42 4,996.82 MWD+IFR-AK-CAZ-SC (7) 6,988.29 75.77 179.86 3,485.06 3,325.64 -5,087.81 -18.18 5,924,874.20 480,925.54 0.55 5,087.81 MWD+IFR-AK-CAZ-SC (7) 7,083.04 75.71 181.56 3,508.40 3,348.98 -5,179.63 -19.32 5,924,782.40 480,924.17 1.74 5,179.63 MWD+IFR-AK-CAZ-SC (7) 7,177.11 75.68 181.85 3,531.65 3,372.23 5,270.75 -22.03 5,924,691.30 480,921.23 0.30 5,270.75 MWD+IFR-AK-CAZ-SC (7) 7,272.39 75.53 181.65 3,555.33 3,395.91 5,362.99 -24.85 5,924,599.07 480,918.17 0.26 5,362.99 MWD+IFR-AK-CAZ-SC (7) 7,367.43 75.53 180.28 3,579.08 3,419.66 -5,455.00 -26.40 5,924,507.08 480,916.39 1.40 5,455.00 MWD+IFR-AK-CAZ-SC (7) 7,461.77 75.59 179.51 3,602.61 3,443.19 -5,546.36 -26.23 5,924,415.73 480,916.33 0.79 5,546.36 MWD+IFR-AK-CAZ-SC (7) 7,557.06 75.56 178.84 3,626.35 3,466.93 5,638.64 -24.90 5,924,323.46 480,917.43 0.68 5,638.64 MWD+IFR-AK-CAZ-SC (7) 7,651.89 75.59 178.84 3,649.97 3,490.55 -5,730.46 -23.04 5,924,231.64 480,919.05 0.03 5,730.46 MWD+IFR-AK-CAZ-SC (7) 7,746.38 75.69 179.41 3,673.41 3,513.99 -5,821.98 -21.64 5,924,140.12 480,920.22 0.59 5,621.98 MWD+IFR-AK-CAZ-SC (7) 7,840.71 75.65 180.15 3,696.75 3,537.33 -5,913.38 -21.29 5,924,048.73 480,920.34 0.76 5,913.38 MWD+IFR-AK-CAZ-SC (7) 7,936.10 75.62 180.77 3,720.42 3,561.00 -6,005.78 -22.03 5,923,956.34 480,919.37 0.63 6,005.78 MWD+IFR-AK-CAZ-SC (7) 12/la/2018 12:40:05PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-315 Project: Kuparuk River Unit TVD Reference: Actual: 39.42+120 @ 159.42usft Site: Kuparuk 2S Pad MD Reference: Actual: 39.42+120 @ 159.42usft Well: 2S-315 North Reference: True Wellbore: 2S-315 Survey Calculation Method: Minimum Curvature Design: 2S-315 Database: EDT 14 Alaska Production Survey 12118/2018 12:40:05PM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Easting DLS Section (usft) (°) r) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 8,030.18 75.53 180.08 3,743.86 3,584.44 -6,096.89 -22.71 5,923,865.24 480,918.46 0.72 6,096.89 MWD+IFR-AK-CAZ-SC (7) 8,124.26 75.60 179.57 3,767.31 3,607.89 -6,168.00 -22.43 5,923,774.14 480,918.51 0.53 6,188.00 MWD+IFR-AK-CAZ-SC (7) 8,218.87 75.65 178.27 3,790.80 3,631.38 -6,279.63 -20.70 5,923,682.52 480,920.00 1.33 6,279.63 MWD+IFR-AK-CAZ-SC (7) 8,313.35 75.68 178.30 3,814.19 3,654.77 -6,371.13 -17.97 5,923,591.02 480,922.51 0.04 6,371.13 MWD+IFR-AK-CAZ-SC (7) 8,408.24 75.71 177.80 3,837.64 3,678.22 -6,463.02 -14.84 5,923,499.13 480,925.41 0.51 6,463.02 MWD+IFR-AK-CAZ-SC (7) 8,501.98 75.62 177.28 3,860.85 3,701.43 -6,553.76 -10.94 5,923,408.39 480,929.08 0.55 6,553.76 MWD+IFR-AK-CAZ-SC (7) 8,598.76 75.64 176.82 3,884.87 3,725.45 -6,647.39 -6.11 5,923,314.76 480,933.67 0.46 6,647.39 MWD+IFR-AK-CAZ-SC (7) 8,691.84 75.93 176.49 3,907.72 3,748.30 -6,737.46 -0.85 5,923,224.68 480,938.70 0.46 6,737.46 MWD+IFR-AK-CAZ-SC (7) 8,788.14 75.64 177.01 3,931.37 3,771.95 -6,830.67 4.44 5,923,131.48 480,943.76 0.60 6,830.67 MWD+IFR-AK-CAZ-SC (7) 8,882.82 75.65 181.25 3,954.85 3,795.43 -6,922.36 5.64 5,923,039.79 480,944.92 4.34 6,922.36 MWD+IFR-AK-CAZ-SC (7) 8,937.20 75.70 182.71 3,968.31 3,808.89 -6,975.01 4.02 5,922,987.15 480,942.97 2.60 6,975.01 MWD+IFR-AK-CAZ-SC (7) 8,977.69 75.93 184.05 3,978.23 3,818.81 -7,014.20 1.70 5,922,947.97 480,940.55 3.26 7,014.20 MWD+IFR-AK-CAZ-SC (7) 9,070.45 75.74 185.04 4,000.93 3,841.51 -7,103.85 -5.43 5,922,858.34 480,933.20 1.05 7,103.85 MWD+IFR-AK-CAZ-SC (7) 9,164.44 75.68 183.41 4,024.13 3,864.71 -7,194.68 -12.14 5,922,767.54 480,926.26 1.68 7,194.68 MWD+IFR-AK-CAZ-SC (7) 9,259.10 75.68 181.11 4,047.55 3,888.13 -7,286.32 -15.75 5,922,675.91 480,922.42 2.35 7,286.32 MWD+IFR-AK-CAZ-SC (7) 9,355.18 75.87 179.73 4,071.16 3,911.74 -7,379.45 -16.43 5,922,582.80 480,921.50 1.41 7,379.45 MWD+IFR-AK-CAZ-SC (7) 9,449.69 75.55 179.86 4,094.49 3,935.07 -7,471.04 -16.11 5,922,491.22 480,921.60 0.36 7,471.04 MWD+IFR-AK-CAZ-SC (7) 9,543.44 75.68 179.73 4,117.78 3,958.36 -7,561.85 -15.78 5,922,400.42 480,921.69 0.19 7,561.85 MWD+IFR-AK-CAZ-SC (7) 9,637.98 75.80 178.57 4,141.07 3,981.65 -7,653.46 -14.42 5,922,308.81 480,922.82 1.20 7,653.46 MWD+IFR-AK-CAZ-SC (7) 9,732.52 75.77 179.41 4,164.28 4,004.86 -7,745.09 -12.81 5,922,217.18 480,924.20 0.86 7,745.09 MWD+IFR-AK-CAZ-SC (7) 9,827.10 75.77 182.03 4,187.54 4,028.12 -7,836.76 -13.96 5,922,125.53 480,922.82 2.69 7,836.76 MWD+IFR-AK-CAZ-SC (7) 9,921.37 75.84 181.96 4,210.65 4,051.23 -7,928.09 -17.14 5,922,034.22 480,919.41 0.10 7,928.09 MWD+IFR-AK-CAZ-SC (7) 9,953.43 75.67 181.95 4,218.54 4,059.12 -7,959.15 -18.20 5,922,003.17 480,918.27 0.53 7,959.15 MWD+IFR-AK-CAZ-SC (7) 9,974.71 75.94 181.96 4,223.76 4,064.34 -7,979.77 -18.90 5,921,982.55 480,917.52 1.27 7,979.77 MWD+IFR-AK-CAZ-SC (8) 10,067.62 75.75 182.51 4,246.48 4,087.06 -8,069.79 -22.42 5,921,892.55 480,913.78 0.61 8,069.79 MWD+IFR-AK-CAZ-SC (8) 10,162.51 75.94 183.79 4,269.69 4,110.27 -8,161.65 -27.47 5,921,800.70 480,908.49 1.32 8,161.65 MWD+IFR-AK-CAZ-SC (8) 10,257.24 75.69 183.98 4,292.90 4,133.48 -8,253.28 -33.70 5,921,709.10 480,902.03 0.33 8,253.28 MWD+IFR-AK-CAZ-SC (8) 10,352.60 75.88 182.68 4,316.32 4,156.90 -8,345.57 -39.07 5,921,616.84 480,896.43 1.34 8,345.57 MWD+IFR-AK-CAZ-SC (8) 10,449.00 75.73 181.58 4,339.96 4,180.54 -8,438.96 -42.54 5,921,523.47 480,892.72 1.12 8,438.96 MWD+IFR-AK-CAZ-SC (8) 10,542.25 75.78 181.05 4,362.90 4,203.48 -8,529.32 -44.61 5,921,433.12 480,890.42 0.55 8,529.32 MWD+IFR-AK-CAZ-SC (8) 10,637.26 75.88 179.28 4,386.16 4,226.74 -8,621.43 -44.88 5,921,341.02 480,889.93 1.81 8,621.43 MWD+IFR-AK-CAZ-SC (8) 10,732.16 75.70 177.18 4,409.46 4,250.04 -8,713.38 -42.04 5,921,249.07 480,892.53 2.15 8,713.38 MWD+IFR-AK-CAZ-SC (8) 10,826.51 75.66 176.99 4,432.80 4,273.38 -8,804.68 -37.39 5,921,157.77 480,896.95 0.20 8,804.68 MWD+IFR-AK-CAZ-SC (8) 10,922.38 75.82 178.86 4,456.42 4,297.00 -8,897.53 -34.02 5,921,064.92 480,900.08 1.90 8,897.53 MWD+IFR-AK-CAZ-SC (8) 11,015.91 75.72 178.68 4,479.41 4,319.99 -8,9BB.17 -32.08 5,920,974.29 480,901.80 0.22 8,988.17 MWD+IFR-AK-CAZ-SC (8) 11,110.37 75.79 178.48 4,502.65 4,343.23 -9,079.69 -29.81 5,920,882.76 480,903.84 0.22 9,079.69 MWD+IFR-AK-CAZ-SC (8) 11,204.75 75.95 178.99 4,525.69 4,366.27 -9,171.20 -27.79 5,920,791.27 480,905.63 0.55 9,171.20 MWD+IFR-AK-CAZ-SC (8) 11,299.38 75.24 178.94 4,549.23 4,389.81 -9,262.84 -26.13 5,920,699.63 480,907.05 0.75 9,262.84 MWD+IFR-AK-CAZ-SC (8) 11,393.94 76.21 179.12 4,572.55 4,413.13 -9,354.46 -24.56 5,920,608.01 480,908.37 1.04 9,354.46 MWD+IFR-AK-CAZ-SC (8) 11,488.27 75.49 181.81 4,595.61 4,436.19 -9,445.92 -25.32 5,920,516.57 480,907.40 2.87 9,445.92 MWD+IFR-AK-CAZ-SC (8) 12118/2018 12:40:05PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-315 Project: Kuparuk River Unit TVD Reference: Actual: 39.42+120 @ 159.42usft Site: Kuparuk 2S Pad MD Reference: Actual: 39.42+120 @ 159.42usft Well: 2S-315 North Reference: True Wellbore: 2S-315 Survey Calculation Method: Minimum Curvature Design: 2S-315 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,582.76 76.10 182.33 4,618.80 4,459.38 -9,537.46 -28.63 5,920,425.05 480,903.86 0.84 9,537.46 MWD+IFR-AK-CAZ-SC (8) 11,676.84 75.82 181.15 4,641.62 4,482.20 -9,628.68 -31.40 5,920,333.84 480,900.86 1.25 9,628.68 MWD+IFR-AK-CAZ-SC (8) 11,772.02 75.73 179.99 4,665.01 4,505.59 -9,720.94 -32.32 5,920,241.59 480,899.71 1.19 9,720.94 MWD+IFR-AK-CAZ-SC (8) 11,866.44 75.92 181.78 4,688.14 4,528.72 -9,812.47 -33.74 5,920,150.08 480,898.06 1.85 9,812.47 MWD+IFR-AK-CAZ-SC (8) 11,961.12 75.78 180.03 4,711.28 4,551.86 -9,904.26 -35.19 5,920,058.30 480,896.38 1.80 9,904.26 MWD+IFR-AK-CAZ-SC (8) 12,056.00 75.88 178.88 4,734.51 4,575.09 -9,996.25 -34.31 5,919,966.32 480,897.02 1.18 9,996.25 MWD+IFR-AK-CAZ-SC (8) 12,151.37 75.82 178.58 4,757.83 4,598.41 -10,088.70 -32.26 5,919,873.87 480,898.84 0.31 10,088.70 MWD+IFR-AK-CAZ-SC (8) 12,245.63 75.85 178.37 4,780.89 4,621.47 -10,180.06 -29.83 5,919,782.51 480,901.04 0.22 10,180.06 MWD+IFR-AK-CAZ-SC (8) 12,340.60 75.67 178.88 4,804.25 4,644.83 -10,272.09 -27.62 5,919,690.49 480,903.02 0.55 10,272.09 MWD+IFR-AK-CAZ-SC (8) 12,435.27 75.38 179.84 4,827.92 4,668.50 -10,363.74 -26.60 5,919,598.84 480,903.81 1.03 10,363.74 MWD+IFR-AK-CAZ-SC (8) 12,530.06 75.35 180.39 4,851.87 4,692.45 -10,455.46 -26.78 5,919,507.13 480,903.40 0.56 10,455.46 MWD+IFR-AK-CAZ-SC (8) 12,625.16 75.32 179.64 4,875.94 4,716.52 -10,547.46 -26.80 5,919,415.14 480,903.14 0.76 10,547.46 MWD+IFR-AK-CAZ-SC (8) 12,719.49 75.27 179.23 4,899.89 4,740.47 -10,638.70 -25.90 5,919,323.91 480,903.81 0.42 10,638.70 MWD+IFR-AK-CAZ-SC (8) 12,814.36 74.64 178.22 4,924.52 4,765.10 -10,730.29 -23.87 5,919,232.32 480,905.61 1.22 10,730.29 MWD+IFR-AK-CAZ-SC (8) 12,908.52 72.40 176.72 4,951.23 4,791.81 -10,820.48 -19.89 5,919,142.13 480,909.36 2.83 10,820.48 MWD+IFR-AK-CAZ-SC (8) 13,003.14 70.29 176.02 4,981.49 4,822.07 -10,909.95 -14.22 5,919,052.66 480,914.81 2.34 10,909.95 MWD+IFR-AK-CAZ-SC (8) 13,098.26 67.17 174.35 5,016.00 4,856.58 -10,998.26 -6.79 5,918,964.34 480,922.01 3.67 10,998.26 MWD+IFR-AK-CAZ-SC (8) 13,192.46 64.02 172.48 5,054.92 4,895.50 -11,083.47 3.03 5,918,879.12 480,931.61 3.80 11,083.47 MWD+IFR-AK-CAZ-SC (8) 13,287.34 61.34 171.60 5,098.46 4,939.04 -11,166.94 14.69 5,918,795.62 480,943.07 2.94 11,166.94 MWD+IFR-AK-CAZ-SC (8) 13,382.78 57.59 170.15 5,146.94 4,987.52 -11,248.09 27.71 5,918,714.44 480,955.88 4.14 11,248.09 MWD+IFR-AK-CAZ-SC (8) 13,476.74 54.73 169.79 5,199.26 5,039.84 -11,324.93 41.29 5,918,637.58 480,969.27 3.06 11,324.93 MWD+IFR-AK-CAZ-SC (8) 13,571.22 51.80 168.97 5,255.76 5,096.34 -11,399.35 55.24 5,918,563.14 480,983.02 3.18 11,399.35 MWD+IFR-AK-CAZ-SC (8) 13,665.93 48.75 167.91 5,316.29 5,156.87 -11,470.71 69.82 5,918,491.75 480,997.42 3.33 11,470.71 MWD+IFR-AK-CAZ-SC (8) 13,760.52 45.95 166.43 5,380.37 5,220.95 -11,538.53 85.24 5,918,423.89 481,012.67 3.18 11,538.53 MWD+IFR-AK-CAZ-SC (8) 13,854.91 45.49 165.05 5,446.27 5,286.85 -11,604.03 101.89 5,918,358.36 481,029.15 1.15 11,604.03 MWD+IFR-AK-CAZ-SC (8) 13,949.39 45.47 162.65 5,512.52 5,353.10 -11,668.72 120.62 5,918,293.62 481,047.72 1.81 11,668.72 MWD+IFR-AK-CAZ-SC (8) 14,045.46 45.53 161.24 5,579.86 5,420.44 -11,733.87 141.86 5,918,228.43 481,068.79 1.05 11,733.87 MWD+IFR-AK-CAZ-SC (8) 14,138.43 45.52 160.55 5,644.99 5,485.57 -11,796.55 163.57 5,918,165.70 481,090.34 0.53 11,796.55 MWD+IFR-AK-CAZ-SC (8) 14,233.43 45.52 159.88 5,711.56 5,552.14 -11,860.33 186.51 5,918,101.87 481,113.12 0.50 11,860.33 MWD+IFR-AK-CAZ-SC (8) 14,328.16 45.51 160.66 5,777.94 5,618.52 -11,923.95 209.33 5,918,038.20 481,135.77 0.59 11,923.95 MWD+IFR-AK-CAZ-SC (8) 14,422.37 44.91 161.49 5,844.31 5,684.89 -11,987.19 231.01 5,917,974.91 481,157.30 0.89 11,987.19 MWD+IFR-AK-CAZ-SC (8) 14,516.48 44.75 162.42 5,911.05 5,751.63 -12,050.27 251.57 5,917,911.78 481,177.69 0.72 12,050.27 MWD+IFR-AK-CAZ-SC (8) 14,565.99 44.71 162.01 5,946.23 5,786.81 -12,083.45 262.21 5,917,878.58 481,188.25 0.59 12,083.45 MWD+IFR-AK-CAZ-SC (8) 14,654.00 44.71 162.01 6,008.77 5,849.35 -12,142.34 281.33 5,917,819.65 481,207.22 0.00 12,142.34 PROJECTED to TD 12/18/2018 12:40:05PM Page 6 COMPASS 5000.14 Build 85D Cement Detail Report 2S-315 String: Production Casing Cement Job: DRILLING ORIGINAL, 11/15/2018 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 12/8/2018 17:45 12/8/2018 21:00 2S-315 Comment Test lines to 4000 psi. Drop bottom plug #1. Pump 45 bbls 12.5 ppg Mud Push II. 6 bpm 470 psi. Drop bottom plug #2. Mix and pump 184.4 bbls 15.8 ppg production cement with 1 ppb Cemnet at 5 bpm 240-150 psi. Wash up to bleeder line. Drop top plug and displace with 9.6 ppg NaCl brine. First 50 bbls of brine were corrosion inhibited. 7 bpm, ICP=324 psi. Reduce rate to 6 bpm at 500 bbls away, 735 psi. Reduce rate to 5 bpm at 600 bbls away, 1071 psi. Reduce rate to 3 bpm at 650 bbls away, 1200 psi.. Bump plugs at 6572 stks. Pressure up to 1700 psi and hold for 5 mins.CIP at 21:00 hrs. Full returns throughout job. Reciprocate 25' strokes. Land on hanger at 6150 stks.— — Cement Stages Stage # <Stage Number?> Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug. Btm Plug? Production Casing 11,300.0 14,558.0 Yes Yes Yes Cement Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 5 5 152.0 1,700.0 1 Yes 125.00 No I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Production Cement 11,300.0 14,558.0 893 G 184.4 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.07 15.80 105.2 5.91 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push II 10,126.0 11,300.0 45.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label r Page 1/1 Report Printed: 12/17/2018 Cement Summary Report 2S-315 String: Conductor Cement Job: DRILLING ORIGINAL, 11/15/2018 00:00 Cement Fluids & Additives Wellbore Des Start Date End Date Fluid Vol Pumped (bbl) Dens (Ib/gal) Thick Time (hr) 2S-315 Conductor Cement 11/29/201410:00 11/29/201418:15 Conductor cement 15.70 2S-315 Conductor Cement 11/29/201410:00 11/29/201418:15 Conductor cement 15.70 2S-315 Surface Casing Cement 11/19/2018 22:00 11/20/2018 03:00 Lead Cement 488.5 11.00 5.43 2S-315 Surface Casing Cement 11/19/2018 22:00 11/20/2018 03:00 Tail Cement 63.3 15.80 4.37 2S-315 Surface Casing Cement 11/19/2018 22:00 11/20/2018 03:00 CW100 40.2 8.34 2S-315 Surface Casing Cement 11/19/2018 22:00 11/20/2018 03:00 Mud push 11 78.4 10.50 2S-315 Production Casing Cement 12/8/2018 17:45 12/8/2018 21:00 Production Cement 184.4 15.80 5.91 2S-315 Production Casing Cement 12/8/2018 17:45 12/8/2018 21:00 Mud Push 11 45.0 1 1 Page 1/1 Report Printed: 12/17/2018 Cement Detail Report 2S-315 String: Conductor Cement Job: DRILLING ORIGINAL, 11/15/2018 00:00 Cement Details Description Conductor Cement Cementing Start Date 11/29/201410:00 Cementing End Date 11/29/201418:15 Wellbore Name 2S-315 Comment CH2MHill drilled 42" hole to 80' below ground level, set 16" 62.58# APISL Grade B Insulated Conductor. SLB cemented in two stages with 15.7ppg Arctic Set 1 cement with 185 sacks. Sealed Pan Cellar is 5' deep, 6' wide. Cement Stages Stage # 1 Description Conductor Cement Objective Tack conductor in place Top Depth (ftKB) 80.0 Bottom Depth (ftKB) 119.0 Full Return? No Vol Cement... Top Plug. No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No I Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 72 x sacks of Arctic Set 1 Cement slurry at 15.7ppg, 60°F slurry temp, -3°F ambient temp, 58.9°F water temp Cement Fluids & Additives Fluid Fluid Type Conductor cement Fluid Description Estimated Top (ftKB) 80.0 Est Btm (ftKB) 120.0 Amount (sacks) 72 Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) 15.70 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 2 Description Conductor Cement Objective Cement to surface Top Depth (ftKB) 39.0 Bottom Depth (ftKB) 80.0 Full Return? No Vol Cement... Top Plug? INo INo Btm Plug? Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 113 x sacks of Arctic Set 1 Cement slurry at 15.7ppg, 55.5°F slurry temp, -6°F ambient temp, 58°F water temp. Cement in place at 18:15 hrs Cement Fluids & Additives Fluid Fluid Type Conductor cement Fluid Description Estimated Top (ftKB) 39.0 Est Btm (ftKB) Amount 80.0 113 (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic 15.70 Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/17/2018 Cement Detail Report 2S-315 String: Surface Casing Cement Job: DRILLING ORIGINAL, 11/15/2018 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 11/19/2018 22:00 11/20/2018 03:00 2S-315 Comment Line up & SLB pump 5 bbls water. Pressure test lines to 3500 psi, good. Pump 40.2 bbis of CW100 @ 4.8 bpm, 153 psi, FO 14%, PU 170K, SO 125K. Pump 78.4 bbls of 10.5 ppg MP II @ 4.5 bpm, 116 psi, FO 12%. Drop bottom plug & start batching lead. Pump 488.5 bbls of 11.0 ppg lead cement at 5.6 bpm, 140-276 psi, FO 13%, . PU 172K, SO 96K. CW100 at surface with 460 bbis of lead away. Batch and pump 63.3 bbls of 15.8 ppg tail cement @ 4.8 bpm, 65-350 psi, FO 16% MP II at surface with 10 bbls tail away. Land on hanger with 20 bblsTail away. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace wl 9.6 ppg spud mud @ 8 bpm, 300-1070 psi, FO 10-32%.11 ppg lead cement at surface at 90 bbls of displacement away. Lose returns at 272 bbls displacement away Reduce rate to 6 bpm, then 5 bpm, 1070 ps to 914 psi, FO 0%. Bump plug with 3243 strokes (325 bbls), Pressure up to 1600 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 03:00 hrs 11/20/2018. 170.5 bbl 11 ppg cement to surface. Lost 70 bbls total during job. Cement Stages Stage # <Stage Number?> Description Objective i Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug. Btm Plug? Surface Casing Cement 42.5 3,578.0 No 187.0 Yes Yes Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 2 6 1,070.0 1,600.0 1 Yes 29.00 No I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Line up & SLB pump 5 bbls water. Pressure test lines to 3500 psi, good. Pump 40.2 bbls of CW100 @ 4.8 bpm, 153 psi, FO 14%, PU 170K, SO 125K. Pump 78.4 bbls of 10.5 ppg MP II @ 4.5 bpm, 116 psi, FO 12%. Drop bottom plug & start batching lead. Pump 488.5 bbls of 11.0 ppg lead cement at 5.6 bpm, 140-276 psi, FO 13%, . PU 172K, SO 96K. CW100 at surface with 460 bbls of lead away. Batch and pump 63.3 bbls of 15.8 ppg tail cement @ 4.8 bpm, 65-350 psi, FO 16% MP II at surface with 10 bbls tail away. Land on hanger with 20 bbls tail away. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 9.6 ppg spud mud @ 8 bpm, 300-1070 psi, FO 10-32%.11 ppg Tail cement at surface at 90 bbls of displacement away. Lose returns at 272 bbls displacement away Reduce rate to 6 bpm, then 5 bpm, 1070 ps to 914 psi, FO"0*/o-:-E6mp plug with 3243 strokes (325 bbls), Pressure up to 1600 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 03:00 hrs 11/20/201 .170.5 bbl 11 ppg cement to surface. Lost 70 bbls total during job. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 42.9 3,070.9 1,436 G 488.5 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.87 11.00 56.5 5.43 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 3,070.9 3,578.0 306 G 63.3 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (0) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.14 15.80 160.5 4.37 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks)Class Volume Pumped (bbl) CW 100 0.0 0.0 40.2 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud push II 0.0 0.0 78.4 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label v� Page 1/1 Report Printed: 12/17/2018 (D � n � (D N 3 N N U w in a. n 0 v (n 3 m cn cu 0 o Q � (D cc cn n v p = Z3 0- 0 a (` .J Q�1 V O r` L, 0 3 o Q N0 o v W (D D< U3 vU) c CD- oCD (n — o p 1 O �6I 00 Q 8 ® 1 0 o N Cn 1 C 1 1 p N T W 0 o n 1 i co O OJ n O m O N in LN fw fey Ln Un NJ 4J N (n VJ r) cn GJ N to l7 C < (n (n (n (n (0 cri v W I� VJ �� UJ I� UJ �LX UJ I� VJ �� W I� .; V1 �L cc -+ V1 J �+ 4J1 L -n 0 r -n m � t n m J 61: m �� 7 � C � C 3 C �• C ^ � l , •� v N ^ o o ca' o °i � Q a Q Q _ o (D (D CT 6o (. (Dc lA ,� GI O as O f�D rt t0 s (fl ss�.o 9 4 fR ni W 7 C CD i2. CD 4< rri rm �•�'' Y? a p r- � ' a c e Lo 0 0 0 � 0n �� CL '_01 iA O W y�7 � d �..+ i j � (D r 6C] r t0 J 3 ao "a m O N U) O c V i rn O V) Q (D z.o �. .y a O n vx" �7 cn <in N V. W O . � O vi � O N D d �w (3� _0 CA ✓? uJ k+i IdJ UNi �• n -00 Q c� rT co oma oma f J W w p ZY N v V� Ch -41 o �= Q o �? C/) �, v (D w C=) cn 0 O (D X 3 c w o < CD CY) W'. Q N W O N Dim ow0 m 0 0 mCA m C N mum m < UI c ,�—/ m cn 1 N N W C C) O � N N o W Nw 3 o Q N0 o v W (D D< U3 vU) c CD- oCD (n — o p 1 O �6I 00 Q D(D m m N 0 o N Cn 1 C 1 0 o n 1 . zrO Q co O OJ n O w O O cc X p (D 1 > =_ r TT o O CD (0 cri v CD 77-1 OL) 6 O n � C) 3 o Q N0 o v W (D D< U3 vU) c CD- oCD (n — o p 1 O �6I 00 Q THE STATE "'ALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Exploratory Pool, KRU 2S-315 Permit to Drill Number: 218-110 Sundry Number: 318-544 Dear Mr. Alvord: Alaska ail and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.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, Hollis S. French A Chair DATED this 4 day of December, 2018. DEC 0 7i— 10' RBDMS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 PECEIVLD DEL0 5 2018 A 0 G C, G 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El . Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory Q Development ❑ Stratigraphic ❑ Service ❑ 218-110 ` 3. Address: 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-103-20776-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? KRU 2S-315 Will planned perforations require a spacing exception? Yes ❑ No Z 57, /s- 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL025603 / ADL025608 Kuprauk River Field / Exploratory ' 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): Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 119 119 Surface 3530 10.75 3571 2636 5210 2470 Intermediate Production Planned @ 14601 7.625 Planned @ 14639 Planned @ 5998 6890 470 Liner Perforation Depth MD (ft): Perforation DepthTubing Size: Tubing Grade: Tubing MD (ft): 14173 - 14203 5670-5690 3.5 L-80 Planned @ 14,290' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premier Packer 14,034' and 14,260' 12. Attachments: Proposal Summary 0 Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑� Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/8/2018 OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chip Alvord Contact Name: Nick Lehman y Authorized Title: Drilling Manager L L`/LL d Contact Email: nick.r.lehman conoco hllli s.com vty Contact Phone: 907-263-4951 (� J Authorized Signatur : Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 11' I Plug Integrity ❑ BOP Test [►� Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3.j 00 �5 ,r r. ' s (- 71018 RB �M —DEC Post Initial Injection MIT Req'd? Yes ❑ No ❑ / %� , / I� f� �� f J Spacing Exception Required? Yes No Subsequent Form Required: .- Lio 7 / cid W r� ►C ❑ 0' /D l APPROVED BY 1 tC (.011C Approved by: COMMISSIONER THE COMMISSION Date: Z (.O Sit,� lz Submit Form and appIICo Ji(;r12NA'4wthe'dte of approval. 10-403 Revised 4/2017 At2pp(roVved "� Attachments in Duplicate Application for Sundry to Perforate, Well 2S-315 Saved: 5 -Dec -18 December 5, 2018 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry to Perforate 2S-315, a Cairn Exploration Well Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to perforate 2S-315 and run a selective completion on 2S- 315, a Cairn exploration well drilled from 2S -pad. The purpose of perforating on -rig and running a selective completion is to allow for effective fracture stimulation of the interval based on observations made while drilling through the Cairn. The expected operational date for perforating is December 81h, 2018. It is planned to use rig Doyon 142. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403. 2. Proposed selective completion procedure 3. 2S-315 Post -Rig Schematic. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Nick Lehman at 907-263-4951 (nick.r.lehman@cop.com) or Chip Alvord at 265-6120. Sincerely, c Nick Lehman Drilling Engineer Doyon 142 2S-315 Selective Completion Procedure The proposed scope of work for this sundry application is included below. 1. Doyon 142 is currently rigged up on 2S-315. An 8-1/2" x 9-7/8" production hole was drilled to TD of 14,654' MD / 6,009' TVD. Currently the rig is pulling OOH with BHA. 2. Finish pulling OOH and lay down 8-1/2" x 9-7/8" BHA. 3. Pressure test 13-5/8" x 5,000 psi BOPE to 250 psi low and 3500 psi high (annular preventer to 2,500 psi). Notify AOGCC 24 hrs before test. 4. Run 7.625" 29.74, L80, TXP casing to surface. Cement in place with top of cement to be placed at 11,445' MD, which is 1,016' MD (250' TVD) above top of C37. 5. Install 7.625" packoff and test to 5,000 psi. N �% r � 6. Flush 10.75" x 7.625" annulus with water, followed by diesel. C14- rp PA 7. Pressure test production casing to 3,500 psi for 30 min, charted.i ` 2 1 u 8. Run CBL on wireline and send results to AOGCC for approval to perforate. 9. Run perforating assembly on wireline to depth. Perforate Cairn interval. 10. Make clean out run if needed. 11. Run 3.5" upper completion with packer and gauge. 12. Land hanger, run in lock -down screws, and test seals to 5,000 psi. 13. Pressure test tubing to 4000 psi for 30 min and IA / packer to 3500 psi for 30 min, charted. (A (T - Tn 14. Set BPV and test in direction of flow. 15. Nipple down BOPE, nipple up tree and test. Pull BPV. 16. Freeze protect 3.5" x 7.625" annulus. 17. Set BPV and move off rig. 2S-315 Post -Rig Schematic DepthDaturn: 16- 62.5# H40 Conductor EA E) 42'RKB ,120' above MSL = 119' MD I TVD 159,42' Base PermaFrost - 1455' MD 1434'TVD 13-112" Open Hole 10-34"45.5# L80 HYD563 Surface Casing 3571' MD 12636'TVD 9 718'Open Hale 7.5/8" 29.7# LBO UP Production Casing From 0 =14639' Top 03712466` 14835 PAD I TVD Top Cairn 13998' 15547' MD I TVD IV,4%.d I TW" R-Wrl T- 1XV47-%' i 41.'161. SM C—erbek-14: 1t43'x3-U--Itdmnj 2.875' DS Nipple Conductor Cemented to Surface Surface Cemented – Lead of 11.0 PPG 'G', Tail of 15.8 PPG `G' Lead from Surface to 3071' Tail from 3071' to 3571' 1.5' KBMG GLM wl SOV pinned to 2000psi V �io 3 r::` 9.3# EUE Tubing I" KWAG GLM (Dummy) Production Cemented – 115.8 PPG 'G'trom TD, to 2.813" DS Nipple 250'TVD DH gauge above C-37 3 W 7-718" Baker Premier Packer @ 14MC _7 SSD wl 2-813X profile" -Perfs: 14173'- 14203' 3' ' x 7-718" Baker Premier Packer @ 14.260' p tib 2.813' XN Nipple w/2.75" No go 3.112" x 7-54" Trailblazer Casing Scraper Tool or VVLEG 14290' Base Cairn –1440& MD 15834' TVD LI- interval will fie perforated g)TO - 14654' 1 rjOO9'MD I TVD f.11.9.,"alsd,request 45deg (Tangent 76deg) 1390 1395 1400 1405 1410 1415 F �1 1420 1430 1435 1440 r � 1 IL I � I i J I i l Ij i I I B ARC_RS l y f � I 1 1 1 �1 1 l _ { i C I Rc F 13 1390 1395 1400 1405 1410 1415 F �1 1420 1430 1435 1440 Rill f t= 1445 10 1 - - Is I - i 1450 I ! it _ \ - 1455 1111111 IAII 11 1 1111 111 1111111 1J J I I z 1460 i 1465 Rate of penetration averaged over the last 5 ft Rotational Phase Shift Resistivity 16 inch Spacing at 2 Thermal Neutron Porosity (Ratio Method) in (1.5 m) (ROP5) RT Speed (RPM) MHz, Environmentally Corrected. Selected Lithology (TNPH_ECO_RT) ECO[1] 500 ft/h 0 RT (P16H_ECO_RT) ECO[1] RT RT 0.2 ohm.m 2000 0 c/min 200 0.45 ft3/ft3 -0.15 Gamma Ray (GR) 0 gAPI 150 Phase Shift Resistivity 34 inch Spacing at 2 MHz, Environmentally Corrected. Bulk Density, Bottom, Computed Downhole (ROBB_A) ECO[1] RT Instance -1 (6" RAB[1] RT ) (GR) _ (P34H_ECO_RT) EC0[1] RT — — 1.71 g/cm3 2.71 Instance - 2 16" ECO[1] RT) 0.2 ohm.m 2000 Bulk Density Correction, Bottom, Computed Downhole (DRHB_A) ECO[1] RT - - - - - - - - - - I - - - -- - - - - - - - - - - - -0.25 g/cm3 0.25 (GRMA_ECO_RT) Instance - 3 ( 6" ARC[1] RT) (GR–ARC–RT) Resistivity Time After Bit (TAB–ARC–RES) Phase Shift Resistivity 34 inch Spacing at 400 KHz, Environmentally Corrected. (P34L_ECO_RT) ECO[1] RT _ ECO[1] 0.2 ohm.m 2000 0 h 10 Attenuation Resistivity 40 inch Spacing at 2 MHz, Environmentally Corrected. (A40H_ECO_RT) ECO[1] RT 0.2 ohm.m 2000 Phase Shift Resistivity 40 inch Spacing at 2 MHz, Environmentally Corrected. (P40H_ECO_RT) ECO[1] RT 0.2 ohm.m 2000 Description: ARC + VDN Detail RT Format: Log ( VISION Service RT) Index Scale: 2 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 03 -Dec -2018 02:09:59 Run 1: Parameters Parameter Description Tool Value Unit BHK Drilling Fluid Potassium Concentration Borehole 0 % BS Bit Size DNMSESSION Depth Zoned in DFD Drilling Fluid Density Borehole Time Zoned Ibm/gal THE STATE °fALAS-KA GOVERNOR MIKE DUNLEAVY Sandeep Pedam Staff Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Exploratory Pool, KRU 2S-315 Permit to Drill Number: 218-110 Sundry Number: 318-548 Dear Mr. Pedam: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.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, Hollis S. French L Chair DATED this�l �5 day of December, 2018. RBDMSL DEC 19 2018 DEC 1 t 2013 P'Ahs4� STATE OF ALASKA ALAS.-, OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon LJ Plug Perforations ❑ Fracture Stimulate L Repair Well Ll Operations shutdown Ll Suspend ❑ Perforate E] Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilll s Alaska Inc. Exploratory 0 ' Development ❑ Stratigraphic El Service [:1 218-110 3. Address:6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20776-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this po N/A KRU 2S-315 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 025603/ADL025608 Kuparuk River Field/Exploratory 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): 14654' 6009' 14654' 6009' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 119' 119' Surface 3,530' 10.75" 3571' . 2636' Intermediate Production 14558' 7.625" 14558' 5941' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14173-14203' 5670'-5690' 3.5" L-80 Planned @14290' Planned @ 14315'-14345' Planned @ 5769'-5790' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premium Packer Planned @14034' Baker Premium Packer Planned 14260' 12. Attachments: Proposal Summar Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Q ' Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 12/26/2018 Commencing Operations: OIL E] - WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sandeep Pedam Contact Name: Sandeep Pedam Authorized Title: Staff Completions Engineer Contact Email: Sandeep.Pedam@conocophillips.com Contact Phone: ;907) 263-4724 /� Authorized Signatur P" 1614. 2,01,F . Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 l Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test❑ Location Clearance ❑ Other: Post Initial Injection MIT Req' Yes ❑ No ❑ Spacing Exception Required, Yes ❑ No Subsequent Form Required: ! (� - I t7 a APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: e= Form 10-403 Revised 4/2017 k Apgro'x&I applicatio fflqf "W12r the date f a r At tac s Conoco hilli s p Alaska Paul K. Wharton Staff Landman P.O. Box 100360 —Suite ATO 1482 Anchorage, Alaska 99510-0360 Phone (907) 263-4076 Paul. K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2S-315 Well Kuparuk River Unit, Alaska ADL 25603, KRU Tract 90; ADL 25608, KRU Tract 95; and ADL 25607, KRU Tract 96 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2S-315 Well (the "Well'). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about November 8, 2018. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, pa44_4 /�- W4At� Paul Wharton Staff Landman cc: Rebecca Swensen Depth Datum: 16" 62.5# H40 Conductor 39.42' RKB + 120' above MSL = 119' MD / TVD 159.42' Base PermaFrost - 1455' MD / 1434' TVD 13-1/2" Open Hole 10-3/4" 45.5# L80 HYD563 Surface Casing 3571' MD / 2636' TVD �, 9 7/8" Open Hole from 3,571' to 14,459' 8 1/2" Open Hole from 14,459' to 14,654' 7-5/8" 29.7# L80 TXP Production Casing From 0 — 14558' Top C-37 12466'/ 4835' MD / TVD Top Cairn 13998'/ 5547' MD / TVD x`1173, f4fZCs Base Cairn — 14408' MD / 5834' TVD TD - 14654'/ 6009' MD / TVD @ 45deg(Tangent76deg) iY3rs" / `13 Wellhead / Tubing Hanger/ Tree 10-3/4" x 7-5/8" x 43Yz" IBT, SM Crossover below TH - 4-1/2" x 3-1/2" Tubing Conductor Cemented to Surface Surface Cement Job Lead of 11.0 PPG 'G', Tail of 15.8 PPG 'G' Lead from Surface to 3071', 2.875" DS Nipple Tail from 3071' to 3571' Total of 1436 sacks 11.0ppg lead and 306 sacks 15.8ppg tail pumped. Observed 170.5 bbls of good 1 1.0ppg Cement returned to surface 1.5" MMG GLM w/ SOV pinned to 2000psi 3 1/2" 9.3# EUE Tubing 1" KBMG GLM (Dummy) 2.813" DS Nipple DH gauge Production Cement Job 15.8 PPG 'G' from TD to 250' TVD above C-37. Total of 893 sacks of 15.8ppg cement pumped. CBL results showed TOC @ 11,300' MD / 4,549' TVD 3 1/2' x 7-7/8" Baker Premier Packer @ 14,034' SSD w/ 2.813X profile" Perfs: 14173' - 14203' 3 1/2" x 7-7/8" Baker Premier Packer @ 14,260' 2.813" XN Nipple w/ 2.75" No go 3-1/2" x 7-5/8" Trailblazer Casing Scraper Tool or WLEG @ 14290' Lower Perf Interval - 14315'-14345' 2S-315 Hydraulic Fracturing Notice Lette, November 8, 2018 Page 2 N Exhibit 1 ADL025603 ' N I Q 1 (4 0 L N N iI r ~ ii N ADL025608 ConocoPhillips Alaska 2S-315 Lease Plat 1117/2019 2Si ADL025604 ADL025607 Well Trajectory Kuparuk Frac Zone R_iv_er_U_nit_T-ION4_8c_ _ T9NR3E Wells within Trajectory Radius N Q Half Mile Frac Zone Radius QHalf Mile Well Trajectory Radius 0 0.2 0.4 0.6 F—I CPAI Lease Miles 2S-315 Hydraulic Fracturing Notice Letter November 8, 2018 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 Anchorage, AK 99501 Attention: Misty Alexa, Manager, NS Development Non -Operators: BP Exploration (Alaska) Inc. 900 E. Benson Boulevard Anchorage, AK Zip 99508 Attention: Mr. Weston Nash Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 310 Attention: Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint, Suite 600 Anchorage, AK 99503 Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7t" Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director TO THE.-._.-kSKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K. Wharton Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2S-315 well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA M THIRD JUDICIAL DISTRICT Paul K. Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton, and I have personal knowledge of the matters set forth herein. 2. 1 am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On or about November 8, 2018, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 8th day of November, 2018. Paul K. Wharton STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 81h day of November, 2018, by Paul K. Wharton. Notary Public, State of Alaska STATE OF ALASKA � NOTARY PUBL14C REBECCA SWENSEN Nly cohnmtssion Expires Aug. 27, 2020. Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one- half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1) Affidavit Section 2 - Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within 0.5 mile Table 1: Wells within 0.5 mile Section 3 - Freshwater Aquifers 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within one-half mile radius of the current or proposed wellbore trajectory. Section 4 - Plan for Baseline Water Sampling for Water Wells 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. Section 5 - Detailed Cementing and casing information 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.030(b) and tested in accordance with 20 AAC 25.030 (e) when completed. See Wellbore schematic for casing details. Section 6 - Assessment of each casing and cementing operation to be performed to construct or repair the well 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 11/19/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 10.5 ppg MP II and 11.0 ppg cement. Plugs bumped and floats held. The 7-5/8" casing cement pump report on 12/08/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg production cement. CIOV �' The plug bumped and the floats were checked and held. Full returns and reciprocated casing throughout the cement job. A CBL (cement bond log) was run on 12/09/2018. The log shows strong indication of good coupling between casing -cement -formation. A TOC can be seen at 11300' MD. Summary' �` n.� �-z- JJJJI cC-cL.Ccfi2..✓ `'=�c� All casing is cement@d in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successful fractured within design limits. Section 7 - Pressure test information and plans to pressure test casing and tubing installed in the well 20 AAC 25.283 (a)(7) 20 AAC 25.283. Hydraulic fracturinci On 11/21/2018 the 10-3/4" casing was tested on rig to 3,000 psi. On 12/10/2018 the 7" casing was pressure tested to 3,500 psi. The 7" x 3-1/2" annulus will be pressure tested to 3,850 psi prior to fracing The 3-1/2" tubing will be pressure tested to 4,140 (Lower) and 5,175 (Upper) psi prior to (racing. Table 1: Required Pressures for Lower Cairn Perf Interval AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 5,745 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 Annulus pressure test 3,850 Tubing pressure Test 4,140 Nitrogen PRV 6,745 Highest pump trip 6,245 Table 2: Required Pressures for Upper_Cairn Perf Interval AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,600 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 Annulus pressure test 3,850 Tubing pressure Test 5,175 Nitrogen PRV 7,600 Highest pump trip 7,100 Section 8 - Pressure ratings and schematics for the Wellbore, Wellhead, BOPE and Treating head 20 AAC 25.283(a)(8) 20 AAC 25.283. Hydraulic fracturing (a) Before hydraulic fracturing, the operator must submit an Application for Sundry Approvals (Form 10- 403) under 20 AAC 25.280. Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (8) accurate pressure ratings and schematics for the wellbore, wellhead, BOPE, and treating head; Size Weight Grade API Burst API Collapse 9 & 5/8" 40.0 L-80 5,750 psi 3,090 psi 7 26.0 L-80 7,240 psi 5,410 psi 3 & %2" 9.3 L-80 10,159 psi 10,533 psi Table 2: Pressure Ratings Stimulation Surface Rig -Up Bleed t Tattle Tale Tans Il ru j dfund Pop -Off Tank • Min. press. Rating on all surface treating lines 10,000 psi • Main treating line PRV set to 95% of max. treating pressure • IA parallel PRV set to 3600 psi • Frac pump trip pressure setting staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi Pop Off Tans Pump Truck Tree Saver With Wellhead lair.] DATE: Maximum Allowable Pumping Rates PROPOSAL: SIZE CSG ID L 2.250 1.750 OD RATE tn'/min 3.750 10 m1min 3 1/2" Big Bore 2.750 6 nill/min 2 7/8" & 31t2" 1.43-6— 2360 4 rn-lfimW 2 318" 11000 1.9002 m1min 31116 & 411116 with tapered mandrel 2.760 15 rn"ImIn 4 1116 X Tool Mandrel 3.610 4,760 24 mYrn in Pressure rating: 15,000psi cross P011T40N 0M1V kiwi To r, Aft 0. M" wwN.osesca nada. coin low, Or tel Y 3 U0410 Nk Pressure rating: 15,000psi cross P011T40N 0M1V kiwi To r, Aft 0. M" wwN.osesca nada. coin GEN 5 SLIM HOLE COa0C OO PHOLLRp8 ALASKA 16 X 10 3/4 X 7 5/8 X 4 I/2 Section 9 - Data for Fracturing zone and confining zones 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Cairn reservoir interval, has a gross thickness of approximately 290 ft TVD within the 2S-315 well from where it intersects the top at a MD of 13,998', to its base at a MD of 14,408'. The Cairn has two primary zones of interest within the gross section. Both zones are comprised of interbedded sandstone, siltstone, and mudstone layers. The sandstone and siltstone components are litharenites, moderately to well sorted, and very fine to fine grained. The mudstones are composed of clay -rich, moderately to poorly sorted silt and mud grains. The estimated fracture pressure for the Cairn interval is 212.5-13.5 ppg MW equivalent. The overlying confining interval of the Cairn Formation, (the T6 shale interval) consists of mudstone and siltstone with an average thickness of =190 ft. TVD. The top of the T6 confining interval starts at 5,209 ft. TVDSS (13,735 ft. MD). The estimated fracture gradient of the overlying T6 shale interval is z16 ppg MW equivalent in offset wells. The underlying confining zone consists of shales from the C-35, K3, HRZ, and Kalubik intervals totaling greater than 500' TVD thickness. The estimated fracture gradient for this section ranges from 15-18 ppg, with the gradient increasing down section. The top of the HRZ is estimated to be at 5,990 ft TVDSS at the location of the bottom hole location of the 2S-315 well. (no MD as the HRZ is not penetrated in the 2S-315 well). Section 10 - Location, Orientation and a Report on Mechanical Condition of Each Well that may Transect Confining Zone 20 AAC 25.283(a)(10) There are no wells within on -half mile radius of the proposed wellbore trajectory Section 11- Location of, Orientation of and Geological Data for Faults and Fractures that may Transect the Confining Zones 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that there is a single fault that transects the Cairn interval within one half mile radius of the wellbore trajectory. This fault occurs to the northwest of the 25-315 well bottom hole location. CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that the there are no faults that will interfere with containment. 25-315 Fracture Stimulation Area of Review WELL NAME STATUS Casin Size g Top of A -sand Top of A -Sand Oil Pool Top of Cement Top of Cement Top of Cement Reservoir Status Zonal Isolation Cement Operations Mechanical Oil Pool (MD) (NDSB) (MD j (NOBS) Determined By Summary Integrity 7-5/8" casing 2S-06 PfiOO 7.5/8' 7,497' 6,181' 5.125' 0,738 - Sonic leg Frac s3C>eves open TOC 5. 125' & Packer (P 738 sx 15.8ppg Ciass G pressure tested 7.179' h!C to 35011 psi on �/11ne Plat 2: 2S-315 Fault Analysis i� r N ADL025608 Kupi ConocoPhillips ............River _ Alaska 2S-315 Fault Analysis 11m2o1s uk Init _ N I 0 0.2 0.4 0.6 Miles ADL025604 ADL025607 Well Trajectory Frac Zone ® Faults within Frac Point Radius Wells within Frac Zone Radius QHalf Mile Frac Zone Radius MHalf Mile Well Trajectory Radius CPAI Lease Section 12 - Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) 25-315 was drilled in Nov 2018 as an exploration well in the Cairn formation. The well is completed with 3-1/2" 9.3# L-80 EUE tubing, two premier packers and a sliding sleeve. The Upper Cairn interval was perforated on rig between 14173'-14203'MD on 12/10/2018. Post rig, the lower Cairn interval will be perforated using wireline (planned depth: 14315-14345'MD) and stimulated first. The upper cairn interval will be perforated next. Pre -Frac Procedure: 1. Ensure all Pre -frac Well work has been completed. a. Lower Zone frac i. Swap OV for DV ii. Rig up Wireline, RIH and perforate (planned depth: 14315-14345'MD) iii. Pressure test tubing to 4140 psi/30min with 0 on IA to confirm tubing integrity for frac. iv. Pressure test IA to 3850 psi/30min with 0 on tubing to confirm IA integrity for frac. b. Upper Zone Frac c i. Ensure Upper perfs have been perforated on rig (depth: 14173'-14203'MD) l ii. RIH to set plug with gauges on XN nipple profile iii. Pressure test tubing to 5175 psi/30min with 0 on IA to confirm tubing integrity for frac. iv. Pressure test IA to 3850 psi/30min with 0 on tubing to confirm IA integrity for frac. v. RIH to open sliding sleeve Proposed Procedure: Halliburton Pumping Services: (Cairn Frac for both zones) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any preexisting conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 1,500' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. Ensure the BLM Sundry has been reviewed and approved by the BLM. 5. MIRU —9 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 1002 F seawater (approx. design volumes required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank are noted in the attached pump schedules.) 6. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 7. MIRU HES Frac Equipment. 8. PT Surface lines to 7,745 psi (lower frac) and 8,600 psi (upper frac) using a Pressure test fluid. 9. Test IA Pop off system to ensure lines are clear and all components are functioning properly. Set IA pop off to 3,600 psi and N2 PRV to 6,745 (lower frac) and 7,600 (upper frac) psi before frac. 10. Pump the Frac job by following schedule with a maximum expected treating pressure of 5,745 psi (lower frac) and 6,600 psi (Upper frac). .'�s t-4, Llt '` � ' �- Section 13 - Post -Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283 (a) (13) Production Testing Services (PTS) will be the Well Testing company for 25-315 (Cairn). The base case for the flow test consists of six periods: 1 Post -Frac Cleanup Flow (Zone 1) 3-5 2 Shut -In Pressure Build up (Zone 1) 3-5 3 Post -Frac Cleanup Flow (Zone 2) 3-5 4 Shut-in Pressure Build up (Zone 2) 3-5 5 Main Flow Period (Combined) 10-20 6 LonR Term Build uD Period 60-90 The "post -frac clean up flow" periods from Zone 1 and Zone 2 are intended to produce the frac fluid back to tanks as quickly as possible until each zone is producing at less than 10% water cut, and less than 0.5% BS&W, at which time the produced fluids meets the facility acceptance criteria. We will likely utilize N2 to kick off the well during the initial cleanup period, as well as during bottom hole sampling, to mitigate sample contamination. There will be a tank farm on location with — 800-1,200 BBL capacity, to contain the initial cleanup fluids. The clean up fluids will be hauled to 1B-WIF for disposal. The "shut-in pressure build up period" for each zone will tentatively be equal to the clean up flow period duration. With the well tied into the 2S facilities, we plan to utilize miscible injection or lift gas to maintain stable flow conditions through the Main Flow Period. The "main flow period" will impose minimal drawdown while maintaining stable flow. We will collect pressurized gas and oil samples, and stock tank oil. During the main flow period, production will be measured through the PTS separator metering systems and delivered to the 25-315 flowline. Shakeouts will be taken at 30 min intervals to gather BS&W, water cut, PH, salinity, and density. During the main flow period, an E -line PPROF log will also be performed to identify production rates from the individual zones. Once the flow test is complete the "main shut-in period" will begin (when the DHSIT closes), to gather pressure build up data. With the well being located in -field, and not limited to ice road time constraints, the duration of the "main shut-in period" may be extended as necessary to meet the objectives of the program. After completion of the 2S-315 Well Test, the intent is to produce the well long term, or as long as feasibly possible without offset injection support in the area at this time. Sample We|T stn Layout and Process Flow: ----------------, 2. \ � � \ 1 \ � \ \ � \ � a f �� ... � e715 Sample Well Testing MID: ---------------------------1 t t KRU 25-315 Stage Job Size (lb) Top MD (ft) Top TVD (ft) Propped Half- length (ft) Fracture Height (ft) Avg Fracture Width (in) Lower Cairn 149,250 14,060 5,590 480 225 0.276 Disclaimer Notice: This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results CUSTOMER Conoco Phillips Alaska, Inc. API 50-103-20776 cD (Ib/gal) 8.54 - -- 21981413 LEASE KRU 25-315 SALES ORDER 1234567890 BHST (7) 140 HALLIBURTON .1536372 FORMATION Lower Cairn DATE Mav Proca I -ll reatmen Interval Stage Number Fluid Description Stage Description Proppant Description Prop Conc (ppg) urry Rate (bpm) can Volume (gal) can Volume (bbl) Slurry Volume (bbl) Prop Total llbsJ Stage Intervalo- Time Time lhh:mmss) (hh:mm:ssj ur surfactant (g tJ - Buffer (ptj - - Crossiinker Crossiinker (gpt lgptj I - - Freeze Protea, Gei (gptj t) - Biocide (p j Ufy Aad, eves lai o• Breaker (Pptj pti o-11 Breaker (PPtI SP DPH 0.4 1-1 30# Hybor G Load Well 1.7 0.2 5 1,000 24 24 210.0 0:04:46 2:09:29 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-2 30#HyborG Mini -Frac 20 12,600 300 300 0:15:00 2:04:43 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 LL 1-3 30# Linear Flush 20 6,180 147 147 0:07:21 1:49:43 1.00 30.00 0.15 2.00 0.25 1-4 Shut -In Shut -In 1:42:22 +• 1-5 30# HyborG Pad 100 mesh 0.25 20 25,000 595 595 6,250 0:3EMMM 2:22 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 Z o n 1-6 30# Hybor G Proppant Laden Fluid Wan li 20/40 1.00 20 5,000 119 124 5,000 0:02:16 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.251-7 30# HyborG Proppant Laden Fluid Wanli 20/40 2.00 20 9,000 214 233 18,000 0:16:02 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.251-8 30# HyborG Proppant Laden Fluid Wanli 20/40 3.00 20 8000 190 215 24,000 0:14:21 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.251-9 30# HyborG Proppant Laden Fluid Wanli 20/40 3.50 20 16000 381 439 56,000 023:31 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25� 1-10 30# HyborG Proppant Laden Fluid Wanli 20/40 4.00 20 10000 238 279 40,000 0:11:26 1.00 O.SO 0.90 0.45 30.00 0.15 2.00 0.25 0.251-11 30# Linear Flush 20 5340 127 0:07:21 1.00 30.00 0.15 2.00 0.25 0.501-12 Freeze Protect Freeze protect 20 840 20 20 0:01:00 1000.00 Fluid Type Design Total (gal) 30# Linear 11,520 30# Hybor G 86,600 Freeze Protect 840 SP (gpm) (9pm) (gPm) (gpm) (gprn) PPm pion, Pam PPM PPM 0.8 0.7 0.8 0.4 840.0 7 ,7 I C,ySl l 3,191 I 149,250 l 2:09:29 I Proppant Type sign Tota I(lbs) Wanli 20/40 143,000 100 mesh 6,250 Lo -Surf 300D MO -67 CL -22 UC CL -31 LVT-200 WG -36 BE -6 Opfflo-III OptiFlo-II (gal) (got) (gal) (gal) (gal) lbs lbs lbs lbs Initial Design Material Volumel 98.1 1 69.3 1 77.9 39.0 840.0 2,943.6 14.7 196.2 24.5 9.2 Max Additive Rate Min Additive Rate Lo-SUrf300DMO-67 CL -22 UC CL -31 LVT-200 WG -36 BE -6 Opti Flo -III OptiFlo-II SP (gpm) (9pm) (gPm) (gpm) (gprn) PPm pion, Pam PPM PPM 0.8 0.7 0.8 0.4 840.0 25.2 0.1 1.7 0.2 0.4 0.2 0.2 0,2 0.1 210.0 5.3 0.0 0.4 0.1 0.1 CUSTOMER ConocoPhillips Alaska, Inc. API 50-103-20776 -D (Ib/gal) 8.54 - - 11981413 NALLtBVRTCTN LEASE KRU 25-315 SALES ORDER 1234562890 BHST (°F) 140 -- .1536372 FORMATION Upper Cairn DATE Max Pressure (psi( L' 'd Add1 roti reatmen Interval Stage Number Fluid Description Stage Description Proppant Description Prop Conc (ppg) Slurry Rate (bpm) Clean Volume (gal) Clean Volume (bbl) Slurry Volume (bbl) Prop Total (lbs) tagenterva Time Time (hh:mm:ssJ (hh:mm:ss) o- u Surfactant /gpt) - Buffer NO rqu es Crosslinker Crosslinker (gpt) (gpt) - Freeze Protect Gel (gpt) (ppt) Blocide (ppt) pry Additives pti 0- Breaker (ppt) pti o -Il Breaker IPPtI IPPt) 0.1 1-1 30#Hybor G Load Well 0.2 0.2 0.2 0.1 5 1,000 24 24 0.1 0:04:46 2:09:25 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-2 30# Hybor G Mini -Frac 20 12,600 300 300 0:15:00 2:04:40 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 ^i 0 1-3 30# Linear Flush 20 6,180 147 147 0:07:21 1:49:40 1.00 30.00 0.15 2.00 0.25 1-4 Shut -In Shut -In 1:42:18 •' 1-5 30# Hybor G Pad 100 mesh 0.25 20 25,000 595 595 6,250 0:30:06 1:42:18 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 Z o N 1-6 30# Hybor G Proppant Laden Fluid Wanli 20/40 1.00 20 5,000 119 124 5,000 0:06:13 1:12:12 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 °i 1-7 30# G Hybor y Pro ppLaden Fluid Wanli 20/40 2.00 20 9,000 214 233 18,000 0:11:41 1:05:59 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-8 30# HyborG Proppant Laden Fluid Wanli 20/40 3.00 20 8,000190 215 24,000 0:10:50 0:54:17 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-9 30# Hybor G Proppant Laden Fluid Wanli 20/40 3.50 20 16,000 381 439 56,000 0:22:05 0:43:28 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25 1-10 30# Hybor G Proppant Laden Fluid Wanli 20/40 4.00 20 10,000 238 279 40,000 0:14:05 0:21:22 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25 1-11 30# Linear Flush20 5,289 126 126 0:06: 18 0:07:18 1.00 30.00 0.15 2.00 0.25 0.50 1-12 Freeze Protect Freeze Protect 20 840 20 20 0:01:00 0:01:00 1000.00 Fluid Type i Design Total (gal) 30# Linear 11,469 30# Hybor G 86,600 Freeze Protect 840 (gPm) (gPm) (gPm) (go-) (gPm) ppm Ppm PPm PPM PPm 0.8 0.7 0.8 0.4 840.0 25.2 0.1 1.7 L `J C, `JU`J 1 2,971 I 3,1911 1 149,250 2:09:25 Proppa nt Type sign Total (lbs) Wank 20/40 143,000 100 mesh 6,250 Initial Design Material Max Additive Rate Min Additive Rate SP Lo -Surf 300D MO -67 CL -22 UC CL -31 LVT-200 WG -36 BE -6 Opti Flo -III OptiFlo-II SP (gPm) (gPm) (gPm) (go-) (gPm) ppm Ppm PPm PPM PPm 0.8 0.7 0.8 0.4 840.0 25.2 0.1 1.7 0.2 0.4 0.2 0.2 0.2 0.1 210.0 5.3 0.0 0.4 0.1 0.1 Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 2018-12-10 State: Alaska County: Harrison Ba API Number: 5010320776 NOCOPH L S NORTHSLOPE- Operator Name: ESUS Well Name and Number: KRU 2S-315 Longitude: -150.15 Latitude: 70.22 LonglLat Projection: Indian/Federal: none Production Type: True Vertical Depth (TVD): 0 Total Water Volume (al)*: 98,120 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Ingredient Mass Comments Company First Name Last Name Email Phon Number (CAS (% by mass)** HF Fluid (% by lbs #) mass)** Sea Water Operator Base Fluid Water 7732-18-5 96.00- 80.51753- 804425 Density 8.540 MHalliburton IC ICROBIOCIDE Biocide Listed Below Listed Below 0 NA CL-22 UC Halliburton lCrosslinker Listed Below Listed Below 0 NA CL-31 Halliburton CROSSLINKER Crosslinker Listed Below Listed Below 0 NA LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA MO-67 Halliburton pH Control Additive Listed Below Listed Below 0 NA OPTIFLO-II DELAYED Halliburton RELEASE Breaker Listed Below Listed Below 0 NA BREAKER OPTIFLO-III DELAYED Halliburton RELEASE Breaker Listed Below Listed Below 0 NA BREAKER SAND-COMMON WHITE-100 MESH, SSA-2, Halliburton Proppant Listed Below Listed Below 0 NA 2500 LB SACK SP BREAKER Halliburton Breaker Listed Below Listed Below 0 NA WG-36 GELLING Halliburton AGENT Gelling Agent Listed Below Listed Below 0 NA LVr-200 penreco Additive Listed Below Listed Below 0 NA Xinmi Wanli 20140 Wanli Industry Additive Listed Below Listed Below Developmen 0 NA t Co. Ltd Ingredients Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00075% 8 2-Bromo-2-nitro-1,3-pro anediol 52-51-7 100.00% 0.00150% 15 Denise Tuck, Halliburton, 3000 Acrylate polymer Proprietary 1.00% 0.00052% 10 N. Sam Houston Halliburton Denise Denise.Tuck@ Tuck Halliburton,co Pkwy E., Houston, 281-871-6226 TX 77032,281- m 871-6226 Ammonium persulfate 7727-54-0 100.00% 0.02222% 222 Borate salts Proprietary 60.00% 0.05504% 550 Halliburton Denise Denise.Tuck@ Tuck Halliburton.co 281-871-6226 m Corundum 1302-74-5 55.00% 7.87239% 78651 Crystalline silica, quartz 14806-60-7 100.00% 0.63685% 6364 Cured acrylic resin Proprietary 30.00% 0.00667% 68 Halliburton Denise Denise.Tuck@ Tuck Halliburton.co 281-871-6226 m Ethanol 6417-5 1 60.00% 0.09471% 1447 Guar um 9000-30-0 100.00% 0.29467% 2944 Heav aromatic petroleum na htha 64742-94-5 30.00% 0.02236% 1224 H drotreated Distillate, Light-CR-16 64742-47-8 100.00% 0.5809B% 15805 Mullite 1302-93-8 45.00% 6.49101% 164350 Oxylated phenolic resin Proprietary 30.00% 0.029818 Denise.Tuck@ 299 Halliburton Denise Tuck Halliburton.co 281-871-6226 m Poly(oxy-1,2-ethanediyl), alpha -(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 branched 5.008 0.00373% 38 Potassium formate 590-29-4 60.008 0.055048 550 Potassium hydroxide 1310-58-3 5.008 0.002138 22 Potassium metaborate 13709-94-9 60.00% 0.025558 256 Sodium carboxymethyl cellulose 9004-32-4 1.008 0.00092% 10 Sodium chloride 7647-14-5 4.008 3.356568 33536 Sodium glycollate 2836-32-0 1.008 0.000928 10 Sodium hydroxide 1310.73-2 30.008 0.022328 224 Sodium persulfate 7775-27-1 100.008 0.001008 10 Sodium sulfate 7757-82-6 0.108 0.000008 1 Water 7732-18-5 100.008 0.127488 1275 Total Water Volume sources may include fresh water, produced water, and/or recycled water " Information is based on the maximum potential for concentration and thus the total may be over 100% — Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. �3 All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier, provided it. The Occupational Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. NOVA !I'!l'fl' 1A 41. 4420 4430 14440 I II i i Gamma Ray (ECGR_EDTC) EDTC-B Stuck Tool Indicator, Total (STIT) CBL Amplitude (CBL) DSLT-BB Min Amplitude Max 0 mV 100 CBL Amplitude (CBL) DSLT-BB Variable Density Log (VDL) DSLT-BB 200 us 1200 0 mV 10 Good Bond (GOBO) 0 mV - 10 ' :.' :: ....................... • • . GoodBond from CBL to GOBO• Index Event Pips DSLT-BB 0 gAPI 150 Transit Time for CBL (TT) DSLT-BB 0 ft 50-------------------------- 400 us 200 Cable Tension (TENS)- _ 5000 Ibf 0 Casing Collar Locator Amplitude (CCL) CAL-YA -19 1 TIME -1900 - Time Marked every 60.00 (s) Cable Drag;:.: Tool Tot. Drag , �- BIEP - Bond Description: CBL _VDL Format: Log( Sonic CBL with VDL) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 09 -Dec -201815:23:41 • '. 7CemenFtBond Log: Parameters r Description Tool Value Unit ISSBAR Barite Mud Presence Flag Borehole No BHS Borehole Status (Open or Cased Hole) Borehole Cased BS Bit Size WLSESSION 9.875 in CBLG CBL Gate Width DSLT-BB 100 us CBLO Casing Bottom (Logger) WLSESSION 14558 It CBRA CBL LQC Reference Amplitude in Free Pipe DSLT-BB 59 mV CCL MULTIPLIER Casing Collar Locator Multiplier CAL-YA 2 CDEN Cement Density EDTC-B 2 g/cm3 DETE Delta -T Detection DSLT-BB E1 DFD Drilling Fluid Density Borehole 9.6 Ibm/gal GCSE—DOWN—PASS Generalized Caliper Selection for WL Log Down Passes Borehole BS(RT) GCSE_UP_PASS Generalized Caliper Selection for WL Log Up Passes Borehole BS(RT) GOBO CURB Good Bond in Arbitrary Cement DSLT-BB 3.02 mV MAHTR Manual High Threshold Reference for first arrival detection DSLT-BB 120 MATT CURR Maximum Attenuation in Arbitrary Cement DSLT-BB 11.44 dB/ft MCI Minimum Cemented Interval for Isolation DSLT-BB 11.15 It MNHTR Minimum High Threshold Reference for first arrival detection DSLT-BB 100 MSA Minimum Sonic Amplitude DSLT-BB 1.44 mV MSA CURR Minimum Sonic Amplitude in Arbitrary Cement DSLT-BB 1.44 mV 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-315 (PTD No. 218-110; Sundry No. 318-548) Paragraph Sub -Paragraph (a) Application for (a)(1) Affidavit Sundry Approval (a)(2) Plat (a)(2)(A) Well location (a)(2)(8) Each water well within % mile (a)(2)(C) Identify all well types within mile (a)(3) Freshwater aquifers: geological name; measured and true vertical depth Section Complete? Provided with application. On 11/8/2018, operator sent Notice of Operations (Notice) to all owners, landowners, surface owners, and operators within one-half mile radius of proposed well trajectory. Provided within Section 2 of the application Provided on map within Section 2 of the application. Well lies in Sections 17, 20, and 29, T10N, R08E, UM. Provided with application: No wells are used for drinking water purposes are known to lie within % mile of the surface location of KRU 25-315. According to the Water Estate map available through DNR's Alaska Mapper application (accessed online December 17, 2018), the nearest subsurface water rights assignments lie about 20 miles to the north and northeast in the Oooguruk and Milne Point Units. The nearest surface water rights lie between 5 and 6 miles to the west and northwest of the proposed fracturing interval (TWUA A2014-59 and TWUA A2017-125). SFD 12/17/2018 SFD 12/17/2018 SFD 12/17/2018 SFD 12/17/2018 There are no wells that penetrate the confining or SFD fracturing intervals within a one -half -mile radius of the 12/17/2018 fracturing interval in KRU 25-315. None. Freshwater aquifers within the area % mile beyond and lying directly below the Kuparuk River Unit are exempt per Federal Regulation 40 CFR 147.102(b)(3). For an SFD outline of the Area, see the EPA's "Alaska Oil & Gas Aquifer 12/17/2018 Exemptions Interactive Map" available online under the "Permits" section of EPA Region 10's web page at AOGCC Page 1 December 18, 2018 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-315 (PTD No. 218-110; Sundry No. 318-548) Paragraph Sub -Paragraph (a)(4) Baseline water sampling plan (a)(5) Casing and cementing information (a)(6) Casing and cementing operation assessment (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 (a)(6)(B) Each hydrocarbon zone is isolated (a)(7) Pressure test: information and pressure -test plans for casing and tubing installed in well (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head (a)(9)(A) Fracturing and confining zones lithologic description for each zone (a)(9)(B) Geological name of each zone (o)(9)(C) and (a)(9)(D) Measured and true vertical depths (a)(9)(E) Fracture pressure for each zone Section Complete?'_' https://www.epa.gov/uic/underground-injection-control- region-l0-ak-id-or-and-wa. _ None required. SFD 12/17/2018 CBL provided... daily drilling report and cement summary GLS Cementing went as planned. Eline CBL shows good cement over intended frac zones at aobut 14300 ft. Also GLS excellent cement above 14000 ft and to TOC at 11300 ft. No freshwater aquifers present (see Section (a)(3), above). SFD Surface casing set at 3,571' MD (2,636' TVD) and cemented 12/17/2018 to surface. CBL provided... good bond over intended frac interval. TOC seen at 11300 ft. CDW 7 5/8" casing tested to 3500 psi ... 3 %" tubing will be tested to 4140 psi and 5175 psi. The 7 5/8"x3.5" annulus CDW will be tested to 3850 psi prior to fracing. Provided. tree saver 15K working press. wellhead 5K. CDW Upper confining zones: approximately 1,200' of mudstone and siltstone assigned to the Seabee and lower Schrader Bluff (in ascending order). Fracture gradient in the 190' thick T-6 mudstone and shale interval that immediately overlies the fracturing interval is expected to be about 0.83 psi/ft. Fracturing Zone: "Cairn" reservoir comprising interbedded sandstone, siltstone and mudstone that extends from about 13,998' to 14,408' MD, a true vertical thickness of SFD 12/17/2018 AOGCC Page 2 December 18, 2018 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-315 (PTD No. 218-110; Sundry No. 318-548) Paragraph 1 Sub -Paragraph Section about 290'. Fracture gradient expected to be about 0.65 to 0.70 psi/ft. Lower confining zones: mudstone and siltstone assigned to the Lower Seabee, Torok, HRZ, and Kalubik intervals (in descending order) totaling about 500' in thickness. Fracture gradient expected to be about 0.78 to 0.93 psi/ft. (a)(10) Location, orientation, report on No other wells in area. mechanical condition of each well (a)(11) Sufficient information to determine wells will not interfere with containment within % mile (a)(11) Faults and fractures, Location, orientation (a)(11) Faults and fractures, Sufficient information to determine no interference with containment within % mile (a)(12) Proposed program for fracturing (a)(12)(A) Estimated volume (a)(12)(B) Additives: names, purposes, concentrations (a)(12)(C) Chemical name and CAS number of each ------------------- (a)(12)(D) Inert substances, weight or volume of each provided Operator -provided structure map indicates one northeast - trending fault that lies about 2,100' to the west of the fracturing interval. The maximum modeled half-length of the induced fractures is about 480', so it is highly unlikely that this fault will interfere with containment of the fracturinp, fluids. 2 interval provided, upper Cain and lower Cain Design slurry volume 3171 bbl plus 20 bbl freeze protect for each interval provided Provided — confidential already on file at AOGCC Planned 150,000 lbs proppant for each interval complete? GLS CDW SFD 12/17/2018 CDW CDW CDW CDW AOGCC Page 3 December 18, 2018 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-315 (PTD No. 218-110; Sundry No. 318-548) Paragraph i Sub -Paragraph 2)(12)(E) Maximum treating pressure with upporting info to determine ppropriateness for program (a)(12)(F) Fractures — height, length, MD and TVD to top, description of fracturing model (a)(13) Proposed program for post - fracturing well cleanup and fluid recovery (b)Testing of casing or intermediate Tested >110% of max anticipated pressure casing (c) Fracturing string (c)(1) Packer >100' MD below TOC of production or intermediate casing Section Provided — Lower Cain frac: est. 5745 psi treating pressure (lower frac) nitrogen PRV set at 6745 psi, highest pump trip 6245 psi. Upper Cain frac: 6600 psi max (upper frac), max pump trip 7100 psi with nitrogen PRV 7600 psi - Provided with supporting documentation. Two intervals will be perforated: 14,173' to 14,203' MD (5,670' to 5,690' TVD) and 14,315' to 14,345' MD (5,769' to 5,790' TVD). The anticipated half-length of the induced fractures is 480', and the anticipated height of the induced fractures is about 225' (top TVD estimated at 5,590' with a maximum fracture width of 0.276"). The induced fractures will likely penetrate upward through most of the Cairn reservoir interval, but certainly not through the overlying 1,200 -foot thick mudstones and siltstones assigned to the Seabee and lower Schrader Bluff (in ascending order). Similarly, the thick mudstone and siltstone intervals of the lower Seabee, Torok, HRZ, and Kalubik (in descending order) will prevent injected fluids from migrating out of the injection interval. Provided —disposal well options 1B-WIF identified. Lower Cain. Test 7 5/8"x3.5 annulus to 3850 psi. IA backpressure will be 3500 psi with PRV valve at 3600 psi. Upper Cain: Test 7 5/8"x3.5 annulus to 3850 psi. IA backpressure will be 3500 psi with PRV valve at 3600 psi. Complete? CDW SFD 12/17/2018 CDW CDW Provided TOC stated as 11300 ft MD, packer depth stated CDW as 14034 ft and 14260 ft. AOGCC Page 4 December 18, 2018 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 25-315 (PTD No. 218-110; Sundry No. 318-548) Paragraph Sub -Paragraph Section Complete? (d) Pressure relief valve (e) Confinement (f) Surface casing pressures (g) Annulus pressure monitoring & notification (h) Sundry Report (1) Reporting (j) Post frac water sampling plan (k) Confidential information (c)(2) Tested >110% of max anticipated pressure differential Line pressure <= test pressure, remotely controlled shut-in device Max est pressure is 6600 psi Upper Cain, 5745 psi Lower Cain. Annulus pressure hold is 3500 psi. Test tubing to 4140 psi is plan Lower, 5175 psi Upper Cain. 110% x (6600-3500psi) = 3410 psi tubing test required (min) Surf line test to 7745 psi. max est press is 6,600 psi (Upper Cain frac). max, max pump trip 7100 psi with nitrogen PRV 7,600 psi Frac fluids confined to approved provided formations Monitored with gauge and pressure relief I provided device 500 psi criteria (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance - --------- --- - -- ---- (g)(3) Sundry to AOGCC (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic Clearly marked and specific facts supporting nondisclosure CDW CDW CDW CDW AOGCC Page 5 December 18, 2018 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-315 (PTD No. 218-110; Sundry No. 318-548) Paragraph Sub-Paragraph Section Complete? (1) Variances Modifications of deadlines, requests for requested variances or waivers AOGCC Page 6 December 18, 2018 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-315 (PTD No. 218-110; Sundry No. 318-548) Paragraph p -- - - —--- - -- - -- - Sub -Paragraph Section Complete? 501032024700 3.2 miles 501032074700 0.9 miles 501032077600 1.1 miles 501032010300 44 1 t / 1970110 2160850 2181100 1890390 ARCO Conoco Phillips Alaska, Inc. CONOCOPHILLIPS ALASKA, INC- ARCO TARN 2 KRU 2S-06 KRU 2S-315 KUPARUK RIV UNIT 21-10-8/1 1256 FSL 1021 FEL 2236 FSL, 1408 FEL 3087 FNL 1614 FEL 350 FNL 2520 FEL TWP: 10 N - Range: 7 E - Sec. 23 TWP: 10 N -Range: 8 E - Sec. 17 TWP: 10 N - Range: 8 E - Sec. 17 TWP: 10 N - Range: 8 E - Sec. 21 M-_ - I y; Top of Cement for 7-5/8" casing £ «� in 2S-315 ` Sporadic Upper ; ' ` Cement bond Upper r s` Confining -I t Confining Layers; Good Layers - n Cement bond 3 Fracturing Cairn Interval ----- � { Reservoir 4 __ a .. Lower :g- Confining 7-5/8" casing Lower T v / g in 2S-315 Confining _ Layers _ (-5,941' TVD) Layers - AOGCC Page 7 December 18, 2018 THE STATE F I I I mrs" I WAMIS GOVERNOR BILL WALKER Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Exploratory Oil Pool, KRU 25-315 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-110 Surface Location: 3087' FNL, 1614' FEL, SEC. 17, TION, R08E, UM Bottomhole Location: 4651' FNL, 1392' FEL, SEC. 29, TION, R08E, UM Dear Mr. Alvord: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.claska.gov Enclosed is the approved application for the permit to drill the above referenced exploration well. 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 samples are first caught and 10' sample intervals through target zones. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by CPAI, in the attached application, the following well logs are also required for this well: • Gamma ray log required from surface casing shoe to surface. • Mud log and samples required from surface casing shoe to T.D. 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 approvals 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the AOGCC's internal use. 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, Oil) rIJN,-, Hollis S. French Chair } Lj DATED thisiz day of October, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SSP PERMIT TO DRILL 20 AAC 25.005 CONFIDENTIAL "PIAL 1 a. Typf Drill - er Redrill ❑ Reentry ❑ P oposed Well Class: Exploratory -Gas Service - WAG Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone 2 • Exploratory - Oil Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q , Single Well ❑ ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 11. Well Name and Number: KRU 2S-315 3. Address: 6. Proposed Depth: P.O. Box 100360 Anchorage, AK 99510-0360 MD 14,635 TVD: 5,996 12. Field/Pool(s): Kuparak River Field Exploratory 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3087' FNL & 1614' FEL, Sec 17, TION, R08E, UM ADL025603 / ADL025608 Top of Productive Horizon: 8. DNR Approval Number: 4238' FNL & 1534' FEL, Sec 29, T1 ON, R08E, UM 931899000 / 931903000 Total Depth: 9. Acres in Property: 4651' FNL & 1392' FEL, Sec 29, TION, R08E, UM 2511 /2522 13. Approximate Spud Date: 11/24/2018 14. Distance to Nearest PropertV: 1392' to ADL025607 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 15915. Surface: x- 480956.55 y- 5929961.45 ' Zone- 4 GL / BF Elevation above MSL (ft): 120 Distance to Nearest Well Open to Same Pool: 12190' to 2N-310 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 75.7 degrees Downhole: 2,603 Surface: 2,025 " 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) 42" 16" 62.6# H-40 Welded 80' Surf Surf 119' 119' Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 HYD563 Surf Surf 3652' 2659' 1462 sx 11.0 ppg, 270 sx 15.8 ppg 77/8" 7-5/8" 26# L-80 TXP 14596' Surf Surf 14635' 5996' 867 sx 15.8 ppg 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).- measured):Casing CasingLength Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (tt): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes No ❑ 20. Attachments: Property Plat El BOP Sketch Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program 0 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 from without prior written approval. Contact Name: Nick Lehman Authorized Name: Chip Alvord Contact Email: nick.r.lehmanOconocoohillios.com Authorized Title: Alaska DrIJOU Man er Contact Phone: 907-263-4951 Authorized Signature: t Date: o210 e OnI ssionUseOnIVI Permit to Drill7� Number: 2-19 11b API Number: /� 50-1©�-� -7, 776 C�C>i ` � Permit Approval Date: I� Z I See cover letter for other requirements. eth ne, gas hydrates, or gas contained in shat s: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coatA-L] Other: �� ��L �aP�rTd 3�-®o s� Samples req'd: Yes Mud log req'd: Yes[No❑ �_ eG n/ /r �v �' y ✓ p� measures: Yes [ Non / Directional svy req'd: YesEl Non j C nil //"�j 1 ,[`Spacing exception req'd: Yes No"L=1( Inclination -only svy req'd: Yes❑ NoIJ( /'z`0/` y/T10 to, WN �Y' Fee � �` Post initial injection MIT req'd: Yes❑ No[ cc, cc- APPROVED BY t Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL Submit Form and Form 10-401 Revised 5/2017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(9) Attachments in Duplicate i�-� IiSEPr<$ NP-,I onocoPh hips Post Office Box 100360 Anchorage, Alaska 99510-0360 September 4t", 2018 Commissioner Alaska Oil and Gas Conservation Commission 333 West 71' Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill 2S-315, a Cairn exploration well Dear Commissioners: ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore exploratory 2S-315 Cairn well. This will be drilled off an existing gravel pad at Drill Site 2S in the Kuparuk field using Doyon 142. The objective of 2S-315 is to drill through the Cairn interval, capture LWD logs, and conduct an evaluation program to help justify future development. As indicated in the attachments, the drilling program calls for drilling 13-1/2" surface hole to approx. 3,652' MD / 2,659' TVD, followed by an 8-1/2" x 9-7/8" production hole section to approx. 14,635' MD / 5,996' TVD, which will penetrate the Cairn interval. The evaluation program in the production hole section of 2S-315 will first include obtaining a full suite of LWD logs through the sand. The well will then be cased and completed and the target sand will be perforated, fractured and flow tested to gather data on inflow performance and fluid ✓ properties. The well will be tied into existing facilities on 2S -pad as a permanent well. The planned spud date for 2S-315 is November 24, 2018. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for these wellbores. If you have any questions or require further information, please contact myself at (907) 263-4951 Sincerely,- Nick Lehman` Drilling Engineer Depth Datum: 16" 62.5# H40 Conductor 39' RKB + 120' above MSL = 159' 11 9'MD / TVD Base PermaFrost - 1454' MD 11433' TVD 13-1/2" Open Hole 10-3/4" 45.5# L80 HYD563 Surface Casing 3652' MD / 2659' TVD 9 7/8" Open Hole from 3,652' to 14,445' 8 1/2" Open Hole from 14,445' to 14,635' 7-5/8" 29.7# L80 TXP Production Casing From 0 — 14625' Top C-37 12,307'/ 4,801' MD / TVD Top Cairn 14,016'/ 5,559' MD / TVD Base Cairn - 14335'/ 5784' MD / TVD TD - 14635'/ 5996' MD / TVD 9 45° INC (Tangent @76° INC) 9 L2 Conductor Cemented to Surface Surface Cemented — Lead of 11.0 PPG DeepCrete Tail of 15.8 PPG 'G' Lead from Surface to 3152' Tail from 3152' to 3652' 2.875" DS Nipple 3 1/2" 9.3# ELIE Tubing 1" KBMG GLM 2.813" X Nipple DH gauge 3'/" x 7-5/8" Baker Premier Packer 2.813" XN Nipple w/ 2.75" No go Scraper/Magnet Assy Production Cemented — 15.8 PPG 'G' from TD to 250' TVD above C-37 Perfs post rig across Cairn interval KRU 2S-315 Application for Permit to Drill Document Table of Contents Application for Permit to Drill, Well 2S-315 Saved: 4 -Sep -18 1. Well Name.................................................................................................................. 2 Requirements of 20 AAC 25.005(f)......................................................................................................... 2 2. Location Summary...................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2).....................................................................................................2 Requirements of 20 AAC 25.050(b)......................................................................................................... 2 3. Blowout Prevention Equipment Information............................................................... 3 Requirements of 20 AAC 25.005(c)(3)..................................................................................................... 3 4. Drilling Hazards Information......................................................................................3 Requirements of 20 AAC 25.005 (c)(4).................................................................................................... 3 5. Procedure for Conducting Formation Integrity Tests...................................................3 Requirements of 20 AAC 25.005 (c)(5).................................................................................................... 3 6. Casing and Cementing Program..................................................................................4 Requirements of 20 AAC 25.005(c)(6)..................................................................................................... 4 7. Diverter System Information.......................................................................................5 Requirements of 20 AAC 25.005(c)(7)..................................................................................................... 5 8. Drilling Fluid Program................................................................................................ 5 Requirements of 20 AAC 25.005(c)(8)..................................................................................................... 5 9. Abnormally Pressured Formation Information............................................................5 Requirements of 20 AAC 25.005 (c)(9).................................................................................................... 5 10. Seismic Analysis..........................................................................................................6 Requirements of 20 AAC 25.005 (c)(10).................................................................................................. 6 11. Seabed Condition Analysis.......................................................................................... 6 Requirements of 20 AAC 25.005 (c)(I1).................................................................................................. 6 12. Evidence of Bonding....................................................................................................6 Requirements of 20 AAC 25.005 (c)(12).................................................................................................. 6 13. Proposed Drilling Program.........................................................................................6 Requirements of 20 AAC 25.005 (c)(13).................................................................................................. 6 2S-315 PTD Application Prepared by: Nick Lehman Page 1 of 6 Printed: 4 -Sep -18 Application for Permit to Drill, Well 2S-315 Saved: 4 -Sep -18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 6 Requirements of 20 AAC 25.005 (c)(14).................................................................................................. 7 15. Attachments............................................................. Attachment 1: Location As -Built ................................................. Attachment 2: Directional Plan .................................................. Attachment 3: Drilling Hazards Summary ................................... Attachment 4: Well Schematic .................................................... Attachment 5: Diverter Layout Schematic .................................... Attachment 6: BOP Configuration .............................................. 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must .similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as KRU 2S-315. This will be an exploratory delineation well for the Cairn interval. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, eecept far an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's• owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective,fomtation, and at total depth, referenced to govennnental section lines. (B) the coordinates of the proposed location of the well at the .surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth: and (D) other information required by 20 AAC 25.050(b); Location at Top of Productive Interval (Cairn) 4238' FNL & 1534' FEL, Sec 29, TION, R8E, UM Location at Surface 3087' FNL & 1614' FEL, Sec 17, TION, R8E, UM NAD 27 Coordinates Northings: 5,929,961.45' Eastings: 480,956.55' IRKB Elevation 159.0' AMSL ' Pad Elevation 120.0' AMSL . Location at Top of Productive Interval (Cairn) 4238' FNL & 1534' FEL, Sec 29, TION, R8E, UM NAD 27 Coordinates Northings: 5,918,251.67' Eastings: 481,042.51' Measured Depth, RKB: 14,017 Total Vertical Depth, RKB: 5,559' Total Vertical Depth, SS: 5,400' Location at Total Depth 4651' FNL & 1393' FEL, Sec 29, TION, R8E, UM NAD 27 Coordinates Northings: 5,917,838.03' Eastings: 481,183.74' Measured Depth, RKB: 14,625' Total Vertical Depth, RKB: 5,996' Total Vertical Depth, SS: 5,837' 2S-315 will be drilled from existing gravel pad at Drill Site 2S. Please refer to Attachment 1: Location As -Built Requirements of 20 AAC 25.050(b) Ifa well is to be inter Tonally deviated, the application fora Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please refer to Attachment 2: Directional Plan. and Printed: 4 -Sep -18 2S-315 PTD Application Prepared by: Nick Lehman Page 2 of 6 Application for Permit to Drill, Well 2S-315 Saved: 4 -Sep -1 8 (2) for all wells within 200 feet of the proposed wellbore (A) list the mantes of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been ficrnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of rhe following items, except far an item already on file with the commission and identified in the application: (3) a diagram and description of the hlowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 and Attachment 6. ConocoPhillips is requesting a waiver from 20 AAC 25.035.e.10.B regulation of weekly BOPE test for exploration ---- wells to allow Doyon 142 to follow a bi-weekly BOPE test for 2S-315. ConocoPhillips believes this waiver to be justified for the following reasons: 1. Doyon 142 is a warm rig that has been operating in Kuparuk since early 2016. 2. It's BOPE is currently on the Between -Well -Maintenance program with a proven history of exceptional BOP performance. ConocoPhillips recently submitted the first half of 2018 BWM status report to AOGCC that details Doyon 142's performance. 3. Although this well is being permitted as an exploration well, it is being drilled within the Kuparuk development field. Unlike remote exploration wells that require ice pads, 2S-315 is being drilled off the existing DS -2S gravel pad in the Kuparuk field with access to Kuparuk infrastructure and Kuparuk spill response equipment. ✓ 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application,for a Permit to Drill must he accompanied by each of the fallowing items, except,for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2S-315 is calculated using an estimated maximum reservoir pressure of 2,603 psi (assumed to be normally pressured based on Tarn 4 & 2N-310 pressure data showing 0.45 psi/ft gradient), a gas gradient of 0.10 psi/ft, and the estimated depth of the Cairn sand at 5784' TVD: Cairn Sand Estimated. BHP = 2,603 psi Cairn Sand estimated depth = 5,784' TVD �y Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (e)(4)(A) Hydrostatic of full gas column = 578 psi (5,784' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 2,025 psi . (2,603 psi — 578 psi) (B) data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. and (C) data concerning potential causes of hole problems such as ahnornutlly geo-pressured strata, lost circulation Zones, and zones that hm e a propensity for differential sticking; Mudlogging services will be utilized on this well. Please refer to Attachment 3: Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit in Drill must be accompanied by each of the_ following items, exceptfor an item already onfile with the commission and identified in the application: (5) a description of the procedure for conductingformation integrity tests, as required under 20 AAC 25.030(f); Drill out surface casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2S-315 PTD Application Prepared by: Nick Lehman Page 3 of 6 Printed: 4 -Sep -18 Application for Permit to Drill, Well 2S-315 Saved: 4 -Sep -18 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application fa a Permit to Drill must be accompanied by each of the following items, except fan' an item already on file with the commission and iderttif`ied in the application: (6) a cornplete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed; Casingand Cementing Program Csg/Tbg OD in Hole Size in Weight 101 Grade Conn. Length ft Top MD/TVD ft Btm MD/TVD ft Cement Program 16 42 62.6 H-40 Welded 80 Surf I t9 / 119 Existing, cement to surface 10-3/4 13-1/2 45.5 L-80 HYD563 3,523 Surf 3,652 / 2,659 1462 sx 11.0 ppg, 270 sx 15.8 ppg 7-5/8 9-7/8 29.7 L-80 TXP 14,596 Surf 14,635 / 5,996 852 sx 15.8 ppg Class G 10-3/4" Surface casing run to 3,652' MD / 2,659' TVD Cement from 3,652' MD to 3,152' (500' of tail) with 15.8 ppg Class G, and from 3, l52' to surface with 11.0 ppg DeepCRETE. Assume 250% excess annular volume from base of permafrost to conductor, 50% excess annular volume below base of permafrost, and 0% excess in 16" conductor. 10-3/4" SURFACE CEMENT CALCS Design: 500' of 15.8ppg Tail Cmt with 11.0ppg Lead Cmt to surface with 50% excess below 250% excess in Permafrost Permafrost & Tail Cement yield = r 1.17 ft^3/sk I Lead Cement yield = 1.91 ft^3/sk 11.0 ppg DeepCRETE Lead Slurry CONDUCTOR = 119' x 0• 7 bbl/ft x 1.0 (0% excess) bbls Base of Permafrost to COND = (1455'- 119') x 0.0648 bbl/ft x 3.5 (250% excess) 302.9 bbls Btm of Lead to Base of Permafrost= (3152'- 1455') x 0.0648 bbl/ft x 1.5 (50% excess) �ft-3 164.9 bb Is Total Lead Cement= 4 bbls I or 121§1.12' or sks 15.8 ppg Class G Tail Slurry JI Shoetrack = 80'x 0.0962 bbl/ft x 1.0 (0% excess) 7.7 bbls Shoe to Top of Tail = (3652'- 3152') x 0.0648 bbl/ft x 1.5 (50% excess) 48.6 bbls Total Tail Cement = 56.3 bbls I or 316 ft -3 I or 1270 sks Displacement = (3652'- 80') x 0.0962 bbl/ft = 343.5 bbls 7-5/8" Production casing run to 14,635' MD / 5,996' TVD Single stage 15.8 ppg Class G slurry is designed to be placed from TD to 11,296' MD, which is 1,011' MD (250' TVD) above top of C37. 40% excess annular volume will be utilized. 2S-315 PTD Application Prepared by: Nick Lehman Page 4 of 6 Printed. 4 -Sep -18 Application for Permit to Drill, Well 2S-315 Saved: 4 -Sep- 18 7-5/8" Production Cement Calculations Design: Class G 15.8 ppg Cement to 250' TVD above Top of C37 Cement yield = 1.16 ftA3/sk Planned TOC = 11296' Shoe Track 82'x 0.0459 bbl/ft x 1.0 (0% excess) 3.8 bbls 8-1/2" x 7-5/8" Annulus = (14635'- 14445') x 0.0137 bbl/ft x 1.4 (40% excess) 3.6 bbls 9-7/8" x 7-5/8" Annulus = (14445' - 11296') x 0.0383 bbl/ft x 1.4 (40% excess) 168.6 bbls Total Cement Volume = 176 bbis I or 1988.4 ft -3 1 or 1852sks Displacement = (14635'- 82') x 0.0459 bbl/ft = 668.2 bbis 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement it waived by the commission under 20 AAC25.035(h)(2); Please refer to Attachment 5: Diverter Layout Schematic. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except,for an item alreadv on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033: Drilling will be done using water-based mud systems having the following properties: Surface 119'— 3,652' Magid Type Sud Mud Density ( ) 10.0 ✓ Funnel Viscosity (seconds) 200 Yield Point 50 AN Fluid Loss (m1/30min) 10 H 9.5 Production 3,652'— 14,635' Mud Type LSND Density ( ) 9.5 Plastic Viscosity 10 Yield Point 25 API Fluid Loss (m1/30min) 8 H 9.5 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or,siratigraphic test well, a tabulation setting out the depths of predicted abnormally gen-pressured strata as required by 20 AAC 25.0330: 2S-315 PTD Application Prepared by: Nick Lehman Page 5 of 6 Printed: 4 -Sep -18 Application for Permit to Drill, Well 2S-315 Saved: 4 -Sep -18 2S-315 is expected to be normally pressured with 0.45 psi/ft gradient based on 2N-310 and Tarn 4 pressure data. Mudlogging service will be utilized on this well. — 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10).for an exploratory or stratigraphic test well, a seismic refraction or refection analysis as required by 20 AAC 25.061(x); A Shallow Hazard analysis was not conducted due to the large number of offsets close to 2S-315 surface section indicating no presence of shallow gas. -- 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for az item already on f le with the commission and identifed in the application: (Il ),for a well drilled front an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of rhe following items, except for at item already on f le with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 (Bondingfhave been me't; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill Hurst be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program for 2S-315 is listed below. t 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. Notify AOGCC 24 hrs before test. 2. Spud and directionally drill 13.5" hole to 10-3/4" surface casing point (3,652' MD/ 2,659' TVD) according to the directional plan. Run MWD tools in drill string as required for directional monitoring (gamma ray). ./ 3. Run and cement 10.75" 45.5#L-80 HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug. Notify AOGCC if top job is required. 4. Remove diverter system and install wellhead. Install and test 13-5/8" x 5,000 psi BOPE to 250 psi low and 3,500 psi high (annular preventer to 2,500 psi). Notify AOGCC 24 hrs before test. 5. Pick up 8.5" bit and 6.75" drilling assembly with 9.875" under -reamer and MWD/LWD (gamma ray, resistivity, neutron/density). RIH, clean out cement to top of float equipment, and test casing to 3,000 psi for 30 min. 1� 6. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg EMW LOT/FIT, recording results. (� 7. Displace to 9.5 ppg LSND water-based drilling fluid. 8. Directionally drill 8 1/2" x 9-7/8" hole to production TD of 14,635' MD / 5,996' TVD according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 9. Circulate hole clean. POOH. 10. Run 7.625" 29.7#, L80, TXP casing to surface. Cement in place with top of cement to be placed at 11,296' MD, which is 1,011' MD (250' TVD) above top of C37. 11. Install 7.625" packoff and test to 5,000 psi. 2S-315 PTD Application Prepared by: Nick Lehman Page 6 of 6 Printed: 4 -Sep -18 Application for Permit to Drill, Well 2S-315 Saved: 4 -Sep -1 8 12. Flush 10.75" x 7.625" annulus with water, followed by diesel. 13. Pressure test production casing to 3,500 psi for 30 min. C#mr 14. Run CBL on wireline. A,c4 �� 15. Make clean out run if needed. "l 16. Run 3.5" upper completion with packer and gauge. 17. Land hanger, run in lock -down screws, and test seals to 5,000 psi. T 7Z,�,i/� e- 18. Set BPV and test in direction of flow. C— �2T- 19. Nipple down BOPE, nipple up tree and test. Pull BPV. 20. Freeze protect 3.5" x 7.625" annulus. 21. Set BPV and move off rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a permit to Drill nueste be accompanied by each of the following items, e.ccept for an item already on file with the conmtission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and it statement of whether the operator intends to request authorization tender 20 AA 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (DS 1B CRI) or Prudhoe DS -4. All cuttings generated will be hauled to DS 1B Grind and Inject Facility or the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1: Location As -Built Attachment 2: Directional Plan Attachment 3: Drilling Hazards Summary Attachment 4: Well Schematic Attachment 5: Diverter Layout Schematic Attachment 6: BOP Schematic Printed: 4 -Sep -18 2S-315 PTD Application Prepared by: Nick Lehman Page 7 of 6 REVI DATE IBYI CKIAPPI DESCRIPTION I REV DATE I BY CK APP DESCRIPTION 3 8/17/18 LGM I JFC I Change Well 15 to 315 Per K180005ACS 1 2 3/9/17 SZ I MEH Add Well 13 per K170005ACS NOTESa J n 1° 1s 1+ a 1a 17 is n m DS2A NS 2°14 1s 1. BASIS OF LOCATION AND ELEVATION IS DS2S ° 21 22 23 MONUMENTATION PER LOUNSBURY & ASSOC. CPF2 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 25 30 2sZ1` 27 25 25 SS 2S [3 27 DSA ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ✓ - 052F ARE NAD 27. 3' J 35 ostc 3 P°may 3. ELEVATIONS ARE B.P.M.S.L. < 2: mm 6 5 rtoN \a,e°p y 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED — / QQ✓ SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, _ ^'" UMIAT MERIDIAN. — 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS VS2S 1s a 13 1a n r 15 / L15-28, L15-29, L15-32, L15-35, 11-13-2015 - 22 FIELD BOOK L15-75. 20 21 PROJECT 23 2x 2a 21 22 LOCATION 6. ALL DISTANCES SHOWN ARE TRUE. ,° 25 2 27 25 30 2; 5 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR 13. 31 32 3, Sa 35 31 32 S 8. CONDUCTOR 15 HAS BEEN RENAMED TO 315 ON VICINITY MAP 8/17/18. NTS N A 3p' TYP DS2S g 4•. 12.10.8.. 5 3 2 1 14 • 7 • e 9 315 11 13 LEGEND O AS—BUILT CONDUCTOR LOCATION 17+16 EXISTING CONDUCTOR LOCATIONS V 20 21 GRAPHIC SCALE 0 100 200 400 LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. I inch = 200 ft. SU� YORE ENGINEERS PLANNERS AREA: 2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING N0. PART: REV: LK6219d24 5 28 15 CEA-D2SX-6219D24 1 of 2 3 3 18/17/10 LGM I JFC I I Change Well 15 to 315 Per K180005ACS 12 13/9/171 SZ I MEH I I Add Well 13 Per K170005ACS I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN - Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset. Elev. Y X Lat. Long. F.S.L F.E.L. O.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,948.70 480,898.09 70' 13' 11.187" 150' 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186'11643'1110.51 120.0- 315 15,929,961.45' 480,956.55 70' 13' 11.314" 150' 09' 13.070" ' 2192' 1614', 110.6' 120.0' * CONDUCTOR AS BUILT THIS SURVEY ®� OFtit �• • 49th ...........,..ra.......... .... .,.......... .. r ....................: �....-....,,........... %JEREMIAH F. CORNELL.' �'� '• �.LSS-1266633 i SURVEYOR'S CER77FICA7E 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF AUGUST 17, 2018. 0LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS 44 AREA: 2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5 28 15 CEA-D2SX-6219D24 2 of 2 3 10:47, August 09 2018 T 55 m rn m 0 0 25-315 wp03 Permit Pack pian Summa I) , I I -a oOs� 16O L 0 O �0�� 0 3000 6000 9000 12000 4500 16" x 42" 10 3/4" x 13-1/2 Measured Depth 7-5/8" x 9-7/8" o00 0 ! o Rig: 39+120 @ 159.00usft (Doyon142) 2 0 0 0 o -cag o 0 ~ o W � I 0 16" x 42" C 0 a5 a) m c d U2 0 m U 00� 0 0 10025 1000e 00er 00001 S- 2PB1 39 400 2000 4000 6000 8000 10000 1 00 400 -- 590 330 30 590 - 770 10 3/4" x 13-1/2 Hm7nntM Denarture 7-5/8" x 9-7/8 770 - 960 0 1000 2000 3000 4000 5000 6000 7000 Depth From DepthTo Survey/Plan Tool 39.00 1500.00 2S-315 wp03 (Plan: 2S-315) GYD-GC-SS 1500.003650 00 2S-315 wp03 (Plan: 2S-315) M W D 1500.00 3650.00 2S-315 wp03 (Plan: 2S-315) MWD+IFR-AK-CAZ-SC 3650.00 5150.00 2S-315 wp03 (Plan: 2S-315) MWD 3650M 14634.68 25-315 wp03(Plan: 25315) MWD+IFR-AK-CAZ-SC North / Y: East / X: Pad Elevation: 120.00 TVD MD N[ 119.00 119.00 16" x 2659.00 3651.94 10 3/4" x 13 5996.13 14634.68 7-5/8" x 9- Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 Lithology Column 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 11100' OLS, 180.24°TF, for 200' 3 600.00 2.00 180.24 599.96 -3.49 -0.01 1.00 180.24 3.48 Start 2.25°/100' OLS, 0°TF, for 855.52' 4 1455.52 21.25 180.24 1434.00 -175.07 -0.73 2.25 0.00 174.46 Hold for 107.29' jg��;ggnu B 5 1562.82 21.25 180.24 1534.00 -213.95 -0.90 0.00 0.00 213.22 Start 3.5°/100' OLS, 0° TF, for 1554.93' 6 3117.75 75.67 180.24 2526.80 -1334.55 -5.63 3.50 0.00 1329.96 Hold for 9706.39' Ugnu A 712824.14 75.67 180.24 4928.88 -10738.93 -45.52 0.00 0.0010702.03 Start 3.5%100' DLS, -155.86°TF, for 992.35' 'Mo 813816.48 45.00 161.00 5417.58 -11577.2270.24 3.50 -155.8611527.05 Hold for 200' 914016.48 45.00 161..00 5559.00 -11710.94 116.28 0.00 0.0011656.24 28-315 T01 TO 032818 PP AdjustTF to 0°, for 318.2' West Sak Top 1014334.68 45.00 161.00 5784.00 -11923.68 189.53 0.00 0.0011861.79 Adjust TF to 0°, for 300' 11 14634.68 45.00 161.00 5996.13 -12124.26 258.60 0.00 0.0012055.58 TO: 14634.68' MD, 5996.13' TVD 2446.0 West Sak Bas 2660. 90 NW -80 Campanian 1363.0 C-50 163-40 IN, C-37 (Top 1 „s�-6 (Base gTop Cairn _,15 Cairn ICI V LU I I u U I : - By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's 1 completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision CJUavoidance plan as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. repared by 960 - 1140 Checked by 1140 - 1330 300 1330 - 1510 10 1510 - 1700 B. Temple 1700 - 2240 3 2240 2780 E. Sterk 2780 - 3310 N. Lehman 3310 - 3850 90 3850 4390 4390 4920 •=:6.-o- y�i 4920 5460 frrt'(. 4 5460 - 6000 6000 7080 24 2 120 7080 - 8160 - S1' 8160 - 9240 9240 - 10320 ' 9 - 10320 - 11400 21() 150 11400 12470 12470 13560 180 13560 - 14635 Magnetic Model & Date: BGGM2018 10 -Dec -18 Magnetic North is 16.66° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.77° 57415nT Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 Lithology Column 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 11100' OLS, 180.24°TF, for 200' 3 600.00 2.00 180.24 599.96 -3.49 -0.01 1.00 180.24 3.48 Start 2.25°/100' OLS, 0°TF, for 855.52' 4 1455.52 21.25 180.24 1434.00 -175.07 -0.73 2.25 0.00 174.46 Hold for 107.29' jg��;ggnu B 5 1562.82 21.25 180.24 1534.00 -213.95 -0.90 0.00 0.00 213.22 Start 3.5°/100' OLS, 0° TF, for 1554.93' 6 3117.75 75.67 180.24 2526.80 -1334.55 -5.63 3.50 0.00 1329.96 Hold for 9706.39' Ugnu A 712824.14 75.67 180.24 4928.88 -10738.93 -45.52 0.00 0.0010702.03 Start 3.5%100' DLS, -155.86°TF, for 992.35' 'Mo 813816.48 45.00 161.00 5417.58 -11577.2270.24 3.50 -155.8611527.05 Hold for 200' 914016.48 45.00 161..00 5559.00 -11710.94 116.28 0.00 0.0011656.24 28-315 T01 TO 032818 PP AdjustTF to 0°, for 318.2' West Sak Top 1014334.68 45.00 161.00 5784.00 -11923.68 189.53 0.00 0.0011861.79 Adjust TF to 0°, for 300' 11 14634.68 45.00 161.00 5996.13 -12124.26 258.60 0.00 0.0012055.58 TO: 14634.68' MD, 5996.13' TVD 2446.0 West Sak Bas 2660. 90 NW -80 Campanian 1363.0 C-50 163-40 IN, C-37 (Top 1 „s�-6 (Base gTop Cairn _,15 Cairn ICI V LU I I u U I : - By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's 1 completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision CJUavoidance plan as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. repared by Checked by ccepted by Approved by: B. Temple V. Osara E. Sterk N. Lehman 10:39, August 09 2018 2S-315 wp03 39.00 To 14634.68 Spider 1 12M-0 2M-39wp 4 2M 355-26 1_- 1 12M-081-1 2 1 2S 11 133AL2 K-1 2S -09A 2S-04 2S-07 1 11 1 2S-05 2K_ '��A 2K -192K-18 K=28 Ll, 2S-09 2K - 2K -22A 2K -21A 2K -28A 2 -25 2K-21 2S-02 2K 22 K-24 2L-306PB1 2S -13P -04P 2K-24AL2-0 02 a 2K-22AL1-01 2L-319 2K-22AL1 2K-24AL2_ W 5L1-01 0 2L-308 KRU 1-10-8 c� L 21--311 2L-304 2S 12PB1 Sh r Tooth #1 0 z L-3 2S-12 -301 2L-316 L-32 21--317A 2S-03PB1 2S-01 2L-320 2S-08 2L-3 2S-10 21-1.309 2K-30 2N-301 (wp03) 2S-03 2K-32 gifyl wp05 2S 6 2N-301 PB1 (W P03) 2v 3 2L-328 2�f1��4PB1, Easting (3500 usfUin) 2S-315 wp03 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise, 0 16" x 42" - - 1000 2000 3000 10 3/4" x 13-1/2J L 4000 -2500 5000 6000 -5000 7000 0 z 8000 9000 o-7500 U) 10000 11000 -10000 2S-315 T01 TC 032818 PP 12000 � 1300 I' � 7-5/8" x 9-7/8" - A,�g3 -12500 \ -7500 -5000 -2500 0 2500 5000 7500 10000 West( -)/East(+) 2S-315 wp03 Section View 0- Ugnu C Ugnu B it 16" x 42" 0 -Base Perm i Ugnu A 1000 West Sak Top West Sak Base 0 3� �O C-90 - 20 C-80 2000 ° o Campanian SS i coo oo- C", o0 _" _ 10 _ oo .23000- coo o > 10 3/4" x 13-1/2 o q C-50 0 o0 o C-40 4000-1 C-37 (Top Iceberg) o o'. T-6 (Base I eberg C Top airn - - _ - - M Ba e Cai 5000 C-35 6000 7-5/8" x �10 9-7/8" -- 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 185.000 Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-315 50103xxxxx00 Plan: 2S-315 Plan: 2S-315 wp03 Standard Proposal Report 09 August, 2018 ConocoPh i I I i ps ConocoPhillips p Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-315 Wellbore: Plan: 2S-315 Design: 2S-315 wp03 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 2S-315 TVD Reference: Rig: 39+120 @ 159.00usft (Doyonl42) MD Reference: Rig: 39+120 @ 159.00usft (Doyon142) North Reference: True - Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: -0.14 ° Well Plan: 2S-315 Well Position +N/ -S -75.59 usft Northing: Latitude: +El -W -352.22 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 120.00 usft Wellbore Plan: 2S-315 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 12/10/2018 16.66 80.77 57,415 Design 2S-315 wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: Vertical Section: Depth From (TVD) +N/ -S +E/ -W (usft) (usft) (usft) 39.00 0.00 0.00 Pian Survey Tool Program Date 8/8/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,500.00 2S-315 wp03 (Plan: 2S-315) GYD-GC-SS Gyrodata gyro single shots 2 1,500.00 3,650.00 25-315 wp03 (Plan: 2S-315) MWD MWD - Standard 3 1,500.00 3,650.00 25-315 wp03 (Plan: 25-315) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 3,650.00 5,150.00 2S-315 wp03 (Plan: 2S-315) MWD MWD - Standard 5 3,650.00 14,634.68 2S-315 wp03 (Plan: 2S-315) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 39.00 Direction (I 185.00 8/9/2018 10:11:09AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips p Database: OAKEDMP2 Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2S Pad North Reference: Well: Plan: 2S-315 Survey Calculation Method: Wellbore: Plan: 2S-315 Design: 2S-315 wp03 Measured ConocoPhillips Standard Proposal Report Well Plan: 2S-315 Rig: 39+120 @ 159.00usft (Doyon142) Rig: 39+120 @ 159.00usft (Doyon142) True Minimum Curvature 8/9/2018 10:11:09AM Page 3 COMPASS 5000.14 Build 85 Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°1100usft) (°/100usft) (°) Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 2.00 180.24 599.96 -3.49 -0.01 1.00 1.00 0.00 180.24 1,455.52 21.25 180.24 1,434.00 -175.07 -0.73 2.25 2.25 0.00 0.00 1,562.82 21.25 180.24 1,534.00 -213.95 -0.90 0.00 0.00 0.00 0.00 3,117.75 75.67 180.24 2,526.80 -1,334.55 -5.63 3.50 3.50 0.00 0.00 12,824.14 75.67 180.24 4,928.88 -10,738.93 -45.52 0.00 0.00 0.00 0.00 13,816.48 45.00 161.00 5,417.58 -11,577.22 70.24 3.50 -3.09 -1.94 -155.86 14,016.48 45.00 161.00 5,559.00 -11,710.94 116.28 0.00 0.00 0.00 0.00 2S-315 T01 TC 0328' 14,334.68 45.00 161.00 5,784.00 -11,923.68 189.53 0.00 0.00 0.00 0.00 14,634.68 45.00 161.00 5,996.13 , -12,124.26 258.60 0.00 0.00 0.00 0.00 8/9/2018 10:11:09AM Page 3 COMPASS 5000.14 Build 85 f ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 2S-315 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Rig: 39+120 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Rig: 39+120 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Plan: 25-315 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2S-315 (°) (usft) Design: 2S-315 wp03 (usft) (°/100usft) Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 1.00 180.24 499.99 -0.87 0.00 0.87 1.00 1.00 0.00 600.00 2.00 180.24 599.96 -3.49 -0.01 3.48 1.00 1.00 0.00 700.00 4.25 180.24 699.80 -8.94 -0.04 8.91 2.25 2.25 0.00 800.00 6.50 180.24 799.36 -18.31 -0.08 18.25 2.25 2.25 0.00 900.00 8.75 180.24 898.47 -31.58 -0.13 31.47 2.25 2.25 0.00 1,000.00 11.00 180.24 996.98 -48.72 -0.20 48.56 2.25 2.25 0.00 1,100.00 13.25 180.24 1,094.74 -69.73 -0.29 69.49 2.25 2.25 0.00 1,200.00 15.50 180.24 1,191.61 -94.55 -0.40 94.23 2.25 2.25 0.00 1,300.00 17.75 180.24 1,287.42 -123.16 -0.52 122.74 2.25 225 0.00 1,400.00 20.00 180.24 1,382.04 -155.51 -0.65 154.97 2.25 2.25 0.00 1,455.52 21.25 180.24 1,434.00 -175.07 -0.73 174.46 2.25 2.25 0.00 1,500.00 21.25 180.24 1,475.45 -191.19 -0.80 190.53 0.00 0.00 0.00 1,562.82 21.25 180.24 1,534.00 -213.95 -0.90 213.22 0.00 0.00 0.00 1,600.00 22.55 180.24 1,568.50 -227.82 -0.95 227.04 3.50 3.50 0.00 1,700.00 26.05 180.24 1,659.62 -268.97 -1.13 268.04 3.50 3.50 0.00 1,800.00 29.55 180.24 1,748.07 -315.60 -1.32 314.51 3.50 3.50 0.00 1,900.00 33.05 180.24 1,833.50 -367.54 -1.54 366.28 3.50 3.50 0.00 2,000.00 36.55 180.24 1,915.60 -424.61 -1.78 423.14 3.50 3.50 0.00 2,100.00 40.05 180.24 1,994.07 -486.57 -2.04 484.90 3.50 3.50 0.00 2,200.00 43.55 180.24 2,068.60 -553.22 -2.32 551.31 3.50 3.50 0.00 2,300.00 47.05 180.24 2,138.93 -624.29 -2.63 622.14 3.50 3.50 0.00 2,400.00 50.55 180.24 2,204.79 -699.52 -2.94 697.11 3.50 3.50 0.00 2,500.00 54.05 180.24 2,265.93 -778.63 -3.28 775.95 3.50 3.50 0.00 2,600.00 57.55 180.24 2,322.13 -861.32 -3.63 858.36 3.50 3.50 0.00 2,700.00 61.05 180.24 2,373.17 -947.29 -3.99 944.04 3.50 3.50 0.00 2,800.00 64.55 180.24 2,418.87 -1,036.22 -4.37 1,032.66 3.50 3.50 0.00 2,900.00 68.05 180.24 2,459.06 -1,127.77 -4.76 1,123.89 3.50 3.50 0.00 3,000.00 71.55 180.24 2,493.59 -1,221.61 -5.15 1,217.41 3.50 3.50 0.00 3,100.00 75.05 180.24 2,522.32 -1,317.37 -5.56 1,312.84 3.50 3.50 0.00 3,117.75 75.67 180.24 2,526.80 -1,334.55 -5.63 1,329.96 3.50 3.50 0.00 3,200.00 75.67 180.24 2,547.16 -1,414.24 -5.97 1,409.38 0.00 0.00 0.00 3,300.00 75.67 180.24 2,571.90 -1,511.13 -6.38 1,505.93 0.00 0.00 0.00 3,400.00 75.67 180.24 2,596.65 -1,608.01 -6.79 1,602.49 0.00 0.00 0.00 3,500.00 75.67 180.24 2,621.40 -1,704.90 -7.20 1,699.04 0.00 0.00 0.00 3,600.00 75.67 180.24 2,646.15 -1,801.79 -7.61 1,795.60 0.00 0.00 0.00 3,700.00 75.67 180.24 2,670.89 -1,898.68 -8.02 1,892.15 0.00 0.00 0.00 3,800.00 75.67 180.24 2,695.64 -1,995.57 -8.44 1,988.71 0.00 0.00 0.00 3,900.00 75.67 180.24 2,720.39 -2,092.46 -8.85 2,085.27 0.00 0.00 0.00 4,000.00 75.67 180.24 2,745.14 -2,189.35 -9.26 2,181.82 0.00 0.00 0.00 4,100.00 75.67 180.24 2,769.88 -2,286.23 -9.67 2,278.38 0.00 0.00 0.00 4,200.00 75.67 180.24 2,794.63 -2,383.12 -10.08 2,374.93 0.00 0.00 0.00 4,300.00 75.67 180.24 2,819.38 -2,480.01 -10.49 2,471.49 0.00 0.00 0.00 4,400.00 75.67 180.24 2,844.13 -2,576.90 -10.90 2,568.04 0.00 0.00 0.00 4,500.00 75.67 180.24 2,868.87 -2,673.79 -11.31 2,664.60 0.00 0.00 0.00 4,600.00 75.67 180.24 2,893.62 -2,770.68 -11.72 2,761.16 0.00 0.00 0.00 4,700.00 75.67 180.24 2,918.37 -2,867.57 -12.13 2,857.71 0.00 0.00 0.00 4,800.00 75.67 180.24 2,943.12 -2,964.45 -12.54 2,954.27 0.00 0.00 0.00 4,900.00 75.67 180.24 2,967.86 -3,061.34 -12.96 3,050.82 0.00 0.00 0.00 5,000.00 75.67 180.24 2,992.61 -3,158.23 -13.37 3,147.38 0.00 0.00 0.00 M12018 10:11:09AM Page 4 COMPASS 5000.14 Build 85 Planned Survey Measured ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 2S-315 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Rig: 39+120 @ 159.O0usft (Doyon142) Project: Kuparuk River Unit MD Reference: Rig: 39+120 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Plan: 2S-315 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2S-315 (usft) (usft) Design: 2S-315 wp03 (usft) (°/100usft) Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (^) (1) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) 5,100.00 75.67 180.24 3,017.36 -3,255.12 -13.78 3,243.93 0.00 0.00 0.00 5,200.00 75.67 180.24 3,042.11 -3,352.01 -14.19 3,340.49 0.00 0.00 0.00 5,300.00 75.67 180.24 3,066.85 -3,448.90 -14.60 3,437.05 0.00 0.00 0.00 5,400.00 75.67 180.24 3,091.60 -3,545.79 -15.01 3,533.60 0.00 0.00 0.00 5,500.00 75.67 180.24 3,116.35 -3,642.67 -15.42 3,630.16 0.00 0.00 0.00 5,600.00 75.67 180.24 3,141.09 -3,739.56 -15.83 3,726.71 0.00 0.00 0.00 5,700.00 75.67 180.24 3,165.84 -3,836.45 -16.24 3,823.27 0.00 0.00 0.00 5,800.00 75.67 180.24 3,190.59 -3,933.34 -16.65 3,919.82 0.00 0.00 0.00 5,900.00 75.67 180.24 3,215.34 -4,030.23 -17.06 4,016.38 0.00 0.00 0.00 6,000.00 75.67 180.24 3,240.08 -4,127.12 -17.48 4,112.94 0.00 0.00 0.00 6,100.00 75.67 180.24 3,264.83 -4,224.01 -17.89 4,209.49 0.00 0.00 0.00 6,200.00 75.67 180.24 3,289.58 -4,320.89 -18.30 4,306.05 0.00 0.00 0.00 6,300.00 75.67 180.24 3,314.33 -4,417.78 -18.71 4,402.60 0.00 0.00 0.00 6,400.00 75.67 180.24 3,339.07 -4,514.67 -19.12 4,499.16 0.00 0.00 0.00 6,500.00 75.67 180.24 3,363.82 -4,611.56 -19.53 4,595.71 0.00 0.00 0.00 6,600.00 75.67 180.24 3,388.57 -4,708.45 -19.94 4,692.27 0.00 0.00 0.00 6,700.00 75.67 180.24 3,413.32 -4,805.34 -20.35 4,788.83 0.00 0.00 0.00 6,800.00 75.67 180.24 3,438.06 -4,902.23 -20.76 4,885.38 0.00 0.00 0.00 6,900.00 75.67 180.24 3,462.81 -4,999.11 -21.17 4,981.94 0.00 0.00 0.00 7,000.00 75.67 180.24 3,487.56 -5,096.00 -21.58 5,078.49 0.00 0.00 0.00 7,100.00 75.67 180.24 3,512.31 -5,192.89 -22.00 5,175.05 0.00 0.00 0.00 7,200.00 75.67 180.24 3,537.05 -5,289.78 -22.41 5,271.60 0.00 0.00 0.00 7,300.00 75.67 180.24 3,561.80 -5,386.67 -22.82 5,368.16 0.00 0.00 0.00 7,400.00 75.67 180.24 3,586.55 -5,483.56 -23.23 5,464.72 0.00 0.00 0.00 7,500.00 75.67 180.24 3,611.30 -5,580.45 -23.64 5,561.27 0.00 0.00 0.00 7,600.00 75.67 180.24 3,636.04 -5,677.33 -24.05 5,657.83 0.00 0.00 0.00 7,700.00 75.67 180.24 3,660.79 -5,774.22 -24.46 5,754.38 0.00 0.00 0.00 7,800.00 75.67 180.24 3,685.54 -5,871.11 -24.87 5,850.94 0.00 0.00 0.00 7,900.00 75.67 180.24 3,710.29 -5,968.00 -25.28 5,947.49 0.00 0.00 0.00 8,000.00 75.67 180.24 3,735.03 -6,064.89 -25.69 6,044.05 0.00 0.00 0.00 8,100.00 75.67 180.24 3,759.78 -6,161.78 -26.10 6,140.61 0.00 0.00 0.00 8,200.00 75.67 180.24 3,784.53 -6,258.67 -26.51 6,237.16 0.00 0.00 0.00 8,300.00 75.67 180.24 3,809.28 -6,355.55 -26.93 6,333.72 0.00 0.00 0.00 8,400.00 75.67 180.24 3,834.02 -6,452.44 -27.34 6,430.27 0.00 0.00 0.00 8,500.00 75.67 180.24 3,858.77 -6,549.33 -27.75 6,526.83 0.00 0.00 0.00 8,600.00 75.67 180.24 3,883.52 -6,646.22 -28.16 6,623.38 0.00 0.00 0.00 8,700.00 75.67 180.24 3,908.27 -6,743.11 -28.57 6,719.94 0.00 0.00 0.00 8,800.00 75.67 180.24 3,933.01 -6,840.00 -28.98 6,816.50 0.00 0.00 0.00 8,900.00 75.67 180.24 3,957.76 -6,936.89 -29.39 6,913.05 0.00 0.00 0.00 9,000.00 75.67 180.24 3,982.51 -7,033.77 -29.80 7,009.61 0.00 0.00 0.00 9,100.00 75.67 180.24 4,007.26 -7,130.66 -30.21 7,106.16 0.00 0.00 0.00 9,200.00 75.67 180.24 4,032.00 -7,227.55 -30.62 7,202.72 0.00 0.00 0.00 9,300.00 75.67 180.24 4,056.75 -7,324.44 -31.03 7,299.27 0.00 0.00 0.00 9,400.00 75.67 180.24 4,081.50 -7,421.33 -31.45 7,395.83 0.00 0.00 0.00 9,500.00 75.67 180.24 4,106.25 -7,518.22 -31.86 7,492.38 0.00 0.00 0.00 9,600.00 75.67 180.24 4,130.99 -7,615.11 -32.27 7,588.94 0.00 0.00 0.00 9,700.00 75.67 180.24 4,155.74 -7,711.99 -32.68 7,685.50 0.00 0.00 0.00 9,800.00 75.67 180.24 4,180.49 -7,808.88 -33.09 7,782.05 0.00 0.00 0.00 9,900.00 75.67 180.24 4,205.23 -7,905.77 -33.50 7,878.61 0.00 0.00 0.00 10,000.00 75.67 180.24 4,229.98 -8,002.66 -33.91 7,975.16 0.00 0.00 0.00 10,100.00 75.67 180.24 4,254.73 -8,099.55 -34.32 8,071.72 0.00 0.00 0.00 10,200.00 75.67 180.24 4,279.48 -8,196.44 -34.73 8,168.27 0.00 0.00 0.00 10,300.00 75.67 180.24 4,304.22 -8,293.33 -35.14 8,264.83 0.00 0.00 0.00 10,400.00 75.67 180.24 4,328.97 -8,390.21 -35.55 8,361.39 0.00 0.00 0.00 8/9/2018 10:11:09AM Page 5 COMPASS 5000.14 Build 85 sConocoPhillip ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 25-315 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Rig: 39+120 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Rig: 39+120 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Plan: 2S-315 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2S-315 Design: 2S-315 wp03 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (1) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 10,500.00 75.67 180.24 4,353.72 -8,487.10 -35.97 8,457.94 0.00 0.00 0.00 10,600.00 75.67 180.24 4,378.47 -8,583.99 -36.38 8,554.50 0.00 0.00 0.00 10,700.00 75.67 180.24 4,403.21 -8,680.88 -36.79 8,651.05 0.00 0.00 0.00 10,800.00 75.67 180.24 4,427.96 -8,777.77 -37.20 8,747.61 0.00 0.00 0.00 10,900.00 75.67 180.24 4,452.71 -8,874.66 -37.61 8,844.16 0.00 0.00 0.00 11,000.00 75.67 180.24 4,477.46 -8,971.55 -38.02 8,940.72 0.00 0.00 0.00 11,100.00 75.67 180.24 4,502.20 -9,068.43 -38.43 9,037.28 0.00 0.00 0.00 11,200.00 75.67 180.24 4,526.95 -9,165.32 -38.84 9,133.83 0.00 0.00 0.00 11,300.00 75.67 180.24 4,551.70 -9,262.21 -39.25 9,230.39 0.00 0.00 0.00 11,400.00 75.67 180.24 4,576.45 -9,359.10 -39.66 9,326.94 0.00 0.00 0.00 11,500.00 75.67 180.24 4,601.19 -9,455.99 -40.07 9,423.50 0.00 0.00 0.00 11,600.00 75.67 180.24 4,625.94 -9,552.88 -40.49 9,520.05 0.00 0.00 0.00 11,700.00 75.67 180.24 4,650.69 -9,649.77 -40.90 9,616.61 0.00 0.00 0.00 11,800.00 75.67 180.24 4,675.44 -9,746.65 -41.31 9,713.17 0.00 0.00 0.00 11,900.00 75.67 180.24 4,700.18 -9,843.54 -41.72 9,809.72 0.00 0.00 0.00 12,000.00 75.67 180.24 4,724.93 -9,940.43 -42.13 9,906.28 0.00 0.00 0.00 12,100.00 75.67 180.24 4,749.68 -10,037.32 -42.54 10,002.83 0.00 0.00 0.00 12,200.00 75.67 180.24 4,774.43 -10,134.21 -42.95 10,099.39 0.00 0.00 0.00 12,300.00 75.67 180.24 4,799.17 -10,231.10 -43.36 10,195.94 0.00 0.00 0.00 12,400.00 75.67 180.24 4,823.92 -10,327.99 -43.77 10,292.50 0.00 0.00 0.00 12,500.00 75.67 180.24 4,848.67 -10,424.87 -44.18 10,389.06 0.00 0.00 0.00 12,600.00 75.67 180.24 4,873.42 -10,521.76 -44.59 10,485.61 0.00 0.00 0.00 12,700.00 75.67 180.24 4,898.16 -10,618.65 -45.00 10,582.17 0.00 0.00 0.00 12,800.00 75.67 180.24 4,922.91 -10,715.54 -45.42 10,678.72 0.00 0.00 0.00 12,824.14 75.67 180.24 4,928.88 -10,738.93 -45.52 10,702.03 0.00 0.00 0.00 12,900.00 73.25 179.11 4,949.21 -10,812.01 -45.11 10,774.80 3.50 -3.19 -1.49 13,000.00 70.07 177.57 4,980.67 -10,906.88 -42.37 10,869.06 3.50 -3.18 -1.54 13,100.00 66.91 175.97 5,017.33 -10,999.75 -37.14 10,961.13 3.50 -3.17 -1.60 13,200.00 63.76 174.29 5,059.07 -11,090.28 -29.43 11,050.64 3.50 -3.15 -1.68 13,300.00 60.63 172.51 5,105.72 -11,178.13 -19.29 11,137.27 3.50 -3.13 -1.77 13,400.00 57.52 170.63 5,157.11 -11,262.97 -6.73 11,220.70 3.50 -3.10 -1.89 13,500.00 54.45 168.61 5,213.04 -11,344.49 8.18 11,300.61 3.50 -3.07 -2.02 13,600.00 51.41 166.43 5,273.32 -11,422.39 25.39 11,376.71 3.50 -3.04 -2.18 13,700.00 48.42 164.05 5,337.71 -11,496.36 44.85 11,448.71 3.50 -2.99 -2.37 13,800.00 45.48 161.45 5,405.97 -11,566.14 66.47 11,516.34 3.50 -2.94 -2.60 13,816.48 45.00 161.00 5,417.58 -11,577.22 70.24 11,527.05 3.50 -2.90 -2.75 13,900.00 45.00 161.00 5,476.63 -11,633.06 89.46 11,581.00 0.00 0.00 0.00 14,000.00 45.00 161.00 5,547.34 -11,699.92 112.48 11,645.59 0.00 0.00 0.00 14,016.48 45.00 161.00 5,559.00 -11,710.94 116.28 11,656.24 0.00 0.00 0.00 14,100.00 45.00 161.00 5,618.05 -11,766.78 135.51 11,710.19 0.00 0.00 0.00 14,200.00 45.00 161.00 5,688.77 -11,833.64 158.53 11,774.79 0.00 0.00 0.00 14,300.00 45.00 161.00 5,759.48 -11,900.49 181.55 11,839.39 0.00 0.00 0.00 14,334.68 45.00 161.00 5,784.00 -11,923.68 189.53 11,861.79 0.00 0.00 0.00 14,400.00 45.00 161.00 5,830.19 -11,967.35 204.57 11,903.98 0.00 0.00 0.00 14,500.00 45.00 161.00 5,900.90 -12,034.21 227.59 11,968.58 0.00 0.00 0.00 14,600.00 45.00 161.00 5,971.61 -12,101.07 250.61 12,033.18 0.00 0.00 0.00 14,634.68 45.00 161.00 5,996.13. -12,124.26 258.60 12,055.58 0.00 0.00 0.00 8/9/2018 10.11:09AM Page 6 COMPASS 5000.14 Build 85 I ConocoPhillips p ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 2S-315 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Rig: 39+120 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Rig: 39+120 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Plan: 2S-315 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2S-315 119.00 119.00 16" x 42" Design: 2S-315 wp03 42.000 3,651.94 Design Targets 10.750 13.500 Target Name 5,996.13 7-5/8" x 9-7/8" 7.625 hittmiss target Dip Angle Dip Dir. TVD +Nl-S +E/ -W Northing Easting -Shape C) (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2S-315 T01 TC 032818 0.00 0.00 5,559.00 -11,710.94 116.28 0.00 - plan hits target center 2,445.00 West Sak Base -Circle (radius 100.00) 3,655.98 2,660.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 119.00 119.00 16" x 42" 16.000 42.000 3,651.94 2,659.00 10 3/4" x 13-1/2 10.750 13.500 14,634.68 5,996.13 7-5/8" x 9-7/8" 7.625 9.875 Formations Measured Vertical Vertical Dip Depth Depth Depth Dip Direction (usft) (usft) Name Lithology V) (�) 1,169.33 1,162.00 Ugnu C 0.00 1,425.55 1,406.00 Ugnu B 0.00 1,454.45 1,433.00 Base Perm 0.00 1,518.83 1,493.00 UgnuA 0.00 1,895.83 1,830.00 West Sak Top 0.00 2,863.39 2,445.00 West Sak Base 0.00 3,655.98 2,660.00 C-90 0.00 4,456.06 2,858.00 C-80 0.00 4,698.51 2,918.00 Campanian SS 0.00 10,537.50 4,363.00 C-50 0.00 11,648.73 4,638.00 C-40 0.00 12,307.38 4,801.00 C-37 (Top Iceberg) 0.00 13,795.76 5,403.00 T-6 (Base Iceberg) 0.00 14,016.48 5,559.00 Top Cairn 0.00 14,334.68 5,784.00 Base Cairn 0.00 14,480.35 5,887.00 C-35 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 KOP: Start 1°/100' DLS, 180.24° TF, for 200' 600.00 599.96 -3.49 -0.01 Start 2.25°/100' DLS, 0° TF, for 855.52' 1,455.52 1,434.00 -175.07 -0.73 Hold for 107.29' 1,562.82 1,534.00 -213.95 -0.90 Start 3.5°/100' DLS, 0° TF, for 1554.93' 3,117.75 2,526.80 -1,334.55 -5.63 Hold for 9706.39' 12,824.14 4,928.88 -10,738.93 -45.52 Start 3.5°/100' DLS, -155.86° TF, for 992.35' 13,816.48 5,417.58 -11,577.22 70.24 Hold for 200' 14,016.48 5,559.00 -11,710.94 116.28 Adjust TF to 0°, for 318.2' 14,334.68 5,784.00 -11,923.68 189.53 Adjust TF to 0°, for 300' 14,634.68 5,996.13 -12,124.26 258.60 TD: 14634.68' MD, 5996.13' TVD 8/9/2018 10:11:09AM Page 7 COMPASS 5000.14 Build 85 AC Summary ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-315 Plan: 2S-315 50103xxxxx00 2S-315 wp03 ConocoPhillips Clearance Summary Anticollision Report 09 August, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-315 - Plan: 2S-315 - 2S-315 wp03 Well Coordinates: Datum Height: Rig: 39+120 @ 159.00usft (Doyon142) Scan Range: 0.00 to 14,634.68 usft. Measured Depth. Scan Radius is 1,659.57 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 2S-315 - 2S-315 wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-315 - Plan: 2S-315 - 2S-315 wp03 Scan Range: 0.00 to 14,634.68 usft. Measured Depth. Scan Radius is 1,659.57 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Site Name Depth Distance Depth Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) Kuparuk 2S Pad 2S-04 - 2S-04 - 2S-04 2S-04 - 2S-04PB1 - 2S-04PB1 2S-05 - 2S-05 - 2S-05 2S-05 - 2S-05 - 2S-05 2S-06 - 2S-06 - 2S-06 2S-06 - 2S-06 - 2S-06 2S-07 - 2S-07 - 2S-07 2S-07 - 2S-07 - 2S-07 2S-08 - 2S-08 - 2S-08 2S-08 - 2S-08 - 2S-08 2S-09 - 2S-09 - 2S-09 2S-09 - 2S-09 - 2S-09 2S-09 - 2S -09A - 2S -09A 2S-09 - 2S -09A - 2S -09A 2S-10 - 2S-10 - 2S-10 2S-10 - 2S-10 - 2S-10 2S-11 - 2S-11 - 2S-11 2S-11 - 2S-11 - 2S-11 2S-12 - 2S-12 - 2S-12 2S-12 - 2S-12 - 2S-12 2S-12 - 2S-12PB1 - 2S-12PB1 2S-12 - 2S-12PB1 - 2S-12PB1 2S-13 - 2S-13 - 2S-13 2S-13 - 2S-13 - 2S-13 2S-13 - 2S -13A- 2S -13A 2S-13 - 2S -13A - 2S -13A 2S-13 - 2S-13AL1 - 2S-13AL1 2S-13 - 2S-13AL1 - 2S-13AL1 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Ellipse @Measured Clearance Summary Based on Separation Depth Factor Minimum Separation Warning (usft) usft 1,973.83 187.30 1,973.83 156.20 2,050.00 6.022 Clearance Factor Pass - Major Risk 1,973.83 187.30 1,973.83 156.20 2,050.00 6.022 Clearance Factor Pass - Major Risk 510.41 237.71 510.41 229.27 500.00 28.164 Centre Distance Pass - Major Risk 682.93 238.45 682.93 227.58 675.00 21.950 Clearance Factor Pass - Major Risk 99.90 210.25 99.90 207.21 100.00 69.287 Centre Distance Pass - Major Risk 449.38 211.96 449.38 204.14 450.00 27.087 Clearance Factor Pass - Major Risk 610.02 178.95 610.02 163.26 600.00 11.412 Centre Distance Pass - Major Risk 708.59 179.64 708.59 162.74 700.00 10.631 Clearance Factor Pass - Major Risk 656.83 145.75 656.83 135.46 650.00 14.161 Centre Distance Pass - Major Risk 704.58 146.13 704.58 135.19 700.00 13.356 Clearance Factor Pass - Major Risk 698.28 116.33 698.28 105.27 700.00 10.519 Centre Distance Pass - Major Risk 2,317.57 131.58 2,317.57 82.28 2,300.00 2.669 Clearance Factor Pass - Major Risk 698.28 116.33 698.28 105.27 700.00 10.519 Centre Distance Pass - Major Risk 2,317.57 131.58 2,317.57 82.28 2,300.00 2.669 Clearance Factor Pass - Major Risk 61.50 89.50 61.50 86.78 50.00 32.874 Centre Distance Pass - Major Risk 436.35 93.23 436.35 85.69 425.00 12.364 Clearance Factor Pass - Major Risk 1,404.39 44.83 1,404.39 22.50 1,400.00 2.008 Centre Distance Pass - Major Risk 1,454.97 45.25 1,454.97 22.22 1,450.00 1.965 Clearance Factor Pass - Major Risk 461.40 29.17 461.40 21.38 450.00 3.746 Centre Distance Pass - Major Risk 536.15 29.56 536.15 20.77 525.00 3.361 Clearance Factor Pass - Major Risk 461.40 29.17 461.40 21.38 450.00 3.746 Centre Distance Pass - Major Risk 536.15 29.56 536.15 20.77 525.00 3.361 Clearance Factor Pass - Major Risk 61.50 59.84 61.50 56.95 50.00 20.687 Centre Distance Pass - Major Risk 336.48 60.88 336.48 54.87 325.00 10.127 Clearance Factor Pass - Major Risk 49.90 59.84 49.90 57.11 50.00 21.891 Centre Distance Pass - Major Risk 349.88 61.12 349.88 54.88 350.00 9.789 Clearance Factor Pass - Major Risk 49.90 59.84 49.90 57.11 50.00 21.891 Centre Distance Pass - Major Risk 349.88 61.12 349.88 54.88 350.00 9.789 Clearance Factor Pass - Major Risk 09 August, 2018 - 10:22 Page 2 of 5 COMPASS ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-315 - 2S-315 wpO3 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-315 - Plan: 2S-315 - 2S-315 wp03 Scan Range: 0.00 to 14,634.68 usft. Measured Depth. Scan Radius is 1,659.57 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 2S-13 - 2S-131-1 - 2S-131-1 61.50 59.84 61.50 56.95 50.00 20.687 Centre Distance Pass - Major Risk 2S-13 - 2S-1311 - 2S-131-1 336.48 60.88 336.48 54.87 325.00 10.127 Clearance Factor Pass - Major Risk 2S-13 - 2S-13PB1 - 2S-13PB1 61.50 59.84 61.50 56.95 50.00 20.687 Centre Distance Pass - Major Risk 2S-13 - 2S-13PB1 - 2S-13PB1 336.48 60.88 336.48 54.87 325.00 10.127 Clearance Factor Pass - Major Risk 2S-14 - 2S-14 - 2S-14 324.89 29.05 324.89 23.37 325.00 5.112 Centre Distance Pass - Major Risk 2S-14 - 2S-14 - 2S-14 399.85 29.49 399.85 22.55 400.00 4.251 Clearance Factor Pass - Major Risk Non -Pad Shark Tooth #1 - Shark Tooth #1 - Shark Tooth #1 5,858.01 625.93 5,858.01 520.91 3,200.00 Survey tool program From To (usft) (usft) 39.00 1,500.00 2S-315 wp03 1,500.00 3,650.00 2S-315 wp03 1,500.00 3,650.00 2S-315 wp03 3,650.00 5,150.00 2S-315 wp03 3,650.00 14,634.68 2S-315 wp03 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan 5.960 Clearance Factor Survey Tool GYD-GC-SS MWD M W D+l F R-AK-CAZ-SC MWD M W D+I F R-AK-CAZ-SC Pass - Major Risk 09 August, 2018 - 10:22 Page 3 of 5 COMPASS 10:24, August 09 2018 2S-315 wp03 Ladder View 285 m N �.... O 0 N O co i ,) 9 0 0 � I � o 0 0 N i i o 95 I N 1 I 1 Equivalent Magnetic Distance 0 0 900 1800 2700 3600 4500 5400 6300 Measured Depth SURVEY PROGRAM CASING DETAILS pth From Depth To Survey/Plan Tool T D MD Nam 39.00 1500.00 2S-315 wp03 (Plan: 2S-315) GYD-GC-SS 119.00 119.00 16" x 42" 1500.00 3650.00 2S-315 wp03 (Plan: 2S-315) MWD 2659.00 3651.94 10 3/4" x 13-1/2 1500.00 3650.00 2S-315 wp03 (Plan: 2S-315) MWD+IFR-AK-CAZ-SC 5996.13 14634.68 7-5/8" x 9-7/8" 3650.00 5150.00 2S-315 wp03 (Plan: 2S-315) MWD 3650.0014634.68 2S-315 wp03 (Plan: 2S-315) MWD+IFR-AK-CAZ-SC m c. 60—.-- cn i.... I ..... c 0 i ct5 ro Q 0 W a) a. a v X30 - — -- ---- U 0 v Equivalent Magnetic Distance U o 0 550 1100 1650 2200 2750 Partial Measured Depth 10:43, August 09 2018 2S-315 wp03 TC View SURVEY PROGRAM SECTION DETAILS From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 39.06500.00 GYD-GC-SS 39.00 0.00 0.00 39.00 0.00 0.00 1500.00 3650.00 MWD 400.00 0.00 0.00 400.00 0.00 0.00 KOP: Start 1 %100' DLS, 180.24' TF, for 200' 1500.00 3650.00 MWD+IFR-AK-CAZ-SC 600.00 2.00 180.24 599.96 1.00 180.24 Start 2.25'/100' DLS, 0°TF, for 855.52' 3650.00 5150.00 MWD 1455.52 21.25 180.24 1434.00 2.25 0.00 Hold for 107.29' 3650.0014634.68 MWD+IFR-AK-CAZ-SC 1562.82 21.25 180.24 1534.00 0.00 0.00 Start 3.5%100' DLS, 0°TF, for 1554.93' 3117.75 75.67 180.24 2526.80 3.50 0.00 Hold for 9706.39' 12824.14 75.67 180.24 4928.88 0.00 0.00 Start 3.5°/100' DLS, -155.86°TF, for 992.35' 13816.48 45.00 161.00 5417.58 3.50 -155.86 Hold for 200' 14016.48 45.00 161.00 5559.00 0.00 0.00 2S-315 T01 TC 032818 PP Adjust TF to 0', for 318.2' 14334.68 45.00 161.00 5784.00 0.00 0.00 Adjust TF to 0', for 300' 14634.68 45.00 161.00 5996.13 0.00 0.00 TD: 14634.68' MD, 5996.13' TVD CASING DETAILS TVD MD Name 119.00 119.00 16" x 42" 2659.00 3651.94 10 3/4" x 13-1/2 5996.13 14634.68 7-5/8" x 9-7/8" S-13 D 1 330 08 0 10 \� 09A 39 400 400 590 l 300 590-- 770 .,` i \0 770 960 \ 960 1140 2S 11n }`3 1140-- 1330 1330 1510 7-07 1510 - 1700 3 ,a I `� 1700 2240 1 2240 2780 270 u: 1� --�� 90 2780 3310 3310 3850 �����\ -- S-1 /,�% 3850 4390 4390 4920 ,r 4 r 4920 - 5460 5460 6000 6000 -- 7080 7080 8160 90 8160- 9240 240 - 120 9240 1032 12 10320-- 1140 11400 1247 12470 1356 150 13560 1463 210 150 180 180 2S-315 wp03 39.00 To 14634.68 1 Spider Easting (3500 usfbin) ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-315 50103xxxxx00 Plan: 2S-315 Plan: 2S-315 wp03 Error Ellipse Survey Report 09 August, 2018 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan 2S-315 Wellbore: Plan: 2S-315 Design: 2S-315 wp03 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: Well Plan: 2S-315 TVD Reference: Rig 39+120 @ 159-00usft (Doyon 142) MD Reference: Rig 39+120 @ 159.00usft (Doyonl42) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: -0.14 ° Well Plan: 2S-315 Well Position +N/ -S 0.00 usft Northing: Latitude: +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: Wellbore Plan: 2S-315 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (1) (nT) BGGM2018 12/10/2018 16.66 80.77 57,415 Design 2S-315 wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 39.00 0.00 0.00 185.00 Survey Tool Program Date 8/8/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 1,500.00 2S-315 wp03 (Plan: 2S-315) GYD-GC-SS Gyrodata gyro single shots 1,500.00 3,650.00 2S-315 wp03 (Plan: 2S-315) MWD MWD - Standard 1,500.00 3,650.00 2S-315 wp03 (Plan: 2S-315) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,650.00 5,150.00 2S-315 wp03 (Plan: 2S-315) MWD MWD - Standard 3,650.00 14,634.68 2S-315 wp03 (Plan: 2S-315) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/9/2018 10:11:32AM Page 2 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-315 Wellbore: Plan: 2S-315 Design: 2S-315 wp03 Plan Survey Tool Program Date 8/8/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) 1 39.00 1,500.00 2S-315 wp03 (Plan: 25-315) 2 1,500.00 3,650.00 2S-315 wp03 (Plan: 2S-315) 3 1,500.00 3,650.00 2S-315 wp03 (Plan: 2S-315) 4 3,650.00 5,150.00 2S-315 wp03 (Plan- 2S-315) 5 3,650.00 14,634.68 2S-315 wp03 (Plan: 2S-315) Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Tool Name Remarks GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard M WD+I F R-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard M WD+I F R-AK-CAZ-SC MWD+IFR AK CAZ SCC Well Plan: 2S-315 Rig: 39+120 @ 159.00usft (Doyon142) Rig: 39+120 @ 159.00usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination Azimuth Vertical Highside Lateral 0.56 Vertical 1.15 Magnitude Semi -major Seml-minor 0.56 Depth 600.00 2.00 Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) lusft) (usft) (usft) (unit) (usft) (usft) (usft) (usft) (usft) (usft) r) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.04 0.00 0.04 0.00 1.15 0.00 0.00 0.04 0.04 0.00 200.00 0.00 0.00 200.00 0.19 0.00 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 300.00 0.00 0.00 300.00 0.33 0.00 0.33 0.00 1.15 0.00 0.00 0.33 0.33 0.00 400.00 0.00 0.00 400.00 0.48 0.00 0.48 0.00 1.15 0.01 0.01 0.48 0.48 0.00 500.00 1.00 180.24 499.99 0.56 0.00 0.56 0.00 1.15 0.02 0.02 0.56 0.56 135.00 600.00 2.00 180.24 599.96 0.60 0.00 0.60 0.00 1.15 0.03 0.03 0.60 0.60 90.24 700.00 4.25 180.24 699.80 0.67 0.00 0.68 0.00 1.15 0.04 0.04 0.68 0.68 90.23 800.00 6.50 180.24 799.36 0.77 0.00 0.77 0.00 1.15 0.05 0.06 0.78 0.77 90.23 900.00 8.75 180.24 898.47 0.88 -0.01 0.89 0.00 1.15 0.07 0.07 0.89 0.89 45.00 1,000.00 11.00 180.24 996.98 1.00 -0.01 1.03 0.00 1.15 0.09 0.09 1.03 1.02 0.25 1,100.00 13.25 180.24 1,094.74 1.12 -0.01 1.19 0.00 1.15 0.12 0.12 1.19 1.16 0.25 1,200.00 15.50 180.24 1,191.61 1.26 -0.02 1.37 0.00 1.15 0.14 0.14 1.37 1.30 0.24 1,300.00 17.75 180.24 1,287.42 1.41 -0.02 1.57 0.00 1.15 0.17 0.17 1.57 1.45 0.24 1,400.00 20.00 180.24 1,382.04 1.56 -0.03 1.79 0.00 1.15 0.20 0.20 1.79 1.61 0.24 1,455.52 21.25 180.24 1,434.00 1.64 -0.04 1.92 0.00 1.16 0.22 0.22 1.92 1.70 0.24 1,500.00 21.25 180.24 1,475.45 1.72 -0.04 2.02 0.00 1.16 0.23 0.24 2.02 1.78 0.24 1,562.82 21.25 180.24 1,534.00 1.78 -0.04 2.11 0.01 1.17 0.25 0.26 2.11 1.83 0.25 1,600.00 22.55 180.24 1,568.50 1.77 -0.04 2.14 0.02 1.17 0.26 0.27 2.14 1.84 0.27 1,700.00 26.05 180.24 1,659.62 1.77 -0.06 2.33 0.04 1.16 0.30 0.31 2.33 1.87 0.36 1,800.00 29.55 180.24 1,748.07 1.78 -0.08 2.71 0.08 1.15 0.33 0.35 2.71 1.92 0.42 1,900.00 33.05 180.24 1,833.50 1.82 -0.10 3.25 0.12 1.16 0.37 0.41 3.25 1.99 0.44 2,000.00 36.55 180.24 1,915.60 1.88 -0.13 3.95 0.18 1.18 0.40 0.46 3.95 2.08 0.44 2,100.00 40.05 180.24 1,994.07 1.97 -0.15 4.76 0.24 1.22 0.44 0.53 4.76 2.18 0.44 2,200.00 43.55 180.24 2,068.60 2.08 -0.18 5.67 0.31 1.29 0.47 0.60 5.67 2.29 0.43 2,300.00 47.05 180.24 2,138.93 2.22 -0.21 6.67 0.39 1.39 0.50 0.68 6.67 2.42 0.42 2,400.00 50.55 180.24 2,204.79 2.39 -0.24 7.74 0.48 1.53 0.53 0.77 7.74 2.55 0.41 2,500.00 54.05 180.24 2,265.93 2.57 -0.28 8.88 0.59 1.70 0.56 0.87 8.88 2.68 0.40 2,600.00 57.55 180.24 2,322.13 2.77 -0.31 10.08 0.70 1.90 0.59 0.97 10.08 2.81 0.39 2,700.00 61.05 180.24 2,373.17 2.98 -0.35 11.34 0.82 2.14 0.61 1.09 11.34 2.94 0.38 2,800.00 64.55 180.24 2,418.87 3.20 -0.39 12.64 0.95 2.39 0.63 1.22 12.64 3.06 0.37 UNDEFINED GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) GYD-GC-SS (1, 1) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) MWD (1, 2) 8/9/2018 10.11:32AM Page 3 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-315 Wellbore: Plan: 2S-315 Design: 2S-315 wp03 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2S-315 Rig: 39+120 @ 159-00usft (Doyon142) Rig: 39+120 @ 159,00usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination Azimuth Vertical Highside Lettered Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Toot (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 2,900.00 68.05 180.24 2,459.06 3.42 -0.43 13.98 1.08 2.67 0.65 1.35 13.98 3.17 0.36 MWD (1, 2) 3,000.00 71.55 180.24 2,493.59 3.65 -0.47 15.35 1.23 2.98 0.67 1.48 15.35 3.27 0.35 MWD (1, 2) 3,100.00 75.05 180.24 2,522.32 3.88 -0.51 16.76 1.38 3.29 0.68 1.63 16.76 3.36 0.34 MWD (1, 2) 3,117.75 75.67 180.24 2,526.80 3.92 -0.52 17.01 1.40 3.35 0.68 1.65 17.01 3.37 0.34 MWD (1, 2) 3,200.00 75.67 180.24 2,547.16 4.20 -0.52 18.18 1.53 3.62 0.69 1.78 18.18 3.43 0.34 MWD (1, 2) 3,300.00 75.67 180.24 2,571.90 4.54 -0.52 19.60 1.68 3.96 0.70 1.93 19.60 3.50 0.33 MWD (1, 2) 3,400.00 75.67 180.24 2,596.65 4.89 -0.52 21.02 1.83 4.30 0.71 2.08 21.02 3.57 0.32 MWD (1, 2) 3,500.00 75.67 180.24 2,621.40 5.24 -0.52 22.45 1.99 4.64 0.72 2.23 22.45 3.65 0.32 MWD (1, 2) 3,600.00 75.67 180.24 2,646.15 5.58 -0.52 23.88 2.14 4.98 0.73 2.38 23.88 3.72 0.32 MWD (1, 2) 3,700.00 75.67 180.24 2,670.89 3.11 -0.52 10.38 0.08 2.72 0.74 1.09 10.38 2.84 0.67 MWD (2, 3) 3,800.00 75.67 180.24 2,695.64 3.15 -0.52 11.13 0.23 2.76 0.75 1.15 11.13 2.85 0.61 MWD (2, 3) 3,900.00 75.67 180.24 2,720.39 3.23 -0.52 12.01 0.38 2.85 0.77 1.23 12.01 2.86 0.55 MWD (2, 3) 4,000.00 75.67 180.24 2,745.14 3.34 -0.52 12.99 0.53 2.97 0.78 1.33 12.99 2.88 0.51 MWD (2,3) 4,100.00 75.67 180.24 2,769.88 3.49 -0.52 14.05 0.69 3.13 0.79 1.43 14.05 2.90 0.47 MWD (2,3) 4,200.00 75.67 180.24 2,794.63 3.67 -0.52 15.17 0.84 3.32 0.80 1.55 15.17 2.92 0.44 MWD (2, 3) 4,300.00 75.67 180.24 2,819.38 3.87 -0.52 16.35 0.99 3.53 0.81 1.67 16.35 2.94 0.41 MWD (2.3) 4,400.00 75.67 180.24 2,844.13 4.10 -0.52 17.56 1.15 3.76 0.83 1.80 17.56 2.97 0.39 MWD (2,3) 4,500.00 75.67 180.24 2,868.87 4.34 -0.52 18.80 1.30 4.00 0.84 1.94 18.80 3.00 0.37 MWD (2, 3) 4,600.00 75.67 180.24 2,893.62 4.60 -0.52 20.07 1.45 4.26 0.85 2.08 20.07 3.03 0.36 MWD (2, 3) 4,700.00 75.67 180.24 2,918.37 4.86 -0.52 21.36 1.60 4.54 0.86 2.22 21.36 3.06 0.35 MWD (2, 3) 4,800.00 75.67 180.24 2,943.12 5.14 -0.52 22.67 1.76 4.82 0.88 2.37 22.67 3.10 0.34 MWD (2, 3) 4,900.00 75.67 180.24 2,967.86 5.43 -0.52 23.99 1.91 5.11 0.89 2.52 23.99 3.14 0.33 MWD (2, 3) 5,000.00 75.67 180.24 2,992.61 5.73 -0.52 25.33 2.06 5.40 0.90 2.67 25.33 3.18 0.32 MWD (2, 3) 5,100.00 75.67 180.24 3,017.36 6.03 -0.52 26.68 2.22 5.70 0.92 2.82 26.68 3.22 0.32 MWD (2, 3) 5,200.00 75.67 180.24 3,042.11 4.14 -0.52 15.26 0.00 3.80 0.93 1.79 15.26 3.04 0.48 MWD+IFR-AK-CAZ-SC (3,3) 5,300.00 75.67 180.24 3,066.85 4.26 -0.52 15.70 0.00 3.92 0.94 1.85 15.70 3.06 0.47 MWD+IFR-AK-CAZ-SC (3,3) 5,400.00 75.67 180.24 3,091.60 4.38 -0.52 16.15 0.00 4.05 0.96 1.90 16.15 3.08 0.47 MWD+IFR-AK-CAZ-SC (3,3) 5,500.00 75.67 180.24 3,116.35 4.51 -0.52 16.61 0.00 4.18 0.97 1.95 16.61 3.10 0.46 MWD+IFR-AK-CAZ-SC (3, 3) 5,600.00 75.67 180.24 3,141.09 4.64 -0.52 17.07 0.00 4.31 0.99 2.01 17.07 3.12 0.46 MWD+IFR-AK-CAZ-SC (3, 3) 5,700.00 75.67 180.24 3,165.84 4.77 -0.52 17.54 0.00 4.44 1.00 2.07 17.54 3.14 0.45 MWD+IFR-AK-CAZ-SC (3,3) 5,800.00 75.67 180.24 3,190.59 4.90 -0.52 18.02 0.00 4.58 1.02 2.12 18.02 3.16 0.45 MWD+IFR-AK-CAZ-SC (3,3) 5,900.00 75.67 180.24 3,215.34 5.04 -0.52 18.50 0.00 4.72 1.03 2.18 18.50 3.19 0.44 MWD+IFR-AK-CAZ-SC (3,3) 6,000.00 75.67 180.24 3,240.08 5.18 -0.52 18.98 0.00 4.86 1.04 2.24 18.98 3.21 0.44 MWD+IFR-AK-CAZ-SC (3,3) 6,100.00 75.67 180.24 3,264.83 5.33 -0.52 19.47 0.00 5.00 1.06 2.30 19.47 3.23 0.43 MWD+IFR-AK-CAZ-SC (3,3) 6,200.00 75.67 180.24 3,289.58 5.47 -0.52 19.97 0.00 5.15 1.08 2.36 19.97 3.26 0.43 MWD+IFR-AK-CAZ-SC (3, 3) 6,300.00 75.67 180.24 3,314.33 5.62 -0.52 20.46 0.00 5.29 1.09 2.42 20.46 3.28 0.43 MWD+IFR-AK-CAZ-SC (3, 3) 6,400.00 75.67 180.24 3,339.07 5.77 -0.52 20.96 0.00 5.44 1.11 2.48 20.96 3.31 0.42 MWD+IFR-AK-CAZ-SC (3,3) 6,500.00 75.67 180.24 3,363.82 5.91 -0.52 21.47 0.00 5.59 1.12 2.55 21.47 3.34 0.42 MWD+IFR-AK-CAZ-SC (3,3) 6,600.00 75.67 180.24 3,388.57 6.07 -0.52 21.97 0.00 5.74 1.14 2.61 21.97 3.36 0.42 MWD+IFR-AK-CAZ-SC (3,3) 6,700.00 75.67 180.24 3,413.32 6.22 -0.52 22.48 0.00 5.89 1.15 2.67 22.48 3.39 0.42 MWD+IFR-AK-CAZ-SC (3,3) 6,800.00 75.67 180.24 3,438.06 6.37 -0.52 22.99 0.00 6.05 1.17 2.74 22.99 3.42 0.41 MWD+IFR-AK-CAZ-SC (3,3) 6,900.00 75.67 180.24 3,462.81 6.53 -0.52 23.51 0.00 6.20 1.19 2.80 23.51 3.45 0.41 MWD+IFR-AK-CAZ-SC (3,3) 7,000.00 75.67 180.24 3,487.56 6.68 -0.52 24.02 0.00 6.35 1.20 2.87 24.02 3.47 0.41 MWD+IFR-AK-CAZ-SC (3,3) 7,100.00 75.67 180.24 3,512.31 6.84 -0.52 24.54 0.00 6.51 1.22 2.93 24.54 3.50 0.41 MWD+IFR-AK-CAZ-SC (3, 3) 7,200.00 75.67 180.24 3,537.05 7.00 -0.52 25.06 0.00 6.67 1.24 3.00 25.06 3.53 0.41 MWD+IFR-AK-CAZ-SC (3,3) 7,300.00 75.67 180.24 3,561.80 7.16 -0.52 25.58 0.00 6.82 1.25 3.07 25.58 3.56 0.41 MWD+IFR-AK-CAZ-SC (3, 3) 7,400.00 75.67 180.24 3,586.55 7.32 -0.52 26.11 0.00 6.98 1.27 3.14 26.11 3.59 0.40 MWD+IFR-AK-CAZ-SC (3,3) 7,500.00 75.67 180.24 3,611.30 7.48 -0.52 26.63 0.00 7.14 1.29 3.21 26.63 3.63 0.40 MWD+IFR-AK-CAZ-SC (3,3) 7,600.00 75.67 180.24 3,636.04 7.64 -0.52 27.16 0.00 7.30 1.31 3.28 27.16 3.66 0.40 MWD+IFR-AK-CAZ-SC (3,3) 7,700.00 75.67 180.24 3,660.79 7.80 -0.52 27.69 0.00 7.46 1.32 3.35 27.69 3.69 0.40 MWD+IFR-AK-CAZ-SC (3,3) 7,800.00 75.67 180.24 3,685.54 7.96 -0.52 28.22 0.00 7.62 1.34 3.42 28.22 3.72 0.40 MWD+IFR-AK-CAZ-SC (3,3) 7,900.00 75.67 180.24 3,710.29 8.13 -0.52 28.75 0.00 7.78 1.36 3.49 28.75 3.75 0.40 MWD+IFR-AK-CAZ-SC (3,3) 8,000.00 75.67 180.24 3,735.03 8.29 -0.52 29.28 0.00 7.94 1.38 3.56 29.28 3.79 0.40 MWD+IFR-AK-CAZ-SC (3,3) 8,100.00 75.67 180.24 3,759.78 8.45 -0.52 29.81 0.00 8.10 1.40 3.64 29.81 3.82 0.40 MWD+IFR-AK-CAZ-SC (3,3) 8/9/2018 10:11:32AM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 28-315 Wellbore: Plan: 2S-315 Design: 2S-315 wp03 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2S-315 Rig: 39+120 @ 159.00usft (Doyon142) Rig: 39+120 @ 159.00usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination Azimuth Vertical Highsirle Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (') 0 (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) V), 8,200.00 75.67 180.24 3,784.53 8.62 -0.52 30.35 0.00 8.26 1.42 3.71 30.35 3.85 0.40 MWD+IFR-AK-CAZ-SC (3, 3) 8,300.00 75.67 180.24 3,809.28 8.78 -0.52 30.88 0.00 8.42 1.43 3.79 30.88 3.89 0.40 MWD+IFR-AK-CAZ-SC.(3,3) 8,400.00 75.67 180.24 3,834.02 8.95 -0.52 31.42 0.00 8.58 1.45 3.86 31.42 3.92 0.39 MWD+IFR-AK-CAZ-SC (3,3) 8,500.00 75.67 180.24 3,858.77 9.11 -0.52 31.95 0.00 8.75 1.47 3.94 31.95 3.96 0.39 MWD+IFR-AK-CAZ-SC (3, 3) 8,600.00 75.67 180.24 3,883.52 9.28 -0.52 32.49 0.00 8.91 1.49 4.02 32.49 3.99 0.39 MWD+IFR-AK-CAZ-SC (3,3) 8,700.00 75.67 180.24 3,908.27 9.45 -0.52 33.03 0.00 9.07 1.51 4.09 33.03 4.03 0.39 MWD+IFR-AK-CAZ-SC (3,3) 8,800.00 75.67 180.24 3,933.01 9.61 -0.52 33.57 0.00 9.24 1.53 4.17 33.57 4.06 0.39 MWD+IFR-AK-CAZ-SC (3,3) 8,900.00 75.67 180.24 3,957.76 9.78 -0.52 34.11 0.00 9.40 1.55 4.25 34.11 4.10 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,000.00 75.67 180.24 3,982.51 9.95 -0.52 34.65 0.00 9.56 1.57 4.33 34.65 4.13 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,100.00 75.67 180.24 4,007.26 10.12 -0.52 35.19 0.00 9.73 1.59 4.41 35.19 4.17 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,200.00 75.67 180.24 4,032.00 10.29 -0.52 35.74 0.00 9.89 1.61 4.49 35.74 4.21 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,300.00 75.67 180.24 4,056.75 10.45 -0.52 36.28 0.00 10.06 1.63 4.57 36.28 4.24 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,400.00 75.67 180.24 4,081.50 10.62 -0.52 36.82 0.00 10.22 1.65 4.66 36.82 4.28 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,500.00 75.67 180.24 4,106.25 10.79 -0.52 37.37 0.00 10.39 1.67 4.74 37.37 4.32 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,600.00 75.67 180.24 4,130.99 10.96 -0.52 37.91 0.00 10.55 1.69 4.82 37.91 4.36 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,700.00 75.67 180.24 4,155.74 11.13 -0.52 38.46 0.00 10.72 1.71 4.91 38.46 4.39 0.39 MWD+IFR-AK-CAZ-SC (3, 3) 9,800.00 75.67 180.24 4,180.49 11.30 -0.52 39.00 0.00 10.89 1.73 4.99 39.00 4.43 0.39 MWD+IFR-AK-CAZ-SC (3,3) 9,900.00 75.67 180.24 4,205.23 11.47 -0.52 39.55 0.00 11.05 1.76 5.08 39.55 4.47 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,000.00 75.67 180.24 4,229.98 11.64 -0.52 40.10 0.00 11.22 1.78 5.16 40.10 4.51 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,100.00 75.67 180.24 4,254.73 11.81 -0.52 40.65 0.00 11.38 1.80 5.25 40.65 4.55 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,200.00 75.67 180.24 4,279.48 11.98 -0.52 41.19 0.00 11.55 1.82 5.34 41.19 4.59 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,300.00 75.67 180.24 4,304.22 12.15 -0.52 41.74 0.00 11.72 1.84 5.43 41.74 4.63 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,400.00 75.67 180.24 4,328.97 12.32 -0.52 42.29 0.00 11.88 1.86 5.52 42.29 4.67 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,500.00 75.67 180.24 4,353.72 12.49 -0.52 42.84 0.00 12.05 1.89 5.61 42.84 4.71 0.39 MWD+IFR-AK-CAZ-SC (3, 3) 10,600.00 75.67 180.24 4,378.47 12.67 -0.52 43.39 0.00 12.22 1.91 5.70 43.39 4.75 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,700.00 75.67 180.24 4,403.21 12.84 -0.52 43.94 0.00 12.38 1.93 5.79 43.94 4.79 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,800.00 75.67 180.24 4,427.96 13.01 -0.52 44.49 0.00 12.55 1.96 5.88 44.49 4.83 0.39 MWD+IFR-AK-CAZ-SC (3,3) 10,900.00 75.67 180.24 4,452.71 13.18 -0.52 45.04 0.00 12.72 1.98 5.97 45.04 4.87 0.39 MWD+IFR-AK-CAZ-SC (3,3) 11,000.00 75.67 180.24 4,477.46 13.35 -0.52 45.59 0.00 12.89 2.00 6.07 45.59 4.91 0.39 MWD+IFR-AK-CAZ-SC (3,3) 11,100.00 75.67 180.24 4,502.20 13.52 -0.52 46.14 0.00 13.05 2.02 6.16 46.14 4.95 0.39 MWD+IFR-AK-CAZ-SC (3,3) 11,200.00 75.67 180.24 4,526.95 13.70 -0.52 46.69 0.00 13.22 2.05 6.26 46.69 4.99 0.39 MWD+IFR-AK-CAZ-SC (3,3) 11,300.00 75.67 180.24 4,551.70 13.87 -0.52 47.24 0.00 13.39 2.07 6.35 47.24 5.03 0.39 MWD+IFR-AK-CAZ-SC (3,3) 11,400.00 75.67 180.24 4,576.45 14.04 -0.52 47.79 0.00 13.56 2.10 6.45 47.80 5.07 0.39 MWD+IFR-AK-CAZ-SC (3,3) 11,500.00 75.67 180.24 4,601.19 14.21 -0.52 48.35 0.00 13.72 2.12 6.54 48.35 5.11 0.39 MWD+IFR-AK-CAZ-SC (3, 3) 11,600.00 75.67 180.24 4,625.94 14.39 -0.52 48.90 0.00 13.89 2.14 6.64 48.90 5.15 0.39 MWD+IFR-AK-CAZ-SC (3, 3) 11,700.00 75.67 180.24 4,650.69 14.56 -0.52 49.45 0.00 14.06 2.17 6.74 49.45 5.19 0.39 MWD+IFR-AK-CAZ-SC (3,3) 11,800.00 75.67 180.24 4,675.44 14.73 -0.52 50.00 0.00 14.23 2.19 6.84 50.01 5.24 0.39 MWD+IFR-AK-CAZ-SC (3,3) 11,900.00 75.67 180.24 4,700.18 14.90 -0.52 50.56 0.00 14.40 2.22 6.94 50.56 5.28 0.39 MWD+IFR-AK-CAZ-SC (3.3) 12,000.00 75.67 180.24 4,724.93 15.08 -0.52 51.11 0.00 14.57 2.24 7.04 51.11 5.32 0.38 MWD+IFR-AK-CAZ-SC (3,3) 12,100.00 75.67 180.24 4,749.68 15.25 -0.52 51.66 0.00 14.73 2.27 7.14 51.67 5.36 0.38 MWD+IFR-AK-CAZ-SC (3, 3) 12,200.00 75.67 180.24 4,774.43 15.42 -0.52 52.22 0.00 14.90 2.29 7.24 52.22 5.40 0.38 MWD+IFR-AK-CAZ-SC (3,3) 12,300.00 75.67 180.24 4,799.17 15.60 -0.52 52.77 0.00 15.07 2.32 7.34 52.77 5.45 0.38 MWD+IFR-AK-CAZ-SC (3,3) 12,400.00 75.67 180.24 4,823.92 15.77 -0.52 53.33 0.00 15.24 2.34 7.44 53.33 5.49 0.38 MWD+IFR-AK-CAZ-SC (3,3) 12,500.00 75.67 180.24 4,848.67 15.94 -0.52 53.88 0.00. 15.41 2.37 7.55 53.88 5.53 0.38 MWD+IFR-AK-CAZ-SC (3,3) 12,600.00 75.67 180.24 4,873.42 16.12 -0.52 54.44 0.00 15.58 2.39 7.65 54.44 5.57 0.38 MWD+IFR-AK-CAZ-SC (3,3) 12,700.00 75.67 180.24 4,898.16 16.29 -0.52 54.99 0.00 15.75 2.42 7.75 54.99 5.62 0.38 MWD+IFR-AK-CAZ-SC (3, 3) 12,800.00 75.67 180.24 4,922.91 16.46 -0.52 55.55 0.00 15.91 2.45 7.86 55.55 5.66 0.38 MWD+IFR-AK-CAZ-SC (3,3) 12,824.14 75.67 180.24 4,928.88 16.50 -0.52 55.68 0.00 15.95 2.45 7.88 55.68 5.67 0.38 MWD+IFR-AK-CAZ-SC (3,3) 12,900.00 73.25 179.11 4,949.21 16.64 -0.19 55.86 0.15 16.08 2.47 7.97 55.87 5.70 0.39 MWD+IFR-AK-CAZ-SC (3,3) 13,000.00 70.07 177.57 4,980.67 16.80 0.26 55.77 0.35 16.24 2.51 8.09 55.83 5.75 0.39 MWD+IFR-AK-CAZ-SC (3,3) 13,100.00 66.91 175.97 5,017.33 16.95 0.70 55.64 0.57 16.40 2.56 8.21 55.80 5.80 0.39 MWD+IFR-AK-CAZ-SC (3,3) 13,200.00 63.76 174.29 5,059.07 17.11 1.14 55.47 0.80 16.56 2.62 8.35 55.78 5.86 0.40 MWD+IFR-AK-CAZ-SC (3,3) 13,300.00 60.63 172.51 5,105.72 17.31 1.58 55.25 1.05 16.70 2.69 8.50 55.77 5.92 0.40 MWD+IFR-AK-CAZ-SC (3,3) 13,400.00 57.52 170.63 5,157.11 17.58 2.01 54.96 1.31 16.84 2.77 8.65 55.76 5.98 0.41 MWD+IFR-AK-CAZ-SC (3,3) 81912018 10:11:32AM Page 5 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-315 Wellbore: Plan: 2S-315 Design: 2S-315 wp03 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2S-315 Rig: 39+120 @ 159.00usft (Doyon142) Rig: 39+120 @ 159.00usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination Azimuth Vertical Highside Lateral Casing Vertical Magnitude Semi -major Semi -minor Diameter Depth (usft) Name (in) Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Too] (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 13,500.00 54.45 168.61 5,213.04 17.99 2.43 54.60 1.60 16.97 2.86 8.81 55.76 6.05 0.41 MWD+IFR-AK-CAZ-SC (3,3) 13,600.00 51.41 166.43 5,273.32 18.57 2.83 54.14 1.91 17.09 2.97 8.97 55.77 6.13 0.41 MWD+1FR-AK-CAZ-SC (3, 3) 13,700.00 48.42 164.05 5,337.71 19.38 3.20 53.55 2.25 17.21 3.09 9.14 55.78 6.21 0.40 MWD+1FR-AK-CAZ-SC (3,3) 13,800.00 45.48 161.45 5,405.97 20.49 3.55 52.81 2.63 17.31 3.22 9.32 55.79 6.29 0.40 MWD+IFR-AK-CAZ-SC (3, 3) 13,816.48 45.00 161.00 5,417.58 20.70 3.60 52.67 2.70 17.33 3.24 9.34 55.80 6.30 0.40 MWD+IFR-AK-CAZ-SC (3,3) 13,900.00 45.00 161.00 5,476.63 20.79 3.60 52.85 2.70 17.41 3.36 9.49 55.96 6.37 0.34 MWD+IFR-AK-CAZ-SC (3,3) 14,000.00 45.00 161.00 5,547.34 20.90 3.60 53.26 2.70 17.51 3.50 9.67 56.35 6.45 0.21 MWD+IFR-AK-CAZ-SC (3,3) 14,016.48 45.00 161.00 5,559.00 20.92 3.60 53.32 2.70 17.53 3.53 9.70 56.42 6.46 0.19 MWD+IFR-AK-CAZ-SC (3,3) 14,100.00 45.00 161.00 5,618.05 21.01 3.60 53.66 2.70 17.61 3.65 9.85 56.74 6.53 0.08 MWD+IFR-AK-CAZ-SC (3,3) 14,200.00 45.00 161.00 5,688.77 21.12 3.60 54.07 2.70 17.71 3.79 10.04 57.13 6.61 179.95 MWD+IFR-AK-CAZ-SC (3, 3) 14,300.00 45.00 161.00 5,759.48 21.23 3.60 54.48 2.70 17.81 3.94 10.22 57.52 6.69 179.83 MWD+IFR-AK-CAZ-SC (3,3) 14,334.68 45.00 161.00 5,784.00 21.27 3.60 54.63 2.70 17.84 3.99 10.29 57.66 6.72 179.78 MWD+IFR-AK-CAZ-SC (3,3) 14,400.00 45.00 161.00 5,830.19 21.34 3.60 54.90 2.70 17.91 4.09 10.41 57.91 6.77 179.70 MWD+IFR-AK-CAZ-SC (3, 3) 14,500.00 45.00 161.00 5,900.90 21.45 3.60 55.31 2.70 18.00 4.24 10.60 58.30 6.85 179.58 MWD+IFR-AK-CAZ-SC (3,3) 14,600.00 45.00 161.00 5,971.61 21.56 3.60 55.72 2.70 18.10 4.39 10.80 58.70 6.94 179.46 MWD+IFR-AK-CAZ-SC(3,3) 14,634.68 . 45.00 161.00 5,996.13 . 21.60 3.60 55.86 2.70 18.14 4.44 10.87 58.83 6.97 179.42 MWD+IFR-AK-CAZ-SC (3,3) Design Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape C) (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2S-315 T01 TC 032818 0.00 0.00 5,559.00 -11,710.94 116.28 plan hits target center Circle (radius 100.00) Casing points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 119.00 119.00 16" x 42" 16.000 42.000 3,651.94 2,659.00 10 3/4" x 13-1/2 10.750 13.500 14,634.68 5,996.13 7-5/8" x 9-7/8" 7.625 9.875 8/9/2018 10:11:32AM Page 6 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-315 Wellbore: Plan: 2S-315 Design: 2S-315 wp03 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2S-315 Rig: 39+120 @ 159.00usft (Doyon142) Rig: 39+120 @ 159.00usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMP2 Formations Measured Vertical Vertical Dip Depth Depth Depth Dip Direction (usft) (usft) Name Lithology (1) (�) 1,169.33 1,162.00 Ugnu C 0.00 1,425.55 1,406.00 Ugnu B 0.00 1,454.45 1,433.00 Base Perm 0.00 1,518.83 1,493.00 Ugnu A 0.00 1,895.83 1,830.00 West Sak Top 0.00 2,863.39 2,445.00 West Sak Base 0.00 3,655.98 2,660.00 C-90 0.00 4,456.06 2,858.00 C-80 0.00 4,698.51 2,918.00 Campanian SS 0.00 10,537.50 4,363.00 C-50 0.00 11,648.73 4,638.00 C-40 0.00 12,307.38 4,801.00 C-37 (Top Iceberg) 0.00 13,795.76 5,403.00 T-6 (Base Iceberg) 0.00 14,016.48 5,559.00 Top Cairn 0.00 14,334.68 5,784.00 Base Cairn 0.00 14,480.35 5,887.00 C-35 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 KOP: Start 1°/100' DLS, 180.24° TF, for 200' 600.00 599.96 -3.49 -0.01 Start 2.25"/100' DLS, 0° TF, for 855.52' 1,455.52 1,434.00 -175.07 -0.73 Hold for 107.29' 1,562.82 1,534.00 -213.95 -0.90 Start 3.5°/100' DLS, 0° TF, for 1554.93' 3,117.75 2,526.80 -1,334.55 -5.63 Hold for 9706.39' 12,824.14 4,928.88 -10,738.93 -45.52 Start 3.5°/100' DLS, -155.86° TF, for 992.35' 13,816.48 5,417.58 -11,577.22 70.24 Hold for 200' 14,016.48 5,559.00 -11,710.94 116.28 Adjust TF to 0', for 318.2' 14,334.68 5,784.00 -11,923.68 189.53 Adjust TF to 0°, for 300' 14,634.68 5,996.13 -12,124.26 258.60 TD: 14634.68' MD, 5996.13' TVD Checked By: Approved By: Date: 8/9/2018 10:11:32AM Page 7 COMPASS 5000.14 Build 85 Pool Report I 0 10:27, August 09 2018 1 WELLBORE TARGET DETAILS (MAP CO ORDINATES) 2S-315 wp03 Name ND Shape 25-315 TOt TO 032818 PP 5559.06 Circle (Radius: 1320.00) Quarter Mile View 3500 0 0 0 10-3500 0 Z-7000 M, -10500 AC Wells Only -14000- -14000 -10500 -7000 -3500 0 st(-)/East(+) (3 3500 7000 10"31, August 09 2018 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) 2S-315 wp03 Name TVD Shape 25-315 T01 TC 032818 PP 5559.00 Circe (Radius: 1320.00) Quarter Mile View 1 All Wells )S.74 �1 2S 11 2S -09q i 1 ?<, ' 2S.04 '2S'07p� o ® 2S 05 a� 3500ISO _ _ - _ S -o9 O o y _ry0 oo 1 O OO yMy�o O 2S-02 ?�?r 0 _ - � 13Q�1 2" � 5-04 P? CD o O � is 02L.308 O uMi, �Y 0-3500 r ` a 2S-,,,Pa .Sh rk 00th i- ,p `�,° 2S-12 O Z 7000 o Aoo H� 4-1 2$-08 2S 2N 32�y 010 `rya° 1�p031 2K 2K-30 -10500 y5p0 _ ZN°, p0 2S.03 32 S `amp�Pg1l`N Pp31 2S.0 5yp0 5300 2� 32a 560°0 55 510 rg1 g 5400 -14000 5300 4FA i -14000 -10500 -7000 -3500 0 3500 7000 10500 14000 1 3500 _o 6PB1 o Cn 2L.314 24' O �0 �o�2Q1 0-35002" + >✓ �� n p 6 h� z-7000 �_��1°�� � ZN.32 ZN -10500 2L 326 5300 -14000 � f- �y � o WELLBORE TARGET DETAILS (MAP COORDINATES) Name ND Shape 2S-315 T01 TC 032818 PP 5559.00 Circle (Radius: 1320.00) �1� `�� )Soja �gl %AK. 25-05 o° �56p0 5y0° ,y2�3�5 15400 5300 -14000 -10500 -7000 -3500 0 3500 7000 10500 14000 NS -315=03 Surface Location I M CW Coordinate Converter From: To: ---- Datum: Nppgg Region: alaska Datum Npp7 Region: P_Ia_.ka r Latitude/Longitude Decimal Degrees i t Latitude/Longitude I Decimal Degrees r UTM Zone:f— I- South C UTM Zone. 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Datum: NAD� Region:alaska ,_ LatitudelLongitudeDecimal Degrees UTM Zone: South is State Plane Zone: 4 Units: us ft 1 f" z Starting Coordinates:-- --- j X: 1621217.24 t E Y: 5917587.36 i To: Datum: Z 7� Region: alaska i i" Latitude/Longitude Decimal Degrees f UTM Zone: True South " State Plane Zone: F4—_--] Units: us ft % Legal Description (NAD27 only) Legal Description Township: Fol N Range: 008 E Meridian: U Section:25 FNL � 14651.1290 FEL 1392.4820 L- _------------ Qu------ Quit 1 Help Appendix ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 30°of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges 6 ConocoPhilli •_•:_•:s_s:sse! ps ■ Tier 1 (Standard) : ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations ::•s::::�::: : : rrrr:rr:rr u - l �� Conoco' hillips - m+r:r:r: .-www p s 2S-315 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed - control drill, reduce pump Lost circulation Moderate . rates, reduce drilling fluid temperatures, Additions of ScreenKleen. Anti -collision Low Run Gyro as needed for magnetic Hole cleaning Low interference. Gravel / Sand Sloughing Low Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on Stuck pipe Low connections. Hole Swabbing / Tight Moderate Circulate hole clean prior to trip. Proper Hole on Trips hole fill (use of trip sheets), Pumping out of hole as needed. Lost circulation Low - Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Unsuccessful cement job Moderate ✓ Use lower density cement slurry. Adjust the mud properties prior pump cement. Use proper pump rate. Squeeze job or top job to remediate if needed. 8-1/2"x9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Mit! atlon Strategy High ECD and swabbing Low Condition mud prior to trips. Monitor ECD's with PWD tool while drilling. Lost circulation Moderate . Use PWD and T&D to monitor hole cleaning. Reduced pump rates, adjust mud rheology, add LCM. Hole cleaning Low Use PWD and T&D to monitor hole cleaning. Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning, stabilized BHA, proper mud weight, PWD to monitor ECD. L 'A31 BIoZ-jsnbnV 31V0 ON 13NlV *A9NMV2i0 oLlx,ll '.ltl NR103 'oul 'ei sely o—,os =.t 3ivos JNIMV?JO 1nwvV Szso .3ILL sdill!4d0:)0u0) .o -,Sl x.0 -J11 x.9—,Lt 13 00l® • 3snoH -n3M du (S3HOV £S'8) 0NIOVdS -n3M ,0-,0£ NVId iMd 31lS 11180 jod nu a ® 60 t t l l 0 D OVd 30 3003 GVd 30 3003 OVd 30 301 OVd 30 301 63 AFIS 831NU1 SONIM ONnIVA31A .Zt Ste/7 Otis II!ja �aO0N 3n2L OVd TWO Attachment 6 BOP Configuration The following ram configuration will be utilized for the Cairn well. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. Davies, Stephen F (DOA) From: Lehman, Nick R <Nick. R. Lehman @conocophilli ps.com> Sent: Tuesday, September 18, 2018 11:11 AM To: Davies, Stephen F (DOA) Cc: Perfetta, Patrick J; Donat, Aaron Subject: RE: [EXTERNAL]KRU 2S-315 (PTD 218-110) - Question Attachments: 2S-315 Surface Casing Spider Plot.pdf Good morning Steve, Thanks for your email. ConocoPhillips believes 2S-315 to be qualified as an exploration well for the following reasons: 1. 2S-315 will be drilled outside of the existing Tarn Field Participating Area (PA). 2. 2S-315 will be more than 1 spacing unit away from any well that has drilled through / tested the Cairn interval. 3. The targeted Cairn interval is included in the Tarn Pool; however, aside from the short -tern flow test on 2N-310, ConocoPhillips does not have economic production from this interval yet, hence why we are requesting exploratory status. With respect to your second question, is it possible for ConocoPhillips to obtain a waiver from 20.AAC.25.033.f.2 / 20.AAC.25.061.a that requires conducting a seismic analysis for an exploratory well and, if so, what additional information would you require? 1. The drilling risk in the overburden section on 2S-315 is low — we have drilled through it successfully many times in surrounding wells at Tarn and with the 2S development drilling that targeted the deeper Kuparuk reservoir. 2. 2S-315 will be drilled from the existing gravel pad on Drill Site 2S with surrounding offset wells showing no signs of a shallow gas hazard. Attached is a spider plot of 2S-315 showing surface sections from surrounding 2S -wells. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehrnan@ConocoPhillips.corn From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Monday, September 17, 2018 1:26 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: [EXTERNAL]KRU 2S-315 (PTD 218-110) - Question Nick, ConocoPhillips's application for KRU 2S-315requests the AOGCC classify this well as an exploratory well. Please provide justification as to why this well, to be drilled within the Kuparuk River Unit and surrounded on all sides by five older exploratory wells that have drilled and logged the same geologic interval, should be classified as exploratory. ConocoPhillips did not conduct a seismic analysis for KRU 2S-315 as required by 20 AAC 25.061 for exploratory wells. Please provide such an analysis or an equivalent analysis that demonstrates the potential for encountering shallow gas or other drilling hazards. Thanks for your help, Steve Davies Senior Petroleum Geologist 10:11, September 18 2018 2S-315 wp03 Quarter Mile View WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name TVDShape 2S-315 T01 TC 032818 PP 5559.00 Circle (Radius: 1320.00) Surface Csg 2659.01 Circle (Radius: 5280.00) 62 63 4500- 63 63 3000 / 2s. -1500 12PB1 2S-01- 2S.12 2S 06 2S \ 63 08Fg1 U) y O 0 66 2S. '34 63 2S_10 25-03 O 2S -04P&7 LO 2S_ 13 2S, "? ` 2S, 2S -09A c 1500 _ 4 S'34173 2 i 2$Oj. 2 N to O 55 ?S oq p3 z 3000 75-3�y.�p O 6 '67- Shark Tooth �45001 #, 63 � -6000 , �, - 6$ 64 -7500 - - 63 -7500 -6000 -4500 -3000 -1500 0 1500 3000 4500 6000 7500 9000 10500 Kick Tolerance Calculations guy schwartz 10/9/2018 input in yellow areas only 2S-315 PTD 218-110 MW (ppg) 9.5 ppg LOT/FIT (ppg) 12.5 TVD Casing Shoe (ft) 2670 ft TVD If a formation deeper than the casing shoe is known to be weaker than the casing shoe (have a lower fracture gradient/LOT) then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 0.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 5996 ft TVD Gas Gradient (psi/ft) 0.1 psi/ft Change only if gas gradient is known to be different Hole Size (in) 9.875 inches Drill Pipe OD (in) 4.5 inches BHA OD (in) 6.75 inches Lenth of BHA (ft) 250 ft If the BHA is longer than the open hole, the kick will come to surface very quickly due to the smaller annular capacity 0.0751 bbl/ft Annular Capacity between OH and DP 0.0505 bbl/ft Annular Capacity between OH and BHA 416.52 psi Maximum Allowable Surface Pressure 155.896 psi Underbalance due to Kick Intensity 260.624 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 661.5 feet Volume of Gas Kick 33.4 bbl CASE 1 Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 49.7 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx 27.6 bbl CASE 2 depth Conversion KICK TOLERANCE: 27.6 bbl Compare CASE 1 and CASE 2 volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume Davies, Stephen F (DOA) From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Wednesday, September 19, 2018 1:51 PM To: Davies, Stephen F (DOA) Cc: Perfetta, Patrick J; Donat, Aaron Subject: RE: [EXTERNAL]KRU 2S-315 (PTD 218-110) - Question Steve, Please see follow-up answers to your questions below: • Was a 3D seismic dataset used to map the area surrounding the planned well? If not, what are the distances from the anticipated pay interval in KRU 2S-315 to the nearest 2D seismic lines? o Yes, full 3D seismic coverage is present over the prospect area. These data were mapped, and utilized in the planning of the 2S-315 well. • Did the project geoscientist/geophysicist observe any indications of shallow gas in the seismic or velocity datasets? If so, please describe them including the indicator type, depth range, areal extent, and proximity to the planned well. o Two sources of gas in the overburden section are as follows: Thin sands near the C-80 marker "Campanian" sometimes contain gas. These are thin lag sands that are not readily identifiable seismically. They may occur near a subsea depth of 2,760' in the 2S-315 well. They have been penetrated in surrounding wells drilled from 2N, 2L, and 2S pads. Turbidite channel sands of limited lateral extent, readily identifiable on 3D seismic, are present within the C-37 "Iceberg" interval. These sands are known to contain low saturation gas from mudlogs in wells that penetrate this interval in the surrounding area (these include development wells drilled from 2L, 2N, and 2S pads). The Iceberg will be present in the 25-315 well at an estimated depth range of 4,642-5,244' SSTVD. The nearest Iceberg channel, identified from 3D seismic, is located approximately 1,300' from the planned 2S-315 trajectory. The Iceberg channel sands are identified on seismic data via negative amplitude response on the far - stack volumes, predominantly driven by lithology. The Iceberg is correlative to the uppermost interval of the Tarn oil pool, and as such will be covered with cement. Were hydrates encountered beneath the permafrost in any of the wells drilled from 2S -Pad? o We did not see any evidence of gas hydrates or shallow gas while drilling wells on 2S -pad. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehmon@ConocoPhillips.com From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Tuesday, September 18, 2018 5:03 PM To: Lehman, Nick R <Nick.R.Lehman @conocophillips.com> Subject: RE: [EXTERNAL]KRU 2S-315 (PTD 218-110) - Question Nick, I will consider your email, below, as a request for waiver from the requirements of 20.AAC.25.033(f)(2) / 20.AAC.25.061(a). Additional questions: • Was a 3D seismic dataset used to map the area surrounding the planned well? If not, what are the distances from the anticipated pay interval in KRU 2S-315 to the nearest 2D seismic lines? • Did the project geoscientist/geophysicist observe any indications of shallow gas in the seismic or velocity datasets? If so, please describe them including the indicator type, depth range, areal extent, and proximity to the planned well. • Were hydrates encountered beneath the permafrost in any of the wells drilled from 2S -Pad? Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Tuesday, September 18, 2018 11:11 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Perfetta, Patrick J <Patrick.J.Perfetta@conocophillips.com>; Donat, Aaron <Aaron.Donat@conocophillips.com> Subject: RE: [EXTERNAL]KRU 2S-315 (PTD 218-110) - Question Good morning Steve, Thanks for your email. ConocoPhillips believes 2S-315 to be qualified as an exploration well for the following reasons: 1. 2S-315 will be drilled outside of the existing Tarn Field Participating Area (PA). 2. 2S-315 will be more than 1 spacing unit away from any well that has drilled through / tested the Cairn interval. 3. The targeted Cairn interval is included in the Tarn Pool; however, aside from the short -tern flow test on 2N-310, ConocoPhillips does not have economic production from this interval yet, hence why we are requesting exploratory status. With respect to your second question, is it possible for ConocoPhillips to obtain a waiver from 20.AAC.25.033.f.2 / 20.AAC.25.061.a that requires conducting a seismic analysis for an exploratory well and, if so, what additional information would you require? 1. The drilling risk in the overburden section on 2S-315 is low — we have drilled through it successfully many times in surrounding wells at Tarn and with the 2S development drilling that targeted the deeper Kuparuk reservoir. 2. 2S-315 will be drilled from the existing gravel pad on Drill Site 2S with surrounding offset wells showing no signs of a shallow gas hazard. Attached is a spider plot of 2S-315 showing surface sections from surrounding 2S -wells. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehmcin@ConocoPhillips.com From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Monday, September 17, 2018 1:26 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: [EXTERNAL]KRU 2S-315 (PTD 218-110) - Question Nick, ConocoPhillips's application for KRU 2S-315requests the AOGCC classify this well as an exploratory well. Please provide justification as to why this well, to be drilled within the Kuparuk River Unit and surrounded on all sides by five older exploratory wells that have drilled and logged the same geologic interval, should be classified as exploratory. ConocoPhillips did not conduct a seismic analysis for KRU 2S-315 as required by 20 AAC 25.061 for exploratory wells. Please provide such an analysis or an equivalent analysis that demonstrates the potential for encountering shallow gas or other drilling hazards. Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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. Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, September 17, 2018 1:26 PM To: 'Lehman, Nick R' Subject: KRU 2S-315 (PTD 218-110) - Question Nick, ConocoPhillips's application for KRU 2S-315requests the AOGCC classify this well as an exploratory well. Please provide justification as to why this well, to be drilled within the Kuparuk River Unit and surrounded on all sides by five older exploratory wells that have drilled and logged the same geologic interval, should be classified as exploratory. ConocoPhillips did not conduct a seismic analysis for KRU 2S-315 as required by 20 AAC 25.061 for exploratory wells. Please provide such an analysis or an equivalent analysis that demonstrates the potential for encountering shallow gas or other drilling hazards. Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. Remark: AOGCC PTD No. 218-110 Coordinate Check 6 September 2018 INPUT OUTPUT State Plane, NAD27 Geographic, NAD27 5004 -Alaska 4, U.S. Feet KRU 2S-315 1/1 NorthingN: 5929961.45 Latitude: 70 13 11.31421 Easting/X: 480956.55 Longitude: 150 09 13.06981 Convergence: -0 08 40.43763 Scale Factor: 0.999900412 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: �� 1%.6- PTD: 2_1 $ 11C) Development _ Service /Exploratory _ Stratigraphic Test Non -Conventional FIELD:� l i/��_ POOL: 7 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits 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 acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of _ well logs to be run. In addition to the well logging program proposed by n the attached application, the followin944wWare also required for this well: / Well Logging Lu A -'4y E -1c j Requirements /� T k&7*7 _6 t' r f� c--. 1 �r 2 c 7LC3 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. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER - 490000 _ _ _-_ Well Name: KUPARUK RIV_UNIT 2S-315 ._ _Program EXP _ _ Well bore seg ❑ PTD#: 2181100 Company CONOCOPHILLIPS_ALASKA. INC Initial Class/Type EXP/PEND GeoArea 890 Unit 11160 On/Off Shore On _ Annular Disposal ❑ Administration 17 Nonconven. gasconformsto AS31.05.030(j.1_.A),(j.2.A-D) - - - NA - - - - - - - - - - - 1 Permit fee attached NA 2 Lease number appropriate_ - - Yes Surface Location lies_wit_hin ADL0025603, ADL0025608 3 Unique well name and number Yes _ _ _ _ _ _ 4 Well located in_a_defined _pool. No . . - - - - 5 Well located proper distance- from drilling unit -boundary - - - - Yes . - - - - - - - - - - - - - - - - I - - - - - - -- - --- :6 Well located proper distance, from other wells_ - - - - - - - - - - - - - - - - Yes - - - - Closest well is 1_.2 miles -away (Sharktooth 1). - - - j7 Sufficient acreage_ available in drilling unit_ - - Yes . !8 -If-deviated, is wellbore plat included - - - Yes 9 Operator only affected party_ - - - Yes _ - - - - - - 10 Operator has -appropriate bond in force - - - - - Yes - - - - - - - - _ . Appr Date 11 Permitcan be issued without co__nservation order- - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 12 Permit. can be issued without administrative -approval .. - . Yes - - - - . . SFD 9/14/2018 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)_(For NA_ _- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - 15 _All wells within 1/4 mile area of review identified (For service well only) - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - -- - 16 Pre -produced injector; duration -of pre production Less than 3 months_ (For service well only) NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - .. - - 18 _Coonductor string -provided - - - - - - - - - - - - - - - - Yes - - - - - - 16",_62.6-ppf - - - - - - - - - - - - - - - - Engineering 19 Surface casing_ protects all -known_ USDWs - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - 20 CMT vol adequate. to circulate -on conductor_& su_rf_csg - - - - Yes . - Assume 2501% excess- . 21 CMT vol adequate -to tie -in -long string to -surf csg_ - - - - . - - - - - - - - - - - - - - - - - - - - - 22 CMT_will cover -all known -productive horizons- - - - - - - - - - - - - - - - - - - - Yes - - - - - - Assume no hydrocarbon production zones between_ top of -Cairn and. 2659' TVD _(surface -casing shoe)- - 123 Casing designs adequate for CJ, B&- permafrost _________________ Yes _____-_ -------- - - -- -- -------_-__-___--- 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - Yes - - - - Rig Doyon -142 will come from an activie drilling program - 25 If a- re -drill, has_ a 1.07403 for abandonment been approved - - - - - NA_ - - - - - New grassroots -we -11 - - - - - - - - - - - - -- - - - - - - - - - 26 Adequate wellbore separation_proposed- - - - - - - - - - - - - - - Yes - - - - - - - Passes_ all separation criteria_ - - - _ . . 27 If_diverter required, does it meet regulations- - - - - - - - - - - - - - - Yes - - - - Will -drill surface_ hole- on diverterfunction_ test required_ - Appr Date 28 Drilling fluid_ program schematic.& equip _list_adequat_e_ - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ - - _ - . _ - - - MGR 9/19/2018 29 BOPEs,-dothey-meet regulation - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE-press rating appropriate; test to -(put psig in comments)_ - - - - - - - - - - Yes - - - - - - - BOPE test -to 3500_psi_on 5000_ psi rated BOPE 31 Choke -manifold complies w/API_RP-53(May 84)- - - - - - - - - - - - - - - - - Yes- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur withoutoperationshutdown- -- - -- - - - - - - - - - - - - - - Yes- - - - - - - - - - - - - - - - - - - - - 33 Is presence_ ofH2Sgas probable - - - -- -- -- - - - - - - - - - No_ - - - - - - - - - - - - - - - - - - - - - - - 34 Mechanical -condition of wells within AOR verified (For service well only) - - - - NA_ - - - - - - - "Exploration" well. 35 Permit can be issued w/o hydrogen- sulfide measures- - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Five exploratory wells surround this well; none- reported H2S while drilling -the same -geologic interval. - - - - Geology i 36 Data_p_resented on potential overpressure zones - - - - - - - - - - - - - - - - - - - InCmpt - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 37 Seismic -analysis- of shallow gas_zones_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - InCmpt - - - - - 9/17: Request -seismic -or equivalent -analysis from Operator. 38 Seabed condition survey -(if off --shore) - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 39 Contact name/phone for weekly_ progress reports_ [exploratory only] - - - Yes Nick Lehman 907-263-4951- - - - - - - - - - - - - - - - - - - - . _ .. - . Geologic Engineering Public Exploratory (delineation) well lying in the SW KRU. Target is the Cairn interval (within the Tarn Oil Pool) at a location that lies Date: Date Date Commissioner: f � �/ mission mi r outside of, and 3,700' east of, the eastern boundary of the Tarn Oil Pool as defined in CO 430A.This well lies between --and within ( j 1.2 and 4 miles from --six existing exploratory wells: Tarn 4, Bermuda 1, Sharktooth 1, KRU 21 10-8/1, West Sak 13, and West 13 I`) �i tfj I'ZIllc Sak20. Well Summary for 2S-315 2S-315 – Cairn Interval Appraisal Well API # 50-103-20776-00-00 Drilling Rig: Doyon 142 Network# 10411837 November 2018 Wellsite Geologist: Barry Wright, Waters Petroleum Advisors Wellsite Geologist: Jeff McBeth, Waters Petroleum Advisors Well Objectives and Drilling Operations Plan: Geological Objective (reproduced from the 2S-315 Geological Prognosis): The 2S-315 is a planned exploration slant well to be drilled by ConocoPhillips from a surface location on 2S Pad in the Kuparuk River Unit during the 2018/2019 winter drilling season. 2S-315 will test the Cairn Interval. The well design will address the main geologic objectives of the well: Determine reservoir presence, quantity and quality in the Brookian section Determine hydrocarbon phase and possible fluid contacts Expedite development via ability to re-enter and drill development horizontal well The 2S-315 slant well will be drilled to an estimated total depth of 14,635’ md (5,837’ sstvd). This TD will provide enough rat hole for complete coverage of the Cairn sands by all logging tools. LWD logs will be acquired and, in the success case, the wellbore will be set up for re-entry to drill a future development horizontal. The Cairn Prospect comprises channel-levee to amalgamated sheet sands with a large lateral extent. Hydrocarbon indicators exist throughout the interval in offset wells. Figure 1: Generalized stratigraphic setting of Cairn Interval. Drilling Summary (reproduced from the 2S-315 Drilling and Completion Program): This well is a grassroots exploration producer targeting the Cairn sand interval. Doyon 142 will drill a 13-1/2” surface hole and case with 10-3/4”, 45.5#, L-80, Hydril 563 casing. Next, an 8-1/2” 2S-315 x 9-7/8” production hole will be drilled through the Cairn sand interval and 7-5/8”, 29.7#, L-80, TXPM casing will be run to TD. Finally, the production casing will be cemented to cover 250’ TVD above the top of the C-37. The directional program will follow the Schlumberger 2S-315wp3 well plan. Completion Summary: (reproduced from the 2S-315 Drilling and Completion Program): The completion consists of 3-½”, 9.3#, EUE tubing with a casing scraper/magnet combo, a downhole packer, a nipple profile, a dual-flapper valve, and an upper GLM for SOV installation. The dual-flapper valve will allow for reverse circulation only once in hole and will minimize post-rig operations. This completion will allow for production from the Cairn interval. Figure 2: Location of 2S-315 Drilling Operations Summary: TABLE 1: DAILY DRILLING REPORT Date 24:00 Depth (ft) Daily Progress (ft) Operation 11/15/2018 119 119 Skidded floor to moving position. Moved pipe shed and rockwasher to 3G pad. Pulled sub off 3S-612. Transported all modules to CPF 2. Discovered failed axle bearing on pump module. Transported all modules except pump module to 2S pad. Spotted and set sub over 2S- 315. Skidded rig floor to drilling position. Spotted remaining modules. Hooked up all utility lines. Rigged up pipe skate. Completed rig acceptance check list. Nippled up diverter system. Accepted rig at 23:00 hrs 11/15/18. 11/16/2018 303 184 Nippled up diverter. Cut drilling line. Serviced rig. Mobilized BHA to rig floor. Performed diverter test. Made up BHA to 99' MD. Tested lines to 3,500 psi. Cleaned out conductor to 119' MD. Drilled from 119' MD to 303' MD. Pulled out of hole and picked up remaining BHA to 303' MD. Gas alarms malfunctioning. Pulled out of hole to 93' MD. Troubleshot gas alarms. Ran in hole with BHA to 303' MD and tested alarm system. Serviced rig. 11/17/2018 2,465 2,281 Drilled 13 1/2" surface hole section from 303' MD to 2,465' MD. 11/18/2018 3,578 1,113 Drilled 13 1/2" surface hole section from 2,465' MD to TD at 3,578' MD. Circulated bottoms up while backreaming out of hole from 3,578' MD to 3,492' MD. Observed well for flow. Backreamed out of hole Date 24:00 Depth (ft) Daily Progress (ft) Operation from 3,492' MD to 1,697' MD. Backreamed out of hole from 1,697' MD to 1,507' MD while circulating 1 bottoms up per stand. Pulled out of hole on elevators from 1,507' MD to 656' MD. 11/19/2018 3,578 0 Laid down BHA. Cleaned and cleared rig floor. Rigged up to run 10 3/4" casing. Serviced rig. Made up and checked float track. Ran in hole picking up casing to 1,859' MD. Circulated bottoms up. Ran in hole picking up casing to 2,627' MD. Broke circulation. Ran in hole picking up casing to 3,526' MD. Made up hanger and landing joint. Washed down to 3,571' MD. Circulated and conditioned mud for cement job. Rigged up cement lines. Continued to circulate and condition mud. Commenced cement job as per program. 11/20/2018 3,578 0 Nippled down diverter system and nippled up BOPE, rigged up and tested BOPE. (State Rep. Adam Earl witnessed BOP test). 11/21/2018 3,598 20 Continued BOP tests, cleared and cleaned rig floor. Rigged down test equipment and rigged up to test MPD rotation head and manifold. Tested to 500 psi low and 1,200 psi high and hold each 5 min. Made up cleanout BHA and tested casing and charted same. Drilled float equipment and 20' new hole to 3,598' MD. Circulated and conditioned mud weight in and out. Performed FIT to 13.5 ppg EMW. Pulled out of hole. 11/22/2018 4,308 710 Continued to pull out of hole, had improper hole fill, rigged up to top fill hole via pit 1, laid down clean out BHA, cleared rig floor and adjusted trip nipple. PJSM and made up rotary steerable BHA # 3, singled in from shed, filled pipe, Pulse tested, Serviced rig, washed to bottom, displaced to 9.2 LSND mud while control drilling, activiated Rhino reamer with positive opening, drilled ahead. 11/23/2018 5,935 1,627 Controlled drilling due to vibration and shock adjusting parameters as needed 8-1/2" X 9-7/8" production hole. 11/24/2018 7,260 1,325 Drilled ahead and troubleshoot encoder issues on top drive throughout the day. Control drilled due to vibration and shock adjusting parameters as needed 8-1/2" X 9-7/8" production hole. 11/25/2018 8,568 1,308 Drilled ahead 8-1/2" X 9-7/8" hole, had one issue with the Top Drive encoder during the day, placed insulation on top and secured same, continued drilling ahead. 11/26/2018 10,018 1,450 Drilled ahead to 10,018 MD, Back reamed from 10,018 to 9,807' MD with reamer blades open while standing back a stand every bottoms up. 11/27/2018 10,018 0 Backreamed out of holed from 9,841' MD to 9,706' MD. Observed well for flow (breathing). Pulled out of hole on elevators from 9,706' MD to 9,233' MD. Phase 3 conditions declared. Ran in hole to 9,990' MD. Circulated and waited on weather. Pulled out of hole on elevators from 9,990' MD to 9,040' MD. Observed well for flow. Pumped dry job. Pulled out of hole on elevators from 9,040' MD to 3,554' MD. Circulated bottoms up. Observed well for flow. Pulled out of hole on elevators from 3,554' MD to 431' MD. Laid down BHA. Rigged up to test BOPE. 11/28/2018 10,018 0 Conducted weekly BOPE test. Rigged down test equipment. Attempted to set wear ring. Made up BHA in mousehole. Serviced rig. Installed new wear ring. Made up BHA #4. Ran in hole picking up 5" drill pipe to 1,450' MD. Shallow hole tested MWD. Ran in hole picking up 5" drill pipe to 5,140' MD. Ran in hole on stands to 9,868' MD. Circulated and conditioned mud staging up to 550 gpm as shakers allow. 11/29/2018 11,388 1,370 Drilled ahead with rotary steerable system (RSS), 8-1/2" X 9-7/8" Rhino Reamer from 10,018' MD to 11,388' MD. Date 24:00 Depth (ft) Daily Progress (ft) Operation 11/30/2018 12,239 851 Drilled ahead with RSS, 8-1/2" X 9-7/8" Rhino Reamer from 11,388' MD to 11,952' MD.. Installed and calibrated RCD bearing. Drilled ahead from 11,952' MD to 12,239' MD. 12/1/2018 14,325 1,110 Drilled ahead with RSS, 8-1/2" X 9-7/8" Rhino Reamer from 13,215' MD to 14,325' MD. 12/2//2018 14,654 329 Drilled ahead from 14,325’ MD to 14,654’ MD (TD). 12/3/2018 14,654 0 Wellsite geologists leave location Running 7 5/8” casing and 3 ½” tubing were planned but not yet completed at the time of this report. Casing shoes, total depths, markers, and formation tops for 2S-315 are listed in Table 2, below. Formation tops, markers and the wellbore geometry are displayed graphically in the vertical section presented in Figure 3. TABLE 2: FORMATION TOPS, MARKERS AND CASING DEPTHS Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' -- -- -- -- no res tool during surface section Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' 10,250' 4,291' -4,132' -72' shallow to prog C-40 11,647' 4,638' -4,479' 11,393' 4,573' -4,414' -65' shallow to prog C-37 (Top Iceberg) 12,304' 4,801' -4,642' 12,298' 4,795' -4,636' -6' shallow to prog T-6 (Base Iceberg) 13,794' 5,403' -5,244' 13,750' 5,375' -5,216' -28' shallow to prog Top Cairn 14,015' 5,559' -5,400' 13,999' 5,549' -5,390' -10' shallow to prog Base Cairn 14,333' 5,784' -5,625' 14,260' 5,732' -5,573' -52' shallow to prog C-35 14,480' 5,887' -5,728' 14,410' 5,838' -5,679' -49' shallow to prog TD 14,635' 5,996' -5,837' 14,654' 6,011' -5,852' 15' deep to prog for casing tally depth Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults FIGURE 3: 2S-315 VERTICAL SECTION PROFILE WITH FORMATION TOPS AND MARKERS Geologic Summary: 2S-315 marker depths were correlated using the nearby wells Sharktooth 1, 2S-09, WS-20, and 2S-04. Confidence in the selection of the marker beds is high due to the clarity and proximity of the correlation logs. Gas peaks on the mud log matched LWD resistivity peaks. Geological supervision commenced at surface and continued to Total Depth. The 2S-315 surface section was drilled with 8.6 ppg spud mud. The mud weight was left untreated until 9.6 ppg. The production hole section was drilled out of the 10 ¾” shoe using 9.2 ppg LSND water-based mud. The mud was weighted up to 9.6 ppg as the well approached TD. A managed pressure drilling element was installed, at 11,900’ MD, before drilling past the C-37 marker for hole condition and pressure management. Geolog mudloggers collected cutting samples (4 sets of washed – 2 air dried, 2 oven dried) every 30’ TVD from surface to 13,950’ MD. Wet samples were also collected every 30’ TVD in the surface. Four sets of washed and dried 10’ TVD samples were gathered through one area of interest between ~13,950’ to 14,654’ MD (Cairn interval). Additional spot samples were caught as needed to make necessary lithology distinctions and to assist the rig team with assessing wellbore stability, hole cleaning, picking core point, and related issues. Gas samples were collected in Isotubes once every 30’ TVD from below the surface casing shoe to 13,960’ MD and in 10’ TVD intervals through the Cairn interval. During incidences of significant gas peaks above background and during the areas of interest, Isotube sampling frequency was increased to every 10’ MD. An attempt to record Carbon -12/-13 isotopes during drilling of the target zone of interest, but background gas did not reach the 0.5% volume minimum to register on the GeoIsotope device. Slow ROP, gas trap style (CVD vs QGM) and suppression of gas by the MPD likely contributed to the low gas volumes. A QGM style gas trap would have been ideal, but is not available on Doyon 142 due to the closed flow-line mud return system. Rate of penetration was controlled to 50’ feet per hour through any zones of interest for improved data rate and sample collection. Surface Hole Section: The 13 ½” surface section was drilled from the base of the conductor at 119’ MD to 3,578’ MD / -2,479’ SSTVD. The samples from surface to ~1,200’ MD mainly consisted of light to medium gray, soft to firm, hydrophilic claystone and light gray conglomeratic sand. The top of the Ugnu C was penetrated at 1,198’ MD and samples below this depth contained a mixture of pebbly sand, siltstone, and claystone. A carbonaceous shale (dead oil?) was encountered between ~1,320’ MD to 1,360’ MD. The top of the West Sak was at 1,932’ MD. The samples were comprised of light to medium gray, hydrophilic claystone, which was often silty and interbedded with sandy siltstone to occasionally very fine-grained sandstone (for more detailed lithology descriptions, see the Lithological Descriptions section below). The base of the permafrost was projected at 1,455’ MD / -1,275’ SSTVD. No hydrates were encountered. A light brownish gray sand in samples taken at 3,100’ MD and 3,250’ MD a moderate to strong petroleum odor was observed. The samples displayed a pale-yellow sample fluorescence and immediate white-blue cut fluorescence. Free oil in sample and on the shakers were observed. Production Hole Section: The production section was drilled with MI Swaco 9.2 ppg LSND water-based mud. Samples collected below the 10 ¾” casing shoe generally consisted of hydrophilic, light gray claystone and siltstone. The Campanian Sandstone was noted on LWD logs at 4,919’ MD / -2,754’ SSTVD and no gas or losses were observed. Below ~6,000’ MD / -3,200’ SSTVD, samples transitioned to light gray, very fine sandstone, which was occasionally argillaceous and often graded to siltstone. Samples collected at ~7,350 and ~7,450’ MD displayed spotty yellow fluorescence in the sample tray and blue-white solvent cut fluorescence. At 10,018’ MD, the BHA was tripped to surface to add the Schlumberger MicroScope formation imaging tool and the ProVision NMR tool. From 10,018’ MD, the samples continued to be composed of predominantly light gray siltstone and argillaceous sandstone. The C-50 marker was encountered at 10,250’ MD / -4,132’ SSTVD and the formation transitioned to light to medium gray claystone. Moderate amounts of white to buff ashfall tuff and/or tuff altered to bentonite were observed below the C-50 marker. At 11,393’ MD / -4,414’ SSTVD the wellbore crossed the C-40 marker into the upper tongue of the Hue Shale, an organic rich claystone/mudstone. The Cairn interval was penetrated at 13,999’ MD / -5,390’ SSTVD. Cairn samples dominantly consisted of light to medium gray sand, siltstone, and claystone. Sands are likely interbedded with silts and clays. Sands are mostly clear and translucent white quartz with moderate amounts of lithic grains. Spotty dull to medium yellow sample fluorescence was observed as was occasional light brown oil staining. Some light cut fluorescence was noted (photos below). The Cairn sand log profile shows minimal total vertical thickness (TVT) of gross oil pay, although potential net oil pay is difficult to calculate in the field as oil bearing sands could be thinly bedded and are likely near non-hydrocarbon bearing silts and clays which can cause resistivity levels to read lower and can be misleading overall. The resistivity curves, for the most part, over lay each other suggesting a low invasion profile. No sizeable gains or losses were observed. Figure 4: Cairn Interval Log Profile The 2S-315 final depth of 14,654’ MD /-5,852’ SSTVD was picked 179’ md below the base of the C-35 interval to allow all the formation evaluation tools in the drill string to pass over the entire target section, plus extra rat hole to allow for landing the casing per tally. Drilling was completed on December 2, 2018 at 08:00 hours. The 11,076’ of production section footage was drilled in 135.81 hours for an overall rate of penetration of 81.55 feet per hour. This is the time of on-bottom drilling of the 8.5” x 9.875” hole section. Top Cairn 13,999’ md Base Cairn 14,458’ md Lithological Descriptions: Sample descriptions are interpretive. Pick depths for formation tops are included with the sample descriptions for reference. Zones with observed shows are highlighted in yellow. Measured Depths (ft) Sample Descriptions 107 to 300 Claystone, medium to light gray, soft to slightly firm, hydrophilic, sticky, occasional slightly silty, minor very fine grained sand entrained in massive clay. 300 to 540 Claystone, 80%, medium to light gray, soft to slightly firm, hydrophilic, sticky, occasional slightly silty, occasional black shale; Sand, 20%, light to medium gray, fine to lower coarse, occasional pebbles, poorly sorted, multi to colored quartz and chert, common lithics, occasional bitumen impacted chert pebbles. 540 to 650 Conglomeratic Sand, 80%, light to medium gray, fine to lower coarse, occasional pebbles, poorly sorted, multi to colored quartz and chert, common lithics, occasional bitumen impacted chert pebbles, dominantly disaggregated, occasional cuttings with silty/clayey matrix; Claystone, 20%, light to medium gray, soft to slightly firm, hydrophilic, silty in part, gritty texture. 650 to 750 Claystone, 90%, medium to dark gray, soft to slightly firm, occasional hard and sub platy shale, hydrophilic, silty in part, gritty texture; Sand, 10%, light to medium gray, fine to lower coarse, occasional pebbles, lithic rich, dominantly disaggregated. 750 to 1,000 Conglomeratic Sand, 80%, light to medium gray, fine to lower coarse, occasional pebbles, poorly sorted, multi to colored quartz and chert, common lithics, common bitumen impacted chert pebbles, dominantly disaggregated, occasional cuttings with silty/clayey matrix; Claystone, 20%, light to medium gray, soft to slightly firm, hydrophilic, silty in part, gritty texture. 1,000 to 1,200 Claystone, 40%, medium to dark gray, soft to slightly firm, occasional hard and sub platy shale, hydrophilic, silty in part, gritty texture; Siltstone, 30% light to medium gray, soft, some grading to silty claystone; Sand, 30%, light to medium gray, fine to lower coarse, occasional pebbles, lithic rich, dom disaggregated. Top Ugnu C at 1,198' MD / -1,032' SSTVD 1,200 to 1,320 Claystone, 40%, medium to dark gray, soft to slightly firm, occasional hard and sub platy shale, hydrophilic, silty in part, gritty texture; Siltstone, 30% light to medium gray, soft, some grading to silty claystone; Sand, 30%, light to medium gray, fine to lower coarse, occasional pebbles, lithic rich, dominantly disaggregated. 1,320 to 1,360 Carbonaceous Shale, black to blackish brown, slightly soft to firm, sub-platy, no petroleum odor, no fluorescence. 1,360 to 1,390 Claystone, 70%, medium to dark gray, soft to slightly firm, occasional hard and sub platy shale, hydrophilic, silty in part, gritty texture; Sand, 30%, light to medium gray, medium to coarse, occasional pebbles, common lithic, trace wood. Top Ugnu B at 1,443' MD / to 1,263' SSTVD 1,390 to 1,530 Sand, 100%, light to medium gray, upper fine to upper medium, poor to moderately sorting, sub angular, unconsolidated, common lithics, trace claystone, trace pebbles. Top Ugnu A at 1,486' MD / to 1,303' SSTVD 1,530 to 1,870 Sand, 100%, light to medium gray, upper fine to upper medium, poor to moderately sorting, sub angular, unconsolidated, abundant lithics, trace shale, trace pebbles. 1,870 to 1,950 Claystone, 80%, light to medium gray, soft to mushy, malleable; Sand, 20%, light to medium gray, fine grain with rare coarse, well to fair sort, angular to sub angular, unconsolidated, common lithics. Top West Sak at 1,932' MD / -1,695' SSTVD 1,950 to 2,270 Claystone, 95%, medium gray, soft to slightly firm, malleable; Sand, 5%, light to medium gray, fine, unconsolidated, common lithics; rare bivalve shell fragments. 2,270 to 2,450 Claystone, 65%, light to medium gray, soft to slightly firm, hydrophilic, grades to siltstone in part; Siltstone, 30%, light to medium gray, soft, common lithic specs, clayey; Sand, 5%, light to medium gray, very fine to fine, disaggregated, common lithic fragments. 2,450 to 2,800 Sand, 60%, light to medium gray, very fine to fine, disaggregated, common lithic fragments, Siltstone, 30%, light to medium gray, soft, common lithic specs, occasional clayey; Claystone, 10%, light to medium gray, soft to slightly firm, hydrophilic, grades to siltstone in part. 2,450 to 2,800 Sand, 60%, light to medium gray, very fine to fine, disaggregated, common lithic fragments; Siltstone, 30%, light to medium gray, soft, common lithic specs, occasional clayey; Claystone, 10%, light to medium gray, soft to slightly firm, hydrophilic, grades to siltstone in part. Base West Sak at 2,940' MD / -2,479' SSTVD 3,050 to 3,250 Sand, 80%, light to medium gray to brownish gray, very fine to fine, occasional less than very fine, disaggregated, dominantly quartz, some lithic fragments, occasional shell fragments, moderately to strong petroleum odor, pale yellow fluorescence, instant white to blue cut fluorescence, dull yell to orange residual ring, free oil in sample and at shakers; Claystone, 10%, light to medium gray, soft to slightly firm, hydrophilic, grades to siltstone in part. 3,250 to 3,578 Siltstone, 35%, light to medium gray, soft, clayey in part, occasional sandy, likely interbedded and grading to claystone and very fine grained sandstone; Sand, 35%, light to medium gray to brownish gray, very fine grained down to silt, disaggregated, dominantly quartz, some lithic fragments, faint petroleum odor, could be contamination from above; Claystone, 30%, light to medium gray, soft to slightly firm, hydrophilic, grades to siltstone in part. 10 3/4" Surface Casing at 3,571' MD / -2,477' SSTVD 3,598 to 4,000 Siltstone, 45%, light to medium gray, soft, clayey in part, occasional sandy, likely interbedded and grading to claystone and very fine grained sandstone; Claystone, 30%, light to medium gray, soft, hydrophilic, grades to siltstone in part; Sand, 25%, light to medium gray to brownish gray, very fine grained down to silt, disaggregated, dominantly quartz, some lithic fragments. C-90 at 3,643’ MD / -2,495’ SSTVD 4,000 to 4,300 Siltstone, 45%, light to medium gray, soft, clayey in part, occasional sandy, likely interbedded and grading to claystone and very fine grained sandstone; Claystone, 30%, light to medium gray, soft, hydrophilic, grades to siltstone in part; Sand, 25%, light to medium gray to brownish gray, very fine grained down to silt, disaggregated, do dominantly quartz, some lithic fragments. 4,300 to 4,600 Claystone, 40%, light to medium gray, soft, hydrophilic, grades to siltstone in part; Siltstone, 35%, light to medium gray, soft, clayey in part, occasional sandy, likely interbedded and grading to claystone and very fine-grained sandstone; Sand, 25%, light to medium gray to brownish gray, very fine grained down to silt, dominantly quartz, some lithic fragments. C-80 at 4,677’ MD / -2,754’ SSTVD 4,600 to 5,000 Claystone, light to medium gray, tacky, malleable, soft to slightly firm; Siltstone, light to medium gray, brittle to crumbly; Sand, light to medium gray, very fine with occasional upper fine, unconsolidated, trace lithics Campanian Sandstone at 4,919’ MD / -2,815’ SSTVD 5,000 to 5,400 Claystone, light to medium gray, tacky to stiff, slightly malleable, soft to firm, silty to gritty; Sand, light gray, very fine, loose unconsolidated, occasional calcite, trace lithics 5,400 to 5,800 Claystone, 60%, light to medium gray, soft to firm, amorphous, common silty to gritty, likely grades to siltstone in part, occasional white tuff; Siltstone, 30%, light to medium gray, soft, clayey; Sand, 10%, light gray, upper to very fine, dominantly entrained in thick clay, common lithic fragments. 5,800 to 6,200 Claystone, 60%, light to medium gray, soft to firm, amorphous, common silty to gritty, likely grades to siltstone in part, occasional white tuff, overall little change from above; Siltstone, 30%, light to medium gray, soft, clayey; Sand, 10%, light gray, upper to very fine, dominantly entrained in thick clay, common lithic fragments. 6,200 to 6,600 Claystone, 40%, light to medium gray, soft to firm, amorphous, occasional sub platy, common silty to gritty, likely grades to siltstone in part, occasional white tuff; Siltstone, 40%, light to medium gray, soft, clayey, occasional grades to very fine sand; Sandstone, 20%, light gray, upper to very fine, soft to occasional firm, common lithic fragments, silty, matrix supported, occasional calcareous cement. 6,600 to 7,000 Sand, 60%, light gray, upper very fine to lower very fine, grain support, trace calcareous cement, unconsolidated; Claystone, 40%, light to medium gray, clayey to silty, pulverulent, soft, malleable, sectile. 7,000 to 7,300 Sand, 40%, light gray, very fine to occasional lower fine, argillaceous matrix, poor vis permeability and porosity, firm to moderately hard; Siltstone, 40%, light to medium gray, moderately hard to hard, occasional calcareous cement, elongated cuttings, argillaceous matrix; Claystone, 20%, medium gray, moderately hard to soft, elongated cuttings, gritty to silty. 7,300 to 7,700 Sand, 60%, light gray, upper to very fine, rare lower fine, common argillaceous, some matrix supported clasts, soft to slightly firm , occasional slightly hard and calcareous, common lithic fragments; Siltstone, 30%, light to medium gray, soft to slightly firm, occasional calcareous cement, argillaceous; Claystone, 10%, medium gray, slightly firm to occasional moderately hard, some elongated cuttings, occasional gritty to silty. 7,700 to 8,100 Sand, 70%, light gray, upper to very fine, rare lower fine, common argillaceous, some matrix supported clasts, soft to slightly firm, occasional slightly hard and calcareous, common lithic fragments; Siltstone, 30%, light to medium gray, soft to slightly firm, occasional calcareous cement, argillaceous, rare sub platy silty claystone. 8,100 to 8,600 Sand, 70%, light gray, upper to very fine, common argillaceous, some matrix supported clasts, soft to slightly firm, occasional calcareous, common lithic fragments; Siltstone, 30%, light to medium gray, soft to slightly firm, occasional calcareous cement, argillaceous, rare sub platy silty claystone. 8,600 to 9,000 Sand, 80%, light gray, upper to very fine, common argillaceous, some matrix supported clasts, soft to slightly firm, occasional calcareous, common lithic fragments; Siltstone, 20%, light to medium gray, soft to slightly firm, occasional calcareous cement, argillaceous. 9,000 to 9,400 Sand, 50%, light gray, upper to very fine, rare lower fine, common argillaceous, some matrix supported clasts, soft to slightly firm , occasional slightly hard and calcareous, common lithic fragments; Siltstone, 25%, light to medium gray, soft to slightly firm, occasional calcareous cement, argillaceous; Claystone, 25%, medium gray, soft to slightly firm, hydrophilic, amorphous, common gritty to silty. 9,400 to 9,700 Sandstone/Sand, 100%, medium gray, blocky to loose, friable, very fine to fine, well sorted, trace slightly calcareous, trace argillaceous matrix 9,700 to 10,000 Sandstone/Sand, 100%, medium gray, blocky to loose, friable, very fine to fine, well sorted, trace slightly calcareous, trace argillaceous matrix 10000-10250 Siltstone, 60%, medium gray, blocky to subplaty, argillaceous, occasional sandy; Claystone, 40%, light gray to medium gray, slightly firm to soft, occasional firm, amorphous to subplaty. C to 50 at 10,250' MD / to 4,132' SSTVD 10250-10600 Siltstone, 50%, medium gray, blocky to subplaty, argillaceous, occasional sandy; Claystone, 50%, light gray to medium gray, common white, waxy bentonite, slightly firm to soft, occasional firm, amorphous to subplaty. 10600-10900 Siltstone, 50%, medium gray, moderately hard, blocky to subplaty, argillaceous, occasional sandy; Claystone, 40%, light gray to medium gray, common white, waxy bentonite, slightly firm to soft, occasional firm, amorphous to sub platy; Sand, 10%, light gray, fine to very fine, well sor 10900-11400 Sand, 60%, light gray, fine to very fine, well sorted, disaggregated; Siltstone, 20%, medium gray, moderately hard, blocky to subplaty, argillaceous, occasional sandy; Claystone, 20%, gray to medium gray, trace white, moderately hard to soft, amorphous to sub platy. C to 40 at 11,393' MD / to 4,414' SSTVD 11400-11800 Siltstone, 50%, medium gray, slightly firm to moderately hard, blocky to subplaty, argillaceous, occasional very fine sand in part, common black carbonaceous flakes; Claystone, 50%, light gray to medium gray, common white, waxy bentonite, slightly firm to soft, occasional firm, amorph Install MPD at 11,900' MD 11800-12200 Claystone, 65%, light gray to medium gray, occasional white ash and altered bentonite, slightly firm to soft, occasional firm, amorphous to sub platy; Siltstone, 35%, medium gray, slightly firm to moderately hard, blocky to subplaty, argillaceous, occasional very fine sand in part, co C to 37 at 12,298' MD / to 4,636' SSTVD 12200-12600 Siltstone, 60%, medium gray, slightly firm to moderately hard, blocky to subplaty, argillaceous, occasional very fine sand in part, decreasing black carbonaceous flakes; Claystone, 40%, light gray to medium gray, some white, waxy bentonite, slightly firm to soft, occasional firm, amor 12600-13000 Siltstone, 80%, medium gray, slightly firm to moderately hard, blocky to subplaty, argillaceous, occasional fine to very fine grain calcareous cement SANDSTONE well disagg fine to very fine quartz, trace pyrite; Claystone, 20%, light gray to medium gray, firm, blocky to sub platy. 13000-13200 Siltstone, 90%, light to medium gray, firm to moderately hard, blocky to subplaty, argillaceous, silty grading to very fine to fine sand, trace pyrite; Sandstone, 10%, light gray to white, very fine to fine, trace coarse, common calcareous cement. 13200-13500 Sand, 90%, light to medium gray to clear, very fine to medium with scattered coarse, poorly sorted, disaggregated, slightly calcareous, trace pyrite; Siltstone, 10%, medium gray, firm to moderately hard, blocky to subplaty, argillaceous, occasional gritty. 13500-13900 Sand, 60%, light to medium gray, very fine to lower fine, moderately well sorted, disaggregated, occasional slightly calcareous, common lithic, trace pyrite; Siltstone, 40%, medium gray, slightly firm to soft, occasional moderately hard, blocky to subplaty, argillaceous, occasional gr T to 6 at 13,750' MD / to 5,216' SSTVD 13900-14000 Sand, 70%, light to medium gray, very fine to lower fine, moderately well sorted, disaggregated, occasional slightly calcareous, common lithic, trace pyrite; Siltstone, 30%, medium gray, slightly firm to soft, occasional moderately hard, blocky to subplaty, argillaceous, occasional gr T to 4 (Cairn) at 13,999' MD / to 5,290' SSTVD 14000-14100 Sand, 90%, light to medium gray, common clear and white, fine to very fine, well sorted, disaggregated, slightly calcareous, trace pyrite, trace glauconitic, pin point sample fluor (mineral fluor?), no cut fluor; Siltstone, 10%, medium gray, firm, blocky to subplaty, argillaceous, occ 14100-14400 Sand, 95%, light to medium gray, abn clear and white, very fine to fine with occasional medium, disagg, slightly calcareous, trace pyrite, trace biotite, trace glauconitic, trace light brown oil stain, SHOW: spotty to patchy, light brown, faint odr, dull to medium yellow fluor, slw to 14400-14654 Claystone, 60%, light gray to medium gray, slightly firm to firm, occasional hard, blocky to sub platy, occasional bladed shaley ctgs; Siltstone, 40%, medium gray to light gray, slightly firm to moderately hard, blocky to subplaty, argillaceous, occasional very fine grain, some calcar TD at 14,654' MD / to 6,011' SSTVD, 08:00 hours, 12/2/2018 Cairn Sample Pictures Depth: 14,000’ md Depth: 14,050’ md Depth: 14,050’ md Cairn Sample Pictures Depth: 14,085’ md Depth: 14,100’ md Depth: 14,115’ md Depth: 14,130’ md Depth: 14,200’ md Depth: 14,250’ md Depth: 14,285’ md Cairn Sample Fluorescence Sample fluorescence with no cutting agent. Depths are TVD. Samples with cutting agent. Samples after cutting agent in plain light. Sample fluorescence with no cutting agent. Samples with cutting agent. Samples after cutting agent in plain light. Wellsite Geologic Morning Reports DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/16/18 Report #1 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:119'Previous Depth (md): 119'Footage Last 24 hrs 0' Present Depth (tvd):119'Fm @ Present Depth: Present Activity: Plan Ahead: 11/15/2018 0600-0945 0945-1130 1130-1200 1200-1415 1415-2300 2300-2400 11/16/2018 0000-0200 0200-0315 0315-0345 0345-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section Top Ugnu C 1,152' 1,144' -985' Ugnu B 1,452' 1,431' -1,272' Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' Top West Sak 1,919' 1,849' -1,690' Base West Sak 2,906' 2,461' -2,302' 10-3/4" Casing Shoe 3,652' 2,659' -2,500' TD Surface -- -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' C-80 4,617' 2,898' -2,739' Camp SS 4,700' 2,918' -2,759' C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults BHA #1 (Draft): 13 1/2" PDC bit, Xceed rotary steerable system, arcVISION, TeleScope Sensor distances: Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Last Survey Lithology / Shows / BHA / LOT / Gas Transport rig to 2S pad Stage sub for spotting over 2S-315, set composite mats and well head equipment in cellar, set rig mats for sub Spot sub Set sub, set stompers, skid rig floor to drilling position Spot modules, work on rig acceptance list 16" conductor @ 119' MD / TVD Pre-spud meeting Test rig alarms, make up BHA, pick up drill pipe, RIH and tag cement, drill ahead Operations Summary Nipple up surface stack, obtain RKB, install pitcher nipple and mousehole, continue to take on mud, load BHA into pipeshed Service top drive, blocks and crown; mudloggers troubleshooting frozen equip Perform pre-spud derrick inspection, mobilize BHA to rig floor, strap and tally tubulars in pipeshed; mudloggers receiving new H2 generator from Deadhorse Continue to nipple up stack, install riser and turnbuckles, install 4' valves on conductor outlets, tighten diverter bolts; mudloggers troubleshooting frozen equip Slip and cut drill line; mudloggers troubleshooting frozen equip Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/17/18 Report #2 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:855'Previous Depth (md): 119'Footage Last 24 hrs 736' Present Depth (tvd):852'Fm @ Present Depth: Present Activity: Plan Ahead: 11/16/2018 0600-0615 0615-0700 0700-0930 0930-1000 1000-1230 1230-1630 1630-1830 1830-1930 1930-2200 2200-2330 2330-2400 11/17/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 700.15' 4.71° 177.00° 699.84' -540.42' -14.45' 0.90' 14.31' 2.22° 794.68' 5.51° 175.18° 794.00' -634.58' -22.84' 1.49' 22.63' 0.86° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section Top Ugnu C 1,152' 1,144' -985' Ugnu B 1,452' 1,431' -1,272' Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' Top West Sak 1,919' 1,849' -1,690' Base West Sak 2,906' 2,461' -2,302' 10-3/4" Casing Shoe 3,652' 2,659' -2,500' TD Surface -- -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' C-80 4,617' 2,898' -2,739' Camp SS 4,700' 2,918' -2,759' C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 16" conductor @ 119' MD / TVD Drilling ahead Drill ahead to TD, circulate hole clean, backream out of hole to base of permafrost Operations Summary Finish diverter function test Hold prespud meeting, hold TT diverter drill PJSM and make up cleanout BHA Flood lines and stack, pressure test mudlines to 3500 psi (good) Drill out conductor to 118' MD and make up BHA #1 Drill surface hole from 118' MD to 303' MD BHA #1: 13 1/2" PDC bit, Xceed rotary steerable system, arcVISION, TeleScope Sensor distances: D+I - 45.51' // MVC - 78.41' // GR - 79.58' // D+I - 81.70' // RES - 103.68' // GR - 103.85' Drill ahead new 13 1/2" surface hole from 303' MD to 855' MD Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Troubleshoot rig floor gas sensors; SIMOPS - work DP in shed, replace damaged jet line valve Pull out of hole racking back HWDP from 303' MD to 120' MD, make up remainder BHA #1 Pull out of hole racking and mouse hole BHA from 303' MD to 93' MD Run in hole with BHA #1, continue to test rig floor gas sensor Lubricate rig Last Survey Lithology / Shows / BHA / LOT / Gas DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/18/18 Report #3 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:2,982'Previous Depth (md): 855'Footage Last 24 hrs 2,127' Present Depth (tvd):2,492'Fm @ Present Depth: Present Activity: Plan Ahead: 11/17/2018 0600-1200 1200-1800 1800-2400 11/18/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 2,747.27' 63.84° 179.93° 2,396.22' -2,236.80' -994.27' -4.02' 990.84' 3.55° 2,841.53' 66.57° 179.51° 2,435.74' -2,276.32' -1,079.83' -3.60' 1,076.04' 2.92° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' - - Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 10-3/4" Casing Shoe 3,652' 2,659' -2,500' TD Surface -- -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' C-80 4,617' 2,898' -2,739' Camp SS 4,700' 2,918' -2,759' C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 16" conductor @ 119' MD / TVD Just below base of West Sak Drilling ahead Drill ahead to TD, circulate hole clean, backream out of hole to base of permafrost Operations Summary Drill ahead new 13 1/2" surface hole from 855' MD to 1,411' MD Drill ahead new 13 1/2" surface hole from 1,411' MD to 1,878' MD Drill ahead new 13 1/2" surface hole from 1,878' MD to 2,465' MD Sensor distances: D+I - 45.51' // MVC - 78.41' // GR - 79.58' // D+I - 81.70' // RES - 103.68' // GR - 103.85' Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Drill ahead new 13 1/2" surface hole from 2,465' MD to 2,982' MD Last Survey Lithology / Shows / BHA / LOT / Gas BHA #1: 13 1/2" PDC bit, Xceed rotary steerable system, arcVISION, TeleScope DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/19/18 Report #4 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:3,578'Previous Depth (md): 2,982'Footage Last 24 hrs 596' Present Depth (tvd):2,638'Fm @ Present Depth: Present Activity: Plan Ahead: 11/18/2018 0600-1100 1100-1200 1200-1800 1800-2100 2100-2215 2215-2400 11/19/2018 0000-0400 0400-0445 0445-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 3,496.13' 74.56° 181.11° 2,615.94' -2,456.52' -1,708.06' -8.51' 1,702.30' 1.95° Projected to TD 3,578.00' 74.56° 181.11° 2,637.74' -2,478.32' -1,786.96' -10.03' 1,781.03' 0.00° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' C-80 4,617' 2,898' -2,739' Camp SS 4,700' 2,918' -2,759' C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 16" conductor @ 119' MD / TVD Below base of West Sak Rigging up to run casing Run in hole with 10 3/4" casing, circulate hole clean, cement casing in place, nipple down diverter, nipple up BOP stack, test BOP Operations Summary Drill ahead new 13 1/2" surface hole from 2,982' MD to 3,578' MD No BHA: running 10 3/4" casing Sensor distances: N/A Continue to backream out of hole from 2,330' MD to 1,697' MD Backream out of hole while circulating bottoms up from 1,697' MD to 1,507' MD Lay down BHA #1 from 562' MD to surface Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Obtain survey and torque/drag, circulate bottom up while backreaming out of the hole from 3,578' MD to 3,492' MD Backream out of the hole from 3,492' MD to 2,330' MD Pull out of hole on elevators from 1,507' MD to 562' MD Rig up to run 10 3/4" casing and service rig Clean and clear rig floor Last Survey Lithology / Shows / BHA / LOT / Gas DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/20/18 Report #5 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:3,578'Previous Depth (md): 3,578'Footage Last 24 hrs 0' Present Depth (tvd):2,638'Fm @ Present Depth: Present Activity: Plan Ahead: 11/19/2018 0600-1200 1200-1900 1900-1930 1930-2245 2245-2300 2300-2400 11/20/2018 0000-0400 0400-0500 0500-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 3,496.13' 74.56° 181.11° 2,615.94' -2,456.52' -1,708.06' -8.51' 1,702.30' 1.95° Projected to TD 3,578.00' 74.56° 181.11° 2,637.74' -2,478.32' -1,786.96' -10.03' 1,781.03' 0.00° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' C-80 4,617' 2,898' -2,739' Camp SS 4,700' 2,918' -2,759' C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD Below base of West Sak Nippling down diverter Measure top of cement, nipple up BOPE, rig up and test BOPE, pick up clean out BHA Operations Summary Verify pipe count, make up shoe track and run in hole with 10 3/4" casing to 1,536' MD Run in hole with 10 3/4" casing from 1,536' MD to 3,526' MD Make up hanger, landing joint Circulate and condition mud Rig up SLB cement lines Pump cement Continue to pump cement Clean and clear rig floor Nipple down diverter Last Survey Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Lithology / Shows / BHA / LOT / Gas No BHA: out of hole Sensor distances: N/A DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/20/18 Report #6 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:3,578'Previous Depth (md): 3,578'Footage Last 24 hrs 0' Present Depth (tvd):2,638'Fm @ Present Depth: Present Activity: Plan Ahead: 11/20/2018 0600-0700 0700-1100 1100-1200 1200-1400 1400-1800 1800-2330 2330-2400 11/21/2018 0000-0300 0330-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 3,496.13' 74.56° 181.11° 2,615.94' -2,456.52' -1,708.06' -8.51' 1,702.30' 1.95° Projected to TD 3,578.00' 74.56° 181.11° 2,637.74' -2,478.32' -1,786.96' -10.03' 1,781.03' 0.00° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' C-80 4,617' 2,898' -2,739' Camp SS 4,700' 2,918' -2,759' C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Nipple up and orient FMC well head, obtain RKBs, test seals to 1,000 psi Nipple up BOP stack Lithology / Shows / BHA / LOT / Gas No BHA: out of hole Sensor distances: N/A 10 3/4" Casing FIT: Continue to test BOPE Clean and clear rig floor, rig down BOP test equipment. Rig up to test MPD rotation head and manifold Last Survey Lay down riser and mousehole, nipple down bell nipple, nipple down annular and diverter tee, lay down same Clean cement from flutes and top of hanger, top of cement 2.4' below bottom of flutes, nipple up FMC starting head Continue to nipple up stack Rig up and test BOPE Below base of West Sak Testing MPD components Pick up clean out BHA, run in hole, test casing, drill out float equipment/cement/shoe track/20' of new hole, perform FIT, POOH, lay down cleanout BHA Operations Summary Lay down remaining casing handling equipment, clean out mud/cuttings in flow box Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/21/18 Report #7 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:3,598'Previous Depth (md): 3,578'Footage Last 24 hrs 20' Present Depth (tvd):2,643'Fm @ Present Depth: Present Activity: Plan Ahead: 11/21/2018 0600-0700 0700-1100 1100-1200 1200-1400 1400-1500 1500-1600 1600-1800 1800-1930 1930-2300 2300-2400 11/22/2018 0000-0030 0030-0130 0130-0345 0330-0430 0430-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 3,496.13' 74.56° 181.11° 2,615.94' -2,456.52' -1,708.06' -8.51' 1,702.30' 1.95° Projected to TD 3,578.00' 74.56° 181.11° 2,637.74' -2,478.32' -1,786.96' -10.03' 1,781.03' 0.00° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' C-80 4,617' 2,898' -2,739' Camp SS 4,700' 2,918' -2,759' C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Circulate hole clean, FIT to 13.5 ppg EMW, monitor well Continue to drill cement and 20' of new hole Pull out of hole from 3,522' MD to 2,670' MD Continue to pull out of hole from 1,439' MD to surface, lay down BHA #2 Improper hole fill, switch to pit 1 and transfer pump to fill hole PJSM; Pick up BHA #3 Lithology / Shows / BHA / LOT / Gas BHA #3: 8 1/2" PDC bit, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope Sensor distances: D+I - 13.58' // GR - 31.54' // Den - 35.50' // Ult Son Cal - 36.86' // Res - 41.52' // Neu - 42.36' // GR - 61.51' // D+I - 63.63' // Sonic - 97.21' 10 3/4" Casing FIT: 13.5 ppg EMW Pull out of hole from 2,670' MD to 1,439' MD Clean and clear rig floor, adjust trip nipple Last Survey Install wear bushing, mobilize BHA to rig floor Make up BHA and run in hole with singles Continue to run in hole with cleanout BHA on singles to 3,332' MD Circulate bottoms up Rig up and test casing to 3,000 psi Wash down and tag cement at 3,474' MD, drill out cement to 3,518' MD Below base of West Sak Pick up BHA Pick up BHA, Single in hole with 33 stands, trip in hole with BHA #3, drill ahead to ~10,000' MD Operations Summary Pull MPD test cap, install trip nipple, pull test plug, and drain stack Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/23/18 Report #8 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:4,800'Previous Depth (md): 3,598'Footage Last 24 hrs 1,202' Present Depth (tvd):2,943'Fm @ Present Depth: Present Activity: Plan Ahead: 11/22/2018 0600-0730 0730-1200 1200-1245 1245-1315 1315-1345 1345-1530 1530-1630 1630-1800 1800-2400 11/23/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 4,621.69' 75.66° 178.04° 2,899.60' -2,740.18' -2,797.07' -8.88' 2,787.20' 1.55° 4,716.57' 75.41° 177.15° 2,923.30' -2,763.88' -2,888.86' -5.02' 2,878.30' 0.95° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' C-80 4,617' 2,898' -2,739' Camp SS 4,700' 2,918' -2,759' C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Pick up BHA #3 Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD Run in hole with BHA #3 on singles, shallow hole test MWD at 1,840' MD (good) Fill pipe, stage up pumps Service and inspect topdrive and blocks Stage pumps and wash to bottom from 3,551' MD to 3,598' MD Displace well to 9.2 ppg LSND mud, drill ahead new 8 1/2" hole from 3,598' MD to 3,740' MD C-80 Drill ahead Drill ahead to ~10,000' MD, pull out of hole, pick up MicroScope and NMR tools, run in hole, drill ahead to TD Operations Summary Last Survey Open rhino reamer Drill ahead new 8 1/2" hole from 4,308' MD to 4,811' MD Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Drill ahead new 8 1/2" hole from 3,740' MD to 3,835' MD Drill ahead new 8 1/2" hole from 3,835' MD to 4,308' MD Lithology / Shows / BHA / LOT / Gas BHA #3: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope Sensor distances: D+I - 13.58' // GR - 31.54' // Den - 35.50' // Ult Son Cal - 36.86' // Res - 41.52' // Neu - 42.36' // GR - 61.51' // D+I - 63.63' // Sonic - 97.21' 10 3/4" Casing FIT: 13.5 ppg EMW DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/24/18 Report #9 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:6,154'Previous Depth (md): 4,800'Footage Last 24 hrs 1,354' Present Depth (tvd):3,275'Fm @ Present Depth: Present Activity: Plan Ahead: 11/23/2018 0600-1200 1200-1800 1800-2400 11/24/2018 0000-0200 0200-0430 0400-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 5,948.14' 75.96° 178.75° 3,228.69' -3,069.27' -4,080.96' 14.96' 4,064.12' 1.28° 6,043.06' 75.65° 181.43° 3,251.97' -3,092.55' -4,172.97' 14.82' 4,155.80' 2.76° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD Drill ahead Drill ahead to ~10,000' MD, pull out of hole, pick up MicroScope and NMR tools, run in hole, drill ahead to TD Operations Summary Drill ahead new 8 1/2" x 9 7/8" hole from 4,811' MD to 5,111' MD Drill ahead new 8 1/2" x 9 7/8" hole from 5,111' MD to 5,445' MD Drill ahead new 8 1/2" x 9 7/8" hole from 6,062 MD to 6,154' MD Troubleshoot top drive, lubricate rig Drill ahead new 8 1/2" x 9 7/8" hole from 5,445' MD to 5,935' MD Drill ahead new 8 1/2" x 9 7/8" hole from 5,935 MD to 6,062' MD Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Last Survey Lithology / Shows / BHA / LOT / Gas BHA #3: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope Sensor distances: D+I - 13.58' // GR - 31.54' // Den - 35.50' // Ult Son Cal - 36.86' // Res - 41.52' // Neu - 42.36' // GR - 61.51' // D+I - 63.63' // Sonic - 97.21' 10 3/4" Casing FIT: 13.5 ppg EMW DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/25/18 Report #10 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:7,630'Previous Depth (md): 6,154'Footage Last 24 hrs 1,476' Present Depth (tvd):3,643'Fm @ Present Depth: Present Activity: Plan Ahead: 11/24/2018 0600-0845 0845-1000 1000-1030 1030-1200 1200-1230 1230-1600 1600-1630 1630-1800 1800-2400 11/25/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 7,461.77' 75.58° 178.81° 3,602.43' -3,443.01' -5,546.26' -26.57' 5,527.47' 1.70° 7,557.06' 75.57° 178.26° 3,626.17' -3,466.75' -5,638.51' -24.22' 5,619.17' 0.56° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Troubleshoot topdrive encoder fault Drill ahead new 8 1/2" x 9 7/8" hole from 6,625' MD to 6,770' MD 10 3/4" Casing FIT: 13.5 ppg EMW Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Drill ahead new 8 1/2" x 9 7/8" hole from 6,154' MD to 6,249' MD Troubleshoot topdrive encoder fault Drill ahead new 8 1/2" x 9 7/8" hole from 6,249' MD to 6,338' MD Troubleshoot topdrive encoder fault Drill ahead new 8 1/2" x 9 7/8" hole from 6,338' MD to 6,625' MD Last Survey Lithology / Shows / BHA / LOT / Gas BHA #3: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope Sensor distances: D+I - 13.58' // GR - 31.54' // Den - 35.50' // Ult Son Cal - 36.86' // Res - 41.52' // Neu - 42.36' // GR - 61.51' // D+I - 63.63' // Sonic - 97.21' Drill ahead new 8 1/2" x 9 7/8" hole from 6,770' MD to 7,260' MD Drill ahead new 8 1/2" x 9 7/8" hole from 7,260' MD to 7,630' MD Drill ahead Drill ahead to ~10,000' MD, pull out of hole, pick up MicroScope and NMR tools, run in hole, drill ahead to TD Operations Summary Troubleshoot topdrive encoder fault Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/26/18 Report #11 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:9,041'Previous Depth (md): 7,630'Footage Last 24 hrs 1,411' Present Depth (tvd):3,994'Fm @ Present Depth: Present Activity: Plan Ahead: 11/25/2018 0600-0700 0700-0730 0730-0745 0745-0830 0830-1200 1200-1800 1800-2400 11/26/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 8,937.20' 75.70° 182.71° 3,968.18' -3,808.76' -6,974.83' 1.03' 6,948.20' 1.22° 8,977.69' 75.91° 184.64° 3,978.11' -3,818.69' -7,014.00' -1.48' 6,987.44' 4.65° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Service topdrive Drill ahead new 8 1/2" x 9 7/8" hole from 7,666' MD to 7,672' MD Install insulation on topdrive encoder, secure guard Drill ahead new 8 1/2" x 9 7/8" hole from 7,672' MD to 7,811' MD Last Survey Lithology / Shows / BHA / LOT / Gas BHA #3: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope Sensor distances: D+I - 13.58' // GR - 31.54' // Den - 35.50' // Ult Son Cal - 36.86' // Res - 41.52' // Neu - 42.36' // GR - 61.51' // D+I - 63.63' // Sonic - 97.21' 10 3/4" Casing FIT: 13.5 ppg EMW Drill ahead new 8 1/2" x 9 7/8" hole from 8,568' MD to 9,041' MD Drill ahead new 8 1/2" x 9 7/8" hole from 7,811' MD to 8,126' MD Drill ahead new 8 1/2" x 9 7/8" hole from 8,126' MD to 8,568' MD Canning Drill ahead Drill ahead to ~10,000' MD, pull out of hole, pick up MicroScope and NMR tools, run in hole, drill ahead to TD Operations Summary Drill ahead new 8 1/2" x 9 7/8" hole from 7,630' MD to 7,666' MD Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/27/18 Report #12 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:10,018'Previous Depth (md): 9,041'Footage Last 24 hrs 977' Present Depth (tvd):4,218'Fm @ Present Depth: Present Activity: Plan Ahead: 11/26/2018 0600-1200 1200-1400 1400-1500 1500-1800 1800-2200 2200-2400 11/27/2018 0000-0115 0115-0200 0200-0330 0330-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 9,921.37' 75.83° 182.86° 4,210.50' -4,051.08' -7,928.05' -21.54' 7,899.76' 0.06° 9,953.43' 75.68° 182.81° 4,218.39' -4,058.97' -7,959.08' -23.08' 7,930.81' 0.49° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Pull out of hole on elevators from 9,706' MD to 9,233' MD Backream from 9,841' MD to 9,706' MD Close Rhino reamer, monitor well 30 min - slight flow BHA #3: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope Sensor distances: D+I - 13.58' // GR - 31.54' // Den - 35.50' // Ult Son Cal - 36.86' // Res - 41.52' // Neu - 42.36' // GR - 61.51' // D+I - 63.63' // Sonic - 97.21' 10 3/4" Casing FIT: 13.5 ppg EMW Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Trip back to bottom and circulate and reciprocate pipe due to Phase 3 conditions Last Survey Lithology / Shows / BHA / LOT / Gas Drill ahead new 8 1/2" x 9 7/8" hole from 9,488' MD to 9,585' MD Monitor well 30 minutes due to 56 bbl loss to formation, observed initial flowback with diminishing returns to static (40 bbls flow back) Drill ahead new 8 1/2" x 9 7/8" hole from 9,585' MD to 9,773' MD Drill ahead new 8 1/2" x 9 7/8" hole from 9,773' MD to 10,018' MD Backream from 10,018' MD to 9,841' MD Canning Circulate and reciprocate hole on bottom Backream out of hole / pull out of hole, pick up MicroScope and NMR tools, run in hole, drill ahead to TD Operations Summary Drill ahead new 8 1/2" x 9 7/8" hole from 9,041' MD to 9,488' MD Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/28/18 Report #13 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:10,018'Previous Depth (md): 10,018'Footage Last 24 hrs 0' Present Depth (tvd):4,218'Fm @ Present Depth: Present Activity: Plan Ahead: 11/27/2018 0600-1200 1200-1300 1300-1330 1330-1615 1615-1745 1745-2000 2000-2300 2300-2400 11/28/2018 0000-0400 0400-0430 0430-0530 0530-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 9,921.37' 75.83° 182.86° 4,210.50' -4,051.08' -7,928.05' -21.54' 7,899.76' 0.06° 9,953.43' 75.68° 182.81° 4,218.39' -4,058.97' -7,959.08' -23.08' 7,930.81' 0.49° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Pull out of hole on elevators from 3,554' MD to 431' MD Lay down BHA #3 Last Survey Lithology / Shows / BHA / LOT / Gas BHA #4: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope, MicroScope, NMR Sensor distances: 10 3/4" Casing FIT: 13.5 ppg EMW Test BOPE Blow down choke and kill line, pull test plug, install wear ring Wear ring will not achieve proper depth, clean and attempt to set again, unsuccessful, pull wear ring Make up BHA using the mouse hole Pull out of hole on elevators from 9,990' MD to 9,040' MD Pump dry job, blow down topdrive Pull out of hole on elevators from 9,040' MD to 3,554' MD CBU, monitor well 10 min Rig up to test BOPE Making up BHA in mouse hole Install wear ring, pick up BHA #4, single in hole, trip in hole to bottom, drill ahead to TD Operations Summary Wait on weather, circulate and reciprocate hole on bottom Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/29/18 Report #14 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:10,332'Previous Depth (md): 10,018'Footage Last 24 hrs 314' Present Depth (tvd):4,310'Fm @ Present Depth: Present Activity: Plan Ahead: 11/28/2018 0600-0630 0630-0700 0700-1045 1045-1200 1200-1230 1230-1800 1800-2130 2130-2400 11/29/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 10,067.60' 75.72° 183.10° 4,246.42' -4,087.00' -8,069.66' -27.72' 8,041.37' 1.41° 10,162.51' 75.89° 183.41° 4,269.69' -4,110.27' -8,161.52' -32.94' 8,133.34' 0.36° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' 10,256' 4,294' -4,135' -69' shallow to prog C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD C-50 Drill ahead Drill ahead to TD Operations Summary Service topdrive and blocks, verify drillpipe count in shed Install new wear bushing Make up BHA #4 Single in hole from 504' MD to 1,450' MD Shallow hole test MWD (good) Continue to run in hole from 1,450' MD to 6,087' MD Continue to run in hole from 5,140' MD to 9,968' MD Sensor distances: D+I - 13.66' // UHRI - 30.70' // Res - 33,73' // GR - 38.57' // ECO GR - 49.04' // Den - 53.00' // Ult Son Cal - 54.36' // ECO Res - 59.02' // Neu - 59.86' // NMR - 136.04' Circulate at max rate dictated by shaker capacity, work pipe from 9,968' MD to 10,018' MD Drill ahead new 8 1/2" hole from 10,018' MD to 10,332' MD 10 3/4" Casing FIT: 13.5 ppg EMW Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Last Survey Lithology / Shows / BHA / LOT / Gas BHA #4: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope, MicroScope, NMR DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:11/30/18 Report #15 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:11,783'Previous Depth (md): 10,332'Footage Last 24 hrs 1,451' Present Depth (tvd):4,668'Fm @ Present Depth: Present Activity: Plan Ahead: 11/29/2018 0600-1200 1200-1800 1800-2400 11/30/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 11,582.76' 76.04° 183.13° 4,619.60' -4,460.18' -9,537.07' -44.15' 9,504.63' 1.17° 11,676.84' 75.75° 182.37° 4,642.53' -4,483.11' -9,628.21' -48.53' 9,595.80' 0.84° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' 10,250' 4,291' -4,132' -72' shallow to prog C-40 11,647' 4,638' -4,479' C-37 (Top Iceberg) 12,304' 4,801' -4,642' T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Lithology / Shows / BHA / LOT / Gas BHA #4: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope, MicroScope, NMR Sensor distances: D+I - 13.66' // UHRI - 30.70' // Res - 33,73' // GR - 38.57' // ECO GR - 49.04' // Den - 53.00' // Ult Son Cal - 54.36' // ECO Res - 59.02' // Neu - 59.86' // NMR - 136.04' 10 3/4" Casing FIT: 13.5 ppg EMW Drill ahead new 8 1/2" hole from 11,388' MD to 11,783' MD Last Survey Drill ahead new 8 1/2" hole from 10,663' MD to 11,006' MD Drill ahead new 8 1/2" hole from 11,006' MD to 11,388' MD C-40 Drilling ahead Control driil at 80'/hour after C-37, control drill at 50'/hour through target section (Cairn), CBU at TD, backream out of hole to shoe, CBU, POOH, lay down BHA Operations Summary Drill ahead new 8 1/2" hole from 10,332' MD to 10,663' MD Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:12/01/18 Report #16 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:13,640'Previous Depth (md): 11,783'Footage Last 24 hrs 1,857' Present Depth (tvd):5,297'Fm @ Present Depth: Present Activity: Plan Ahead: 11/30/2018 0600-0745 0745-0900 0900-1200 1200-1800 1800-2400 12/1/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 13,382.78' 57.57° 169.93° 5,149.01' -4,989.59' -11,247.44' 2.43' 11,204.43' 4.18° 13,476.74' 54.69° 170.78° 5,201.37' -5,041.95' -11,324.34' 15.51' 11,279.90' 3.16° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' 10,250' 4,291' -4,132' -72' shallow to prog C-40 11,647' 4,638' -4,479' 11,393' 4,573' -4,414' -65' shallow to prog C-37 (Top Iceberg) 12,304' 4,801' -4,642' 12,298' 4,795' -4,636' -6' shallow to prog T-6 (Base Iceberg) 13,794' 5,403' -5,244' Top Cairn 14,015' 5,559' -5,400' Base Cairn 14,333' 5,784' -5,625' C-35 14,480' 5,887' -5,728' TD 14,635' 5,996' -5,837' -- Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Pick up and install MPD bearing, align and ramp with NOVOS Drill ahead new 8 1/2" hole from 11,952' MD to 12,239' MD Last Survey Lithology / Shows / BHA / LOT / Gas BHA #4: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope, MicroScope, NMR Sensor distances: D+I - 13.66' // UHRI - 30.70' // Res - 33.73' // GR - 38.57' // ECO GR - 49.04' // Den - 53.00' // Ult Son Cal - 54.36' // ECO Res - 59.02' // Neu - 59.86' // NMR - 136.04' 10 3/4" Casing FIT: 13.5 ppg EMW Drill ahead new 8 1/2" hole from 12,239' MD to 12,804' MD Drill ahead new 8 1/2" hole from 12,804' MD to 13,215' MD Drill ahead new 8 1/2" hole from 13,215' MD to 13,640' MD Iceberg interval Drilling ahead Control drill at 50'/hour starting at 13,800' MD through Cairn interval, CBU at TD, backream out of hole to shoe, CBU, POOH, lay down BHA Operations Summary Drill ahead new 8 1/2" hole from 11,783' MD to 11,952' MD Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD DAILY GEOLOGICAL REPORT: Cairn 2S-315 Date:12/02/18 Report #17 Field: API No: RTE/KBE Geologists: Planned TD 14,635' Present Depth (md) - 6:00 am:14,574'Previous Depth (md): 13,640'Footage Last 24 hrs 934' Present Depth (tvd):5,953'Fm @ Present Depth: Present Activity: Plan Ahead: 12/1/2018 0600-1200 1200-1800 1800-2400 12/2/2018 0000-0600 Type Measured Depth Inclination Azimuth TVD TVDSS North/South East/West Vertical Section Dog Leg/100 MWD 14,328.16' 45.48° 160.52° 5,780.42' -5,621.00' -11,924.89' 176.97' 11,864.09' 0.82° 14,422.37' 44.91° 161.72° 5,846.81' -5,687.39' -11,988.14' 198.61' 11,925.21' 1.09° Top/Marker MD-prognosis TVD-prog TVDSS-prog Comment MD actual TVD actual TVDSS +/- to Prognosis Comment 13-1/2" 2S-315 Surface Section (prognosed depths as per wp03) Top Ugnu C 1,152' 1,144' -985' 1,198' 1,191' -1,032' 47' deep to prog Ugnu B 1,452' 1,431' -1,272' 1,443' 1,422' -1,263' -9' shallow to prog Base Permafrost 1,455' 1,434' -1,275' -- -- -- -- no res tool during surface section Ugnu A 1,505' 1,480' -1,321' 1,486' 1,462' -1,303' -18' shallow to prog Top West Sak 1,919' 1,849' -1,690' 1,932' 1,854' -1,695' 5' deep to prog Base West Sak 2,906' 2,461' -2,302' 2,940' 2,472' -2,313' 11' deep to prog 10-3/4" Casing Shoe 3,652' 2,659' -2,500' 3,571' 2,636' -2,477' -23' shallow to prog TD Surface -- -- -- 3,578' 2,638' -2,479' -- -- 9-7/8" 2S-315 Intermediate Section (prognosed depths as per wp03) C-90 3,658' 2,660' -2,501' 3,643' 2,654' -2,495' -6' shallow to prog C-80 4,617' 2,898' -2,739' 4,677' 2,913' -2,754' 15' deep to prog Camp SS 4,700' 2,918' -2,759' 4,919' 2,974' -2,815' 56' deep to prog C-50 10,535' 4,363' -4,204' 10,250' 4,291' -4,132' -72' shallow to prog C-40 11,647' 4,638' -4,479' 11,393' 4,573' -4,414' -65' shallow to prog C-37 (Top Iceberg) 12,304' 4,801' -4,642' 12,298' 4,795' -4,636' -6' shallow to prog T-6 (Base Iceberg) 13,794' 5,403' -5,244' 13,750' 5,375' -5,216' -28' shallow to prog Top Cairn 14,015' 5,559' -5,400' 13,999' 5,549' -5,390' -10' shallow to prog Base Cairn 14,333' 5,784' -5,625' 14,260' 5,732' -5,573' -52' shallow to prog C-35 14,480' 5,887' -5,728' 14,410' 5,838' -5,679' -49' shallow to prog TD 14,635' 5,996' -5,837' 14,654' -- Drill ahead new 8 1/2" hole from 13,640' MD to 13,908' MD Kuparuk - Cairn 50-103-20776-00-00 159.42' Barry Wright / Jeff McBeth Last Casing / Window 10 3/4" casing @ 3,571' MD / 2,636 TVD Sensor distances: D+I - 13.66' // UHRI - 30.70' // Res - 33.73' // GR - 38.57' // ECO GR - 49.04' // Den - 53.00' // Ult Son Cal - 54.36' // ECO Res - 59.02' // Neu - 59.86' // NMR - 136.04' Drill ahead new 8 1/2" hole from 13,908' MD to 14,102' MD Drill ahead new 8 1/2" hole from 14,102' MD to 14,325' MD Below K-3 marker Drilling ahead Control drill at 50'/hour to TD (14,654' MD), CBU at TD, backream out of hole to shoe, CBU, POOH, lay down BHA Operations Summary 10 3/4" Casing FIT: 13.5 ppg EMW Contact Phone #'s: Geology's rig office 670-6009 // Company Man 670-6001 // Directional Driller 670-6007 // MWD 670-6008 // Doghouse 670-6012 Casing Shoes, Lateral Windows, Lateral Total Depths, Sidetracks, Markers, Formation Tops and Faults Drill ahead new 8 1/2" hole from 14,325' MD to 14,574' MD Last Survey Lithology / Shows / BHA / LOT / Gas BHA #4: 8 1/2" PDC bit with 9 7/8" Rhino Reamer, Xceed rotary steerable system, EcoScope, TeleScope, SonicScope, MicroScope, NMR 2S-315 Bottom Hole Assemblies OD (in)Bot Type Bot Gender FN OD (in) ID (in)Top Type Top Gender FN Length (ft) 8.000 2.810 6-5/8 REG Pin 8.250 6-5/8 REG Box 8.250 4.750 6-5/8 REG Box 25.07 8.250 6-5/8 REG Pin 8.250 2.880 6-5/8 REG Box 2.85 8.250 6-5/8 REG Pin 2.880 6-5/8 FH Pin 8.290 6-5/8 FH Box 5.900 6-5/8 FH Box 8.500 6-5/8 FH Pin 8.500 5.109 6-5/8 FH Box 1.51 8.250 6-5/8 FH Pin 8.250 5.690 6-5/8 FH Box 4.66 8.313 6-5/8 FH Pin 2.880 6-5/8 REG Box 8.250 6-5/8 REG Pin 7.000 3.000 4-1/2 IF Box 1.82 6.880 4-1/2 IF Pin 6.880 2.750 4-1/2 IF Box 3.03 6.750 4-1/2 IF Pin 6.750 2.880 4-1/2 IF Box 2.28 6.880 4-1/2 IF Pin 2.750 4-1/2 IF Box 6.880 4-1/2 IF Pin 2.750 4-1/2 IF Box 6.750 4-1/2 IF Pin 6.750 2.880 4-1/2 IF Box 0.59 5.000 4-1/2 IF Pin 3.000 4-1/2 IF Box 6.250 4-1/2 IF Pin 6.170 2.250 4-1/2 IF Box 1.75 5.000 4-1/2 IF Pin 3.000 4-1/2 IF Box 4.855 4-1/2 IF Pin 4.276 4-1/2 IF Box 592.78 BHA Comments 46.8 40.3 25.9 29.7 9.70 WBM 40.00 50.00 D+I 45.51 MVC 78.41 MWD Gamma Ray 79.58 13.375 1.130 6 x 14 0.902 D+I 81.70 12.125 1.500 APWD 101.35 9.750 1.920 ARC Resistivity 103.68 ARC Gamma Ray 103.85 Motor Rev/Gal. = 0.25 Schlumberger 6 NM Crossover 10 Schlumberger 5 278.37 8 SD49881 Schlumberger 30.75 G6309 Schlumberger 2.00 6.880 6.7 16 E1904 15 Blade OD (in) 28.0 8.480 Schlumberger 5" HWDP (1 joint) 2 188.20 Schlumberger 6.250 6.75" NM Spiral Drill Collar 9 8-1/4" A825M4553XP Power Pak Motor w/ 13 3/8" Stab and 1.5 deg motor bend (ported float) Date Out Bend to Bit (ft) 68.29 Total Weight in Air (1000 lbm) 39.41 27.64 SAD603464 SD50301 6.30 561.78 Bend Angle (deg) Rotor Bypass Nozzle (1/32 in) 27.39 9.8 1.42 17 Cum. Length (ft) 12 ZL30161 17.1 151.03 9.000 4 11 5" 19.50 DPS, Premium 1 3 40.65 Rig Borehole Name Schlumberger YP (lbf/100ft2) 6.75" NM Spiral Drill Collar TFA (in2) 154.090 8.400 NM Crossover 6.500 8.380 6.880 940800 BHA Nozzle Summary 30.87 24.8 Mud Weight (lbm/gal) 219.95 Field Name Rig 18 8 1/4" TeleScope MWD Depth Out (ft) Schlumberger Total Buoyant Weight (1000 lbm) 6.5 Nov 19 2018 02:301.500 Kuparuk 2S Pad Well Name 6.625 120.06 13.375 13 1/2" Kymera Hybrid Bit (KM633) 6 1/4" Mechanical Jars 114.73 157.33 Sensor Offset from Bit (ft) Structure Name 33.48 20.9 Length (ft) Serial Number 5.93 Schlumberger 13.8 16.7 SD26122 Stabilizer Summary 32.1 7 Mud Properties 14 Nov 16 2018 12:30 6.75" NM Spiral Drill Collar 7.250 35.810 28.1 5" HWDP (9 joints) 8.250 Date In Bit Grade: 1-1-WT-A-E-I-NO-TD Pump Hours: 44.23 / Drill Hours 19.63 / Rotary Hours: 12.11 / Sliding Hours: 7.52 Total Footage 3454’ Avg ROP= 176 67% Rotating Ft: 2305’ Avg ROP= 190’/hr, 33% Sliding Ft: 1148’ Avg ROP=152.7’/hr RPM: 40 – 60 / Flow Rate: 450 – 700 gpm On Bottom Torque: 2.5 – 8.6 kft-lbs SPP: 445 – 2150 psi Inc in: 0 Inc Out: 75.73 Azi in: 0 Az Out: 181.11 TD P/U wt: 117k, TD S/O wt: 99k, TD Rot wt: 104k, TD RT TQ off Btm: 5.2 218.35 PV (cP) Desc. 17855-5 5291581 1.60 283.41 Schlumberger 8 1/4" arcVISION Schlumberger Weight in Air Below Jar (1000 lbm) 8.380 3.420 1.24 116.73 8.500 Count x ID (1/32 in) Approved By Buoyant Weight Below Jar (1000 lbm) 32.06 DIR\Doyon142-DD-AKA BHA Name 250.70 Cum. Weight (1000 lbm) 95.68 Blade Length (ft) Blade Mid-Pt to Bit (ft) 13.500 GyroPulse 8.25" High Flow 12 1/8" NM Stabilizer Saver Sub Weatherford 10694-2 30.97 119.00 Mud Type Bit 13 9 3/4" NM Stab Rig 30.15 12.125 N7141 Bend Summary 32.71 3.33 NM Crossover (with baffle plate) 46.1 17.6 19.05 29.7 9.750 6.880 PD Flow Restrictor (1/32 in) 21.5 Schlumberger Hole Size (in) Total Length (ft) BHA01 2S-315_13.5in Motor_Final 13.500Plan: 2S-315 20541 Component Hughes 1.42 Manu.Max OD (in) Kuparuk River Unit - 2 Plan: 2S-315 3578.00 0.4 5.6 1621-0164 Schlumberger SD50029 Depth In (ft) 6.500 BHA #1 Final Report – Surface Section BHA #2 Final Report – Surface Casing Cleanout Run BHA #3 Final Report – Production Section with EcoScope/TeleScope OD (in)Bot Type Bot Gender FN OD (in) ID (in)Top Type Top Gender FN Length (ft) 5.750 2.250 4-1/2 REG Pin 6.750 4-1/2 REG Box 6.750 5.160 5-1/2 FH Box 1.11 6.875 5-1/2 FH Pin 6.875 2.000 5-1/2 FH Box 5.75 6.875 5-1/2 FH Pin 6.875 2.000 5-1/2 FH Box 6.10 6.750 5-1/2 FH Pin 6.750 3.880 5-1/2 FH Box 1.59 6.813 5-1/2 FH Pin 6.938 3.875 5-1/2 FH Box 4.93 6.813 5-1/2 FH Pin 6.938 3.870 4-1/2 IF Box 1.63 6.875 4-1/2 IF Pin 6.875 2.750 4-1/2 IF Box 2.66 7.250 4-1/2 IF Pin 2.813 4-1/2 IF Box 7.250 4-1/2 IF Pin 6.500 3.000 4-1/2 IF Box 2.93 7.250 4-1/2 IF Pin 2.813 4-1/2 IF Box 6.750 4-1/2 IF Pin 6.750 2.875 4-1/2 IF Box 2.45 6.875 4-1/2 IF Pin 6.875 2.750 4-1/2 IF Box 2.65 6.875 4-1/2 IF Pin 6.875 2.750 4-1/2 IF Box 2.60 6.875 4-1/2 IF Pin 6.875 2.750 4-1/2 IF Box 4.15 6.750 4-1/2 IF Pin 6.750 2.880 4-1/2 IF Box 0.59 5.000 4-1/2 IF Pin 0.000 3.000 4-1/2 IF Box 0.00 6.250 4-1/2 IF Pin 6.190 2.250 4-1/2 IF Box 1.12 5.000 4-1/2 IF Pin 0.000 3.000 4-1/2 IF Box 0.00 4.855 4-1/2 IF Pin 4.276 4-1/2 IF Box 535.67 BHA Comments 42.1 36.4 31.2 36.0 9.20 WBM D&I 13.66 UHRI 30.70 Inclination 30.72 8.375 0.900 3 x 14, 3 x 12 0.782 Resistivity 33.73 8.375 0.900 3 x 8 0.147 GR 38.57 8.375 1.190 ECO Gamma Ray 49.04 8.250 2.060 APWD 49.58 8.250 0.670 Inclination 50.76 8.250 0.670 Density 53.00 8.375 1.400 Ultrasonic Caliper 54.36 8.375 1.770 Eco Resistivity 59.02 9.875 2.030 Neutron 59.86 9.750 1.540 Vibration 79.46 8.375 1.720 D+I 82.75 Sonic 116.13 NMR 136.04 25.730.87 Hole Size (in) Total Length (ft) BHA04_2S-315_8.5in x 9.875in Xceed_Run2_In Hole 9.875Plan: 2S-315 2816 Component BHA Name 286.11 Cum. Weight (1000 lbm) 10018.00 Kuparuk River Unit - 2 Depth In (ft) 96.83 Total Weight in Air (1000 lbm) 43.13 27.51 Date Out 6960-03 103.405 SD49881 10.06 411.56 Bend Summary 1.60 10.08 SD50301 Buoyant Weight Below Jar (1000 lbm) DIR\Doyon142-DD-AKA 130.07 Blade Length (ft) Blade Mid-Pt to Bit (ft) 2.190 Schlumberger Weight in Air Below Jar (1000 lbm) 1 5" HWDP (2 joints) 8.375 1.950 26.19 176.45 8.250 6.875 Schlumberger 6 10' NMPC DN468 24.95 Smith 0.86 13 10' NMPC Rig 442.76 Desc. 38.3 SD602179 Rhino Reamer JM2469 6.41 287.71 Schlumberger proVISION 675 [NMR] w/ 8 3/8" stabilizer 8.375 Count x ID (1/32 in) 6.625 4.7 33.24 9.8 0.86 Cum. Length (ft) Bit Manu.Max OD (in) 5" 19.50 DPS, Premium Plan: 2S-315 36.0 19.0 39.62 29.6 14634.00 7.250 7.125 21.0 Smith 0.1 2.7 17855-5 Schlumberger AJ11394 249.55 Depth Out (ft) Schlumberger 8.500 1766-0566 Structure Name 7 Mud Properties 14 Nov 28 2018 07:00 9 3/4" NM Stabilizer (non- ported plunger float 1771) Approved By 6.500 8.375 11.930 25.81 26.4 5" HWDP (4 joints) Corrosion ring on top of 1st joint in) 7.250 19.8 Length (ft) 202.27 8.375 20 4 11 215.440 Kuparuk 2S Pad Well Name 6.250 186.53 8.375 8 1/2 " PDC Bit MDi616 Bit# 4 Saver Sub 169.69 212.33 Sensor Offset from Bit (ft) Bend to Bit (ft) 17.32 Schlumberger 19 0.600 Xceed 675 8 3/8" Stabilizers (Dummy float) Serial Number BHA In Hole Bit to bottom of cutters 195.11' Planned flow reamer closed 500-550 gpm Planned flow reamer open 650-700 gpm Rig Borehole Name Schlumberger YP (lbf/100ft2) 61.91 Rhino Reamer w/ 9-7/8" cutter blocks 3x8s nozzle (non-ported flapper float) TFA (in2) 30.445 6.875 EcoScope w/ 8 1/4" Stabilizer 6.500 8.250 9.875 SD603170 BHA Nozzle Summary 6.35 22.4 Mud Weight (lbm/gal) Rig 255.96 134.170 Field Name Schlumberger 6 3/4" SonicScope w/ 8 1/4" Stabilizers E6952 17.8 12.9 17.1 26079 Stabilizer Summary 29.7 124.615 PV (cP) Total Buoyant Weight (1000 lbm) 6 3/4" TeleScope MicroScope 675 w/ 8 3/8" stab 8 3/8" NM Stab Schlumberger 6960-04 15.74 Mud Type 8 3/8" NM Stabilizer 41.4 195.095 7.5 16 41633 15 Blade OD (in) 252.350 Schlumberger 6.75" Spiral Drill Collar 31.20 2 218.68 Schlumberger 7.190 6.75" Spiral Drill Collar 9 17 12 18 6 1/4" Jars G8343 Date In Schlumberger 172.910 3 69.32 Weatherford 6.76 9.750 Bend Angle (deg) 504.67 10 52.830 Schlumberger 5 123.85 8 SD259595 Schlumberger 30.15 BHA #4 In Hole – Production Section with MicroScope/ProVision Daily Mudlogger Reports Mud Engineer Daily Reports Sales Order# Prepared By: Keegan Lambe Chad Burkett Nanook Crew 905166662 Interval 1-2 Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user’s own risk. KRU 2S-315 ConocoPhillips Alaska, Inc. Harrison Bay County, AK Post Job Report Stimulation Treatment API: 50-103-20776 Prepared for: Sandeep Pedam Cairn Formation 25# Hybor G Table of Contents Section Page(s) Executive Summary Actual Design Interval Summary Well Summary Interval 1 Plots Interval 2 Plots Appendix Chemical Summary Planned Design Water Straps - D-Fit-Interval 1 Water Straps - Interval 2 Water Testing - D-Fit-Interval 1 Water Testing - Interval 2 Real-Time QC Wellbore Information Event Log - DFIT Event Log - Interval 1 Event Log - Interval 2 Fan 15 Minute Zone 1 Fan 15 Minute Zone 2 Chemical Lot Numbers Lab Testing 49-56 47 48 42 43 44 45 46 3 4 5 -10 11 12-23 24-32 34 35 41 36 37 38 39 40 ConocoPhillips Alaska, Inc. - KRU 2S-315 TOC 2 10,452 gallons of Sea Water 0 gallons of Treated Water 18,918 gallons of 30# WaterFrac-G 173,200 gallons of 30# Hybor G 12,500 pounds of Premium - 100m 286,000 pounds of Wanli - 20/40 10,957 gallons of Sea Water 0 gallons of Treated Water 0 gallons of 30# WaterFrac-G 0 gallons of 30# Hybor G 2,441 gallons of Freeze Protect 19,730 gallons of 25# WaterFrac-G 178,589 gallons of 25# Hybor G 1,500 pounds of Premium - 100m 297,630 pounds of Wanli - 20/40 Thank you, Keegan Lambe Technical Professional Halliburton Energy Services Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Engineering Executive Summary On January 02, 2019 a stimulation treatment was performed in the Cairn formation on the KRU 2S-315 well in Harrison Bay County, AK. The KRU 2S-315 was a 2 stage Vertical Perforated Design. The proposed treatment consisted of: The actual treatment fully completed 2 of 2 stages. 0 stages were skipped, and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided The Minifrac was pumped on 1/2/2019, Interval 1 was pumped 1/3/2019 and Interval 2 was pumped on 1/6/2019. Before the Job was started an inventory of 100M sand was taken. The scale weight after offloading the 100M showed an increase in 1500lbs and was completely pumped during the conditioning phase for interval 1. After going over the lab testing the Fluid system was also changed to a 25# Hybor G. After seeing how the interval was treating 3.5lb sand was cut short and the sand was distributed to the 4lb and 5lb stage. This occurred due to the pressures indicating that the formation would accept the increased sand concentration. Per customer request the 100M proppant total was made up by 20/40 Wanli. Interval 2 sand concentration was increased up to 6ppg to make up for the remaining proppant on location. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. The fluid system was changed from a 30# Hybor G down to a 25# Hybor G in order to reduce the friction from the increased viscosity. During interval 2 the CL-31 concentration was adjusted down to a 0.4gpt in order to extend out break times after lab testing indicated more favorable results. ConocoPhillips Alaska, Inc. - KRU 2S-315 Executive Summary 3 CUSTOMER ConocoPhillips Alaska, Inc.API BFD (lb/gal)8.54 LAT 70.21981413 LEASE KRU 2S-315 SALES ORDER BHST (°F)140 LONG -150.1536372 FORMATION Cairn DATE Max Pressure (psi)5745 Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop LoSurf-300D MO-67 CL-22UC CL-31 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Surfactant Buffer Crosslinker Crosslinker Freeze Protect Gel Biocide Breaker Breaker Interval Number Description Description Description (ppg)(bpm)(gal)(gal)(bbl)(bbl)(lbs)(lbs)(gpt)(gpt)(gpt)(gpt)(gpt)(ppt)(ppt)(ppt)(ppt)(ppt) 0-0 Sea Water Load Well 2.0 1,000 944 22 22 0-1 Sea Water Mini-Frac 8.0 4,200 4,185 100 100 0-2 Sea Water Flush 8.0 5,252 5,828 139 139 0-3 Freeze Protect Freeze Protect 8.0 840 907 22 22 1000.00 0-4 Shut-In Shut-In 1-1 25# Hybor G Load Well 20.0 1,000 4,421 105 105 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 1-2 25# Hybor G Mini-Frac 20.0 12,600 12,635 301 301 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 1-3 25# WaterFrac-G Flush 20.0 5,126 5,142 122 122 1.00 25.00 0.15 2.00 0.25 1-4 Shut-In Shut-In 1-5 25# Hybor G Conditioning Pad Premium - 100m 0.25 20.0 25,000 25,085 597 599 6,250 1,500 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 1-6 25# Hybor G Proppant Laden Fluid Wanli - 20/40 1.00 20.0 5,000 4,929 117 123 5,000 5,463 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 1-7 25# Hybor G Proppant Laden Fluid Wanli - 20/40 2.00 20.0 9,000 8,876 211 231 18,000 18,624 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 1-8 25# Hybor G Proppant Laden Fluid Wanli - 20/40 3.00 20.0 8,000 7,920 189 215 24,000 24,397 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 0.25 1-9 25# Hybor G Proppant Laden Fluid Wanli - 20/40 3.50 20.0 16,000 1,922 46 53 56,000 6,964 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 0.25 1-10 25# Hybor G Proppant Laden Fluid Wanli - 20/40 4.00 20.0 12,500 12,442 296 349 50,000 48,964 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 0.50 1-11 25# Hybor G Proppant Laden Fluid Wanli - 20/40 5.00 20.0 8,757 10,305 245 293 43,786 44,101 1.00 0.50 1.00 0.50 25.00 0.15 2.00 0.25 1-12 25# WaterFrac-G Flush 20.0 4,326 5,063 121 121 1.00 25.00 1-13 Freeze Protect Freeze Protect 20.0 840 711 17 17 1000.00 1-14 Shut-In Shut-In 2-1 25# Hybor G Load Well 20.0 1,000 3,562 85 85 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 2-2 25# Hybor G Mini-Frac 20.0 12,600 12,602 300 300 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 2-3 25# WaterFrac-G Flush 20.0 5,179 5,069 121 121 1.00 25.00 0.15 2.00 0.25 2-4 Shut-In Shut-In 2-5 25# Hybor G Conditioning Pad 20.0 25,000 25,112 598 598 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 2-6 25# Hybor G Proppant Laden Fluid Wanli - 20/40 1.00 20.0 5,250 5,212 124 129 5,250 4,668 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 2-7 25# Hybor G Proppant Laden Fluid Wanli - 20/40 2.00 20.0 9,000 9,155 218 237 18,000 17,860 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 2-8 25# Hybor G Proppant Laden Fluid Wanli - 20/40 3.00 20.0 10,000 9,971 237 269 30,000 28,927 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 0.25 2-9 25# Hybor G Proppant Laden Fluid Wanli - 20/40 4.00 20.0 12,750 12,753 304 357 51,000 49,753 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 0.25 2-10 25# Hybor G Proppant Laden Fluid Wanli - 20/40 5.00 20.0 9,000 8,787 209 256 45,000 43,133 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 0.50 2-11 25# Hybor G Proppant Laden Fluid Wanli - 20/40 6.00 20.0 1,000 2,899 69 80 6,000 10,335 1.00 0.50 1.00 0.40 25.00 0.15 2.00 0.25 2-12 25# WaterFrac-G Flush 20.0 4,339 4,456 106 106 1.00 25.00 0.15 2.00 0.25 2-13 Freeze Protect Freeze Protect 20.0 840 823 20 20 1000.00 2-14 Shut-In Shut-In 215,401 211,717 5,041 5,370 358,286 304,689 Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)LoSurf-300D MO-67 CL-22UC CL-31 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP 10,452 10,957 12,500 1,500 1,500 (gal)(gal)(gal)(gal)(gal)(lbs)(lbs)(lbs)(lbs)(lbs) 286,000 303,189 297,630 Initial Design Material Volume 192.1 86.6 173.2 77.9 2,520.0 5,763.5 28.8 384.2 48.0 22.0 ---Actual Design Material Volume 198.3 89.3 178.6 80.3 2,440.9 4,958.0 29.0 386.5 48.3 18.8 18,918 ---Physical Material Volume Pumped 216 92 179 88 7560 4237 28 400 50 20 173,200 ---Physical Material Volume Deviance 9%3%0%10%210%-15%-3%3%3%7% 2,520 2,441 ** IFS numbers for proppant are taken from software calculations based on multiple variables MicroMotion Volume Pumped 200 95 186 85 -4,150 28 380 49 10 19,730 ** Proppant is billed from Weight Ticket volumes MicroMotion Volume Deviance 1%6%4%6%--16%-3%-2%2%-47% 178,589 50-103-20776 905166662 Liquid Additives Dry Additives - Fluid Type Sea Water Treated Water 15% HCl 30# WaterFrac-G 30# Hybor G Proppant Type Premium - 100m Wanli - 20/40 - - Freeze Protect 25# WaterFrac-G 25# Hybor GInterval 0Cairn@ 14315 - 14345 ft 140.2 °FInterval 1Cairn@ 14315 - 14345 ft 140.2 °FInterval 2Cairn@ 14182 - 14203 ft 140.2 °FConocoPhillips Alaska, Inc. - KRU 2S-315 Actual Design 4 1/2/19 14:43 1/2/19 15:54 71 min 1.0 bpm 1,699 psi 4,182 psi 8.8 bpm 2,997 psi 4,182 psi 7.8 bpm 2,621 psi 3,757 psi 502 hhp 235 psi 400 psi 0.00 ppg 3461 psi 0.608 psi/ft 3376 psi 3348 psi 3327 psi 0 lbs 0 lbs 0 lbs 0 lbs Total Proppant Pumped* : Final 5 min: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Interval Summary KRU 2S-315 - Cairn - Interval 0 Interval Summary Start Date/Time: End Date/Time: Pump Time: Initial OA Pressure: Average Surface Pressure: Average Rate: Average Missile HHP: Initial BH Pressure (Breakdown): Average BH Pressure: Max OA Pressure: Premium - 100m Pumped: Proppant Summary ISDP: Final Fracture Gradient: Final 10 min: Wanli - 20/40 Pumped: Final 15 min: Proppant in Formation: Max Proppant Concentration: ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval Summary 5 10,957 gal 261 bbls 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 907 gal 22 bbls 0 gal 0 bbls 0 gal 0 bbls 944 gal 22 bbls 0 gal 0 bbls 0 gal 0 bbls 5,828 gal 139 bbls 4,185 gal 100 bbls 907 gal 22 bbls Completed Comments: Engineer: Treater: Supervisor: Completions Engineer Customer Rep: Chris Burkett Chris Burkett Sandeep Pedam Mike Hazen Opened well, after testing injection Stinger had fluid to the pit. It was determined Stinger had the wrong seal sizes. Stinger Tool was bypassed and max pressure was set to 4000psi. Sucessfully pumped the DFIT and shut down for observation. *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Keegan Lambe Interval Status: Freeze Protect Volume: 25# WaterFrac-G Volume: Conditioning Pad Volume: Proppant Laden Fluid Volume: Mini-Frac Volume: Freeze Protect Volume: 30# WaterFrac-G Volume: Load Well Volume: Sea Water Volume: Treated Water Volume: 15% HCl Volume: 25# Hybor G Volume: Fluid Summary (by fluid description) Fluid Summary (by stage description) 30# Hybor G Volume: Flush Volume: ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval Summary 6 1/3/19 17:54 1/3/19 20:00 101 min 20.1 bpm 3,390 psi 3,699 psi 23.3 bpm 5,824 psi 3,818 psi 22.3 bpm 4,737 psi 3,739 psi 2,587 hhp 299 psi 483 psi 5.29 ppg 17.71 cP 82 F 9.74 3594 psi 0.632 psi/ft 3521 psi 3477 psi 3446 psi 1,500 lbs 148,513 lbs 150,013 lbs 150,013 lbs KRU 2S-315 - Cairn - Interval 1 Interval Summary Start Date/Time: End Date/Time: Pump Time: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Average Rate: Average Surface Pressure: Average BH Pressure: Average Missile HHP: Initial OA Pressure: Max OA Pressure: Max Proppant Concentration: Average Visc: Average Temp: Average pH: ISDP: Final Fracture Gradient: Final 5 min: Premium - 100m Pumped: Wanli - 20/40 Pumped: Total Proppant Pumped* : Proppant in Formation: Final 10 min: Final 15 min: Proppant Summary ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval Summary 7 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 711 gal 17 bbls 10,205 gal 243 bbls 88,535 gal 2,108 bbls 4,421 gal 105 bbls 25,085 gal 597 bbls 46,394 gal 1,105 bbls 10,205 gal 243 bbls 12,635 gal 301 bbls 711 gal 17 bbls Completed Comments: Engineer: Treater: Supervisor: Completions Engineer Customer Rep: Interval Status: Flushed 3 bbl short per customer design. Used LVT for the last 20bbl of flush per request. Changed to a #25 Hybor system to reduce pipe friction per request. Minifrac ISIP of 3543psi. Shut down for pressure analysis. When pumping the main frac 3.5ppg was cut short and the sand was distributed into the 4ppg and a 5ppg sand stage was added per custmer request. Breakers were Chris Burkett Chris Burkett *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Sandeep Pedam Mike Hazen Sea Water Volume: Treated Water Volume: 30# WaterFrac-G Volume: 30# Hybor G Volume: Freeze Protect Volume: Fluid Summary (by fluid description) 25# WaterFrac-G Volume: 25# Hybor G Volume: Fluid Summary (by stage description) Load Well Volume: Conditioning Pad Volume: Proppant Laden Fluid Volume: Flush Volume: Mini-Frac Volume: Freeze Protect Volume: Keegan Lambe ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval Summary 8 1/6/19 17:12 1/6/19 19:21 104 min N/A bpm N/A psi N/A psi 25.4 bpm 6,750 psi 4,140 psi 24.6 bpm 5,472 psi 3,957 psi 3,299 hhp 234 psi 376 psi 5.78 ppg 20.9 cP 73 F 9.8 3726 psi 0.655 psi/ft 3586 psi 3537 psi 3509 psi 0 lbs 154,676 lbs 154,676 lbs 154,676 lbs Average Visc: ISDP: Final 10 min: Proppant Summary Premium - 100m Pumped: KRU 2S-315 - Cairn - Interval 2 Interval Summary Pump Time: Average Surface Pressure: Initial Rate (Breakdown): Max Rate: Total Proppant Pumped* : Proppant in Formation: Max OA Pressure: Start Date/Time: End Date/Time: Average Missile HHP: Final 15 min: Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Max Surface Pressure: Max BH Pressure: Average Rate: Average BH Pressure: Final Fracture Gradient: Final 5 min: Average Temp: Average pH: Max Proppant Concentration: Wanli - 20/40 Pumped: Initial OA Pressure: ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval Summary 9 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 823 gal 20 bbls 9,525 gal 227 bbls 90,053 gal 2,144 bbls 3,562 gal 85 bbls 25,112 gal 598 bbls 48,777 gal 1,161 bbls 9,525 gal 227 bbls 12,602 gal 300 bbls 823 gal 20 bbls Completed Comments: Engineer: Treater: Supervisor: Completions Engineer Customer Rep: Fluid Summary (by fluid description) 30# WaterFrac-G Volume: 25# WaterFrac-G Volume: Keegan Lambe Chris Burkett Chris Burkett *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Sandeep Pedam Mike Hazen Freeze Protect Volume: 25# Hybor G Volume: Fluid Summary (by stage description) Flush Volume: Interval Status: Flush was to the sleeve per customer request. Blender Operator accidently hit ignition switch, turning blender off during mini-frac. No Initial Breakdown Observed. ISIP for the minifrac was 3652psi downhole and 1063osi on the surface. Closure pressure was set to 3578psi after the minifrac data. Per customer request sand concentration was increased up to 6lb to make up for the sand not pumped before. Sea Water Volume: Proppant Laden Fluid Volume: Treated Water Volume: Load Well Volume: 30# Hybor G Volume: Freeze Protect Volume: Conditioning Pad Volume: Mini-Frac Volume: ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval Summary 10 Customer Formation Lease API Date Well Summary Premium - 100m Wanli - 20/40 Total Proppant gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs 0 10,957 261 907 22 11,864 282 1 711 17 10,205 243 88,535 2,108 99,452 2,368 1,500 148,513 150,013 2 823 20 9,525 227 90,053 2,144 100,401 2,390 154,676 154,676 Minimum 10957 261 711 17 9525 227 88535 2108 11864 282 1500 148513 150013 Average 10957 261 814 19 9865 235 89294 2126 70572 1680 1500 151595 152345 Maximum 10957 261 907 22 10205 243 90053 2144 100401 2390 1500 154676 154676 Premium - 100m Wanli - 20/40 Total Proppant gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs Total Planned 10,452 249 2,520 60 0 0 0 0 205,090 4,883 6,250 292,250 298,500 Recorded 10,957 261 2,441 58 19,730 470 178,589 4,252 211,717 5,041 1,500 303,189 304,689 Weight Tickets 1,500 297,630 299,130 ** Proppant is billed from Weight Ticket volumes Total Fluid Fluids Proppants Fluids Proppants Total FluidFreeze Protect ** IFS numbers for proppant are taken from software calculations based on multiple variables Freeze Protect 25# WaterFrac-G 25# Hybor G 25# WaterFrac-G 25# Hybor G Sea Water Sea WaterInterval January 02, 2019 50-103-20776 KRU 2S-315 Cairn ConocoPhillips Alaska, Inc. ConocoPhillips Alaska, Inc. - KRU 2S-315 Fluid System-Proppant Summary 11 <-Paste Interval 0 Plots HerePressure Test - DFIT 1/2/2019 14:06 14:07 14:08 14:09 14:10 14:11 1/2/2019 14:12 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 I1 Global Kickout Pressure (psi)Treating Pressure (psi) Treating Pressure @Pump (psi)P2 Kickout Pressure (psi) 6543 Global Event Log 3 4 5 6 Pressure Test - Globals Pressure Test - Locals Pressure Test - Max Pressure Pressure Test - Good Test 14:06:06 14:06:41 14:09:17 14:11:25 Customer:Conoco Phillips Alaska Job Date:02-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Treatment Plot - DFIT 1/2/2019 14:50 15:00 15:10 15:20 15:30 15:40 1/2/2019 15:50 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 ETreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 4321 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 12 <-Paste Interval 0 Plots HereTreatment Plot - DFIT 1/2/2019 14:50 15:00 15:10 15:20 15:30 15:40 1/2/2019 15:50 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 ETreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 4321 Pressure Test - Interval 1 Minifrac 1/3/2019 16:20 16:30 16:40 16:50 17:00 17:10 1/3/2019 17:20 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 I1 Global Kickout Pressure (psi)Treating Pressure (psi) Treating Pressure @Pump (psi)P2 Kickout Pressure (psi) 1716 15 141312 11 10 9 87 6 5 Global Event Log 5 6 7 8 9 10 11 12 13 14 15 16 17 Pressure Test - Globals Pressure Test - Locals Walk around Bad Lo-Torq Bleed Off to replace LoTorq Leak On T close to Pop-Off Bleed Down Leak on Pump Bleed Off Bad Union Seal on iron Fan Truck to blender Prime Up Pump Pressure Test - Max Presure 16:13:09 16:13:36 16:15:12 16:22:42 16:23:17 16:40:11 16:40:45 16:51:49 16:53:48 17:00:56 17:01:56 17:10:52 17:14:05 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 13 <-Paste Interval 0 Plots HerePressure Test - Interval 1 Minifrac 1/3/2019 16:20 16:30 16:40 16:50 17:00 17:10 1/3/2019 17:20 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 I1 Global Kickout Pressure (psi)Treating Pressure (psi) Treating Pressure @Pump (psi)P2 Kickout Pressure (psi) 1716 15 141312 11 10 9 87 6 5 Global Event Log 5 6 7 8 9 10 11 12 13 14 15 16 17 Pressure Test - Globals Pressure Test - Locals Walk around Bad Lo-Torq Bleed Off to replace LoTorq Leak On T close to Pop-Off Bleed Down Leak on Pump Bleed Off Bad Union Seal on iron Fan Truck to blender Prime Up Pump Pressure Test - Max Presure 16:13:09 16:13:36 16:15:12 16:22:42 16:23:17 16:40:11 16:40:45 16:51:49 16:53:48 17:00:56 17:01:56 17:10:52 17:14:05 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Nitrogen Pop-Off - Interval 1 Minifrac 1/3/2019 17:28 17:30 17:32 17:34 1/3/2019 17:36 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 I1 Global Kickout Pressure (psi)Treating Pressure (psi) Treating Pressure @Pump (psi)P2 Kickout Pressure (psi) 23222120 Global Event Log 20 21 22 23 Test Pop-Off Good Test- Pop At 6737 Other - Pop at -6911 Pop At 6851 17:28:05 17:29:00 17:32:14 17:34:47 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 14 <-Paste Interval 0 Plots HereNitrogen Pop-Off - Interval 1 Minifrac 1/3/2019 17:28 17:30 17:32 17:34 1/3/2019 17:36 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 I1 Global Kickout Pressure (psi)Treating Pressure (psi) Treating Pressure @Pump (psi)P2 Kickout Pressure (psi) 23222120 Global Event Log 20 21 22 23 Test Pop-Off Good Test- Pop At 6737 Other - Pop at -6911 Pop At 6851 17:28:05 17:29:00 17:32:14 17:34:47 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Treatment Plot - Interval 1 MiniFrac 1/3/2019 17:50 18:00 18:10 18:20 18:30 1/3/2019 18:40 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 ETreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 4321 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 15 Treatment Plot - Interval 1 MiniFrac 1/3/2019 17:50 18:00 18:10 18:20 18:30 1/3/2019 18:40 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 ETreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 4321 Blender Chemical Plot - Interval 1 Minifrac 1/3/2019 18:00 18:05 18:10 18:15 18:20 18:25 1/3/2019 18:30 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 1 2 3 4 B MO-67 Conc (gal/Mgal)CL-22 UC Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) Optiflo-III Conc (lb/Mgal)CL-31 Conc (gal/Mgal) B B B B A 321 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 16 Blender Chemical Plot - Interval 1 Minifrac 1/3/2019 18:00 18:05 18:10 18:15 18:20 18:25 1/3/2019 18:30 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 1 2 3 4 B MO-67 Conc (gal/Mgal)CL-22 UC Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) Optiflo-III Conc (lb/Mgal)CL-31 Conc (gal/Mgal) B B B B A 321 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ADP Chemical Plot - Interval 1 Minifrac 1/3/2019 18:00 18:05 18:10 18:15 18:20 18:25 18:30 1/3/2019 18:35 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 10 20 30 40 50 60 70 80 90 100 ELosurf-300D Conc (gal/Mgal)WG-36 Conc (lb/Mgal)A E 4321 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 17 ADP Chemical Plot - Interval 1 Minifrac 1/3/2019 18:00 18:05 18:10 18:15 18:20 18:25 18:30 1/3/2019 18:35 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 10 20 30 40 50 60 70 80 90 100 ELosurf-300D Conc (gal/Mgal)WG-36 Conc (lb/Mgal)A E 4321 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Net Pressure Plot - Interval 1 Minifrac 4 5 6 Time (min) 2 3 4 5 6 7 8 9 100 1000 A 0 1 2 3 4 5 6 7 8 9 10 B Net Gauge BH Pres (psi) BH Proppant Conc (lb/gal) A B Closure Pressure = 3427 psi 0 Time = 01/03/19 17:36:47 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 18 Net Pressure Plot - Interval 1 Minifrac 4 5 6 Time (min) 2 3 4 5 6 7 8 9 100 1000 A 0 1 2 3 4 5 6 7 8 9 10 B Net Gauge BH Pres (psi) BH Proppant Conc (lb/gal) A B Closure Pressure = 3427 psi 0 Time = 01/03/19 17:36:47 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Treatment Plot - Interval 1 1/3/2019 19:20 19:40 20:00 20:20 1/3/2019 20:40 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 ETreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 131211 10 98765 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 19 Treatment Plot - Interval 1 1/3/2019 19:20 19:40 20:00 20:20 1/3/2019 20:40 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 ETreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 131211 10 98765 Blender Chemical Plot - Interval 1 1/3/2019 19:10 19:20 19:30 19:40 19:50 20:00 20:10 20:20 1/3/2019 20:30 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 1 2 3 4 B MO-67 Conc (gal/Mgal)CL-22 UC Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) Optiflo-III Conc (lb/Mgal)CL-31 Conc (gal/Mgal) B B B B A 12111098765 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 20 Blender Chemical Plot - Interval 1 1/3/2019 19:10 19:20 19:30 19:40 19:50 20:00 20:10 20:20 1/3/2019 20:30 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 1 2 3 4 B MO-67 Conc (gal/Mgal)CL-22 UC Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) Optiflo-III Conc (lb/Mgal)CL-31 Conc (gal/Mgal) B B B B A 12111098765 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ADP Chemical Plot - Interval 1 1/3/2019 19:20 19:40 20:00 1/3/2019 20:20 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 10 20 30 40 50 60 70 80 90 100 ELosurf-300D Conc (gal/Mgal)WG-36 Conc (lb/Mgal)A E 131211 10 98765 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 21 ADP Chemical Plot - Interval 1 1/3/2019 19:20 19:40 20:00 1/3/2019 20:20 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 10 20 30 40 50 60 70 80 90 100 ELosurf-300D Conc (gal/Mgal)WG-36 Conc (lb/Mgal)A E 131211 10 98765 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Net Pressure Plot - Interval 1 Minifrac 4 5 6 Time (min) 2 3 4 5 6 7 8 9 100 1000 A 0 1 2 3 4 5 6 7 8 9 10 B Net Gauge BH Pres (psi) BH Proppant Conc (lb/gal) A B Closure Pressure = 3427 psi 0 Time = 01/03/19 17:36:47 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 22 Net Pressure Plot - Interval 1 Minifrac 4 5 6 Time (min) 2 3 4 5 6 7 8 9 100 1000 A 0 1 2 3 4 5 6 7 8 9 10 B Net Gauge BH Pres (psi) BH Proppant Conc (lb/gal) A B Closure Pressure = 3427 psi 0 Time = 01/03/19 17:36:47 Customer:Conoco Phillips Alaska Job Date:03-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 1 Plots 23 <-Paste Interval 0 Plots HerePressure Test - Interval 2 1/6/2019 16:06 16:08 16:10 16:12 16:14 1/6/2019 16:16 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 I1 Global Kickout Pressure (psi)Treating Pressure (psi) Treating Pressure @Pump (psi)P2 Kickout Pressure (psi) 9876 Global Event Log 6 7 8 9 Pressure Test - Globals Pressure Test - Locals Pressure Test - Max Pressure Good Pressure Test 16:07:04 16:09:31 16:13:28 16:15:17 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Nitrogen Pop-Off - Interval 2 1/6/2019 16:18 16:20 16:22 16:24 16:26 16:28 16:30 16:32 1/6/2019 16:34 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 I1 Global Kickout Pressure (psi)Treating Pressure (psi) Treating Pressure @Pump (psi)P2 Kickout Pressure (psi) 1413121110 Global Event Log 10 11 12 13 14 Adjusting Nitrogen No-Pop Bleed down to reset Good Test, Pop @ 7608psi Second Test, Pop @ 7651psi 16:18:01 16:20:06 16:21:30 16:25:30 16:28:34 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 24 <-Paste Interval 0 Plots HereNitrogen Pop-Off - Interval 2 1/6/2019 16:18 16:20 16:22 16:24 16:26 16:28 16:30 16:32 1/6/2019 16:34 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 I1 Global Kickout Pressure (psi)Treating Pressure (psi) Treating Pressure @Pump (psi)P2 Kickout Pressure (psi) 1413121110 Global Event Log 10 11 12 13 14 Adjusting Nitrogen No-Pop Bleed down to reset Good Test, Pop @ 7608psi Second Test, Pop @ 7651psi 16:18:01 16:20:06 16:21:30 16:25:30 16:28:34 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Treatment Plot - Interval 2 MiniFrac 1/6/2019 17:15 17:20 17:25 17:30 17:35 1/6/2019 17:40 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 ETreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 4321 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 25 <-Paste Interval 0 Plots HereTreatment Plot - Interval 2 MiniFrac 1/6/2019 17:15 17:20 17:25 17:30 17:35 1/6/2019 17:40 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 ETreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 4321 Blender Chemical Plot - Interval 2 MiniFrac 1/6/2019 17:15 17:20 17:25 17:30 17:35 1/6/2019 17:40 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 1 2 3 4 B MO-67 Conc (gal/Mgal)CL-22 UC Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) Optiflo-III Conc (lb/Mgal)CL-31 Conc (gal/Mgal) B B B B A 432 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 26 <-Paste Interval 0 Plots HereBlender Chemical Plot - Interval 2 MiniFrac 1/6/2019 17:15 17:20 17:25 17:30 17:35 1/6/2019 17:40 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 1 2 3 4 B MO-67 Conc (gal/Mgal)CL-22 UC Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) Optiflo-III Conc (lb/Mgal)CL-31 Conc (gal/Mgal) B B B B A 432 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ADP Chemical Plot - Interval 2 Minifrac 1/6/2019 17:15 17:20 17:25 17:30 17:35 1/6/2019 17:40 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 10 20 30 40 50 60 70 80 90 100 ELosurf-300D Conc (gal/Mgal)WG-36 Conc (lb/Mgal)A E 432 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 27 ADP Chemical Plot - Interval 2 Minifrac 1/6/2019 17:15 17:20 17:25 17:30 17:35 1/6/2019 17:40 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 10 20 30 40 50 60 70 80 90 100 ELosurf-300D Conc (gal/Mgal)WG-36 Conc (lb/Mgal)A E 432 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Net Pressure Plot - Interval 2 Minifrac 2 3 4 Time (min) 2 3 4 5 6 7 8 9 100 1000 A 0 1 2 3 4 5 6 7 8 9 10 B Net Gauge BH Pres (psi) BH Proppant Conc (lb/gal) A B Closure Pressure = 3578 psi 0 Time = 01/06/19 16:58:11 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 28 Net Pressure Plot - Interval 2 Minifrac 2 3 4 Time (min) 2 3 4 5 6 7 8 9 100 1000 A 0 1 2 3 4 5 6 7 8 9 10 B Net Gauge BH Pres (psi) BH Proppant Conc (lb/gal) A B Closure Pressure = 3578 psi 0 Time = 01/06/19 16:58:11 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Treatment Plot - Interval 2 1/6/2019 18:00 18:20 18:40 19:00 1/6/2019 19:20 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 E Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 15 1413121110987 6 5 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 29 Treatment Plot - Interval 2 1/6/2019 18:00 18:20 18:40 19:00 1/6/2019 19:20 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 A 0 10 20 30 40 50 60 70 80 90 100 B 0 1 2 3 4 5 6 7 8 9 10 C 0 100 200 300 400 500 E Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A E 15 1413121110987 6 5 Blender Chemical Plot - Interval 2 1/6/2019 18:00 18:10 18:20 18:30 18:40 18:50 19:00 1/6/2019 19:10 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 1 2 3 4 B MO-67 Conc (gal/Mgal)CL-22 UC Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) Optiflo-III Conc (lb/Mgal)CL-31 Conc (gal/Mgal) B B B B A 13121110987 6 5 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 30 Blender Chemical Plot - Interval 2 1/6/2019 18:00 18:10 18:20 18:30 18:40 18:50 19:00 1/6/2019 19:10 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 1 2 3 4 B MO-67 Conc (gal/Mgal)CL-22 UC Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) Optiflo-III Conc (lb/Mgal)CL-31 Conc (gal/Mgal) B B B B A 13121110987 6 5 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ADP Chemical Plot - Interval 2 1/6/2019 18:00 18:10 18:20 18:30 18:40 18:50 19:00 19:10 1/6/2019 19:20 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 10 20 30 40 50 60 70 80 90 100 ELosurf-300D Conc (gal/Mgal)WG-36 Conc (lb/Mgal)A E 14131211109876 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 31 ADP Chemical Plot - Interval 2 1/6/2019 18:00 18:10 18:20 18:30 18:40 18:50 19:00 19:10 1/6/2019 19:20 Time 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 A 0 10 20 30 40 50 60 70 80 90 100 ELosurf-300D Conc (gal/Mgal)WG-36 Conc (lb/Mgal)A E 14131211109876 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 Net Pressure Plot - Interval 2 3 4 5 6 7 8 Time (min) 2 3 4 5 6 7 8 9 100 1000 A 0 1 2 3 4 5 6 7 8 9 10 B Net Gauge BH Pres (psi) BH Proppant Conc (lb/gal) Slope of Net Pressure (psi/min) A B C Closure Pressure = 3578 psi 0 Time = 01/06/19 17:58:39 1 Time 83.75 NetPr 120.0 BPC 0.267 Slope -57.09 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 32 Net Pressure Plot - Interval 2 3 4 5 6 7 8 Time (min) 2 3 4 5 6 7 8 9 100 1000 A 0 1 2 3 4 5 6 7 8 9 10 B Net Gauge BH Pres (psi) BH Proppant Conc (lb/gal) Slope of Net Pressure (psi/min) A B C Closure Pressure = 3578 psi 0 Time = 01/06/19 17:58:39 1 Time 83.75 NetPr 120.0 BPC 0.267 Slope -57.09 Customer:Conoco Phillips Alaska Job Date:06-Jan-2019 Sales Order #:0905166662 Well Description:Kuparuk River Unit 2S-315 UWI:50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Interval 2 Plots 33 Sales Order# - - - - - - - - - - Event Log Lab Results Chemical Lot Numbers Fann 15 Minute Wellbore Information Chemical Summary Stimulation Treatment Appendix Planned Design Water Straps Water Report Real Time QC Prepared for: Sandeep Pedam January 3, 2018 Harrison Bay County, AK 905166662 ConocoPhillips Alaska, Inc. KRU 2S-315 Intervals 0-2 Cairn Formation API: 50-103-20776 ConocoPhillips Alaska, Inc. - KRU 2S-315 Appendix 34 Customer ConocoPhillips Alaska, Inc. Formation Cairn Lease KRU 2S-315 API 50-103-20776 Date Interval Summary - Chemicals LoSurf-300D MO-67 CL-22UC CL-31 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP (gal)(gal)(gal)(gal)(gal)(lbs)(lbs)(lbs)(lbs)(lbs) 0 0 0 0 0 1890 0 0 0 0 0 1 103 49 93 51 2940 1997 14 200 25 10 2 113 43 86 37 2730 2240 14 200 25 10 Total 216 92 179 88 7560 4237 28 400 50 20 Interval 1/2/2019 Dry AdditivesLiquid Additives ConocoPhillips Alaska, Inc. - KRU 2S-315 Chemical Summary 35 CUSTOMER ConocoPhillips Alaska, Inc.FALSE API BFD (lb/gal)8.54 LAT 70.21981413 LEASE KRU 2S-315 SALES ORDER BHST (°F)140 LONG -150.1536372 FORMATION Cairn DATE Max Pressure (psi)5745 Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval LoSurf-300D MO-67 CL-22UC CL-31 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time Time Surfactant Buffer Crosslinker Crosslinker Freeze Protect Gel Biocide Breaker Breaker Interval Number Description Description Description (ppg)(bpm)(gal)(bbl)(bbl)(lbs)(hh:mm:ss)(hh:mm:ss)(gpt)(gpt)(gpt)(gpt)(gpt)(ppt)(ppt)(ppt)(ppt)(ppt) 0-1 Sea Water Load Well 2 1,000 24 24 0:11:54 0:42:32 0-2 Sea Water Mini-Frac 8 4,200 100 100 0:12:30 0:30:38 0-3 Sea Water Flush 8 5,252 125 125 0:15:38 0:18:08 0-4 Freeze Protect Freeze Protect 8 840 20 20 0:02:30 0:02:30 1000.00 0-5 Shut-In Shut-In 1-1 30# Hybor G Load Well 20 1,000 24 24 0:01:11 2:03:27 1.00 0.50 1.00 0.50 30.00 0.15 2.00 0.25 1-2 30# Hybor G Mini-Frac 20 12,600 300 300 0:15:00 2:02:16 1.00 0.50 1.00 0.50 30.00 0.15 2.00 0.25 1-3 30# WaterFrac-G Flush 20 5,126 122 122 0:06:06 1:47:16 1.00 30.00 0.15 2.00 0.25 1-4 Shut-In Shut-In 1:41:09 1-5 30# Hybor G Conditioning Pad Premium - 100m 0.25 20 25,000 595 602 6,250 0:30:06 1:41:09 1.00 0.50 1.00 0.50 30.00 0.15 2.00 0.25 1-6 30# Hybor G Proppant Laden Fluid Wanli - 20/40 1.00 20 5,000 119 124 5,000 0:06:13 1:11:03 1.00 0.50 1.00 0.50 30.00 0.15 2.00 0.25 1-7 30# Hybor G Proppant Laden Fluid Wanli - 20/40 2.00 20 9,000 214 234 18,000 0:11:41 1:04:50 1.00 0.50 1.00 0.50 30.00 0.15 2.00 0.25 1-8 30# Hybor G Proppant Laden Fluid Wanli - 20/40 3.00 20 8,000 190 216 24,000 0:10:50 0:53:08 1.00 0.50 1.00 0.50 30.00 0.15 2.00 0.25 0.25 1-9 30# Hybor G Proppant Laden Fluid Wanli - 20/40 3.50 20 16,000 381 441 56,000 0:22:05 0:42:19 1.00 0.50 1.00 0.50 30.00 0.15 2.00 0.25 0.25 1-10 30# Hybor G Proppant Laden Fluid Wanli - 20/40 4.00 20 10,000 238 281 40,000 0:14:05 0:20:14 1.00 0.50 1.00 0.50 30.00 0.15 2.00 0.25 0.50 1-11 30# WaterFrac-G Flush 20 4,326 103 103 0:05:09 0:06:09 1.00 30.00 0.15 2.00 0.25 1-12 Freeze Protect Freeze Protect 20 840 20 20 0:01:00 0:01:00 1000.00 1-13 Shut-In Shut-In 2-1 30# Hybor G Load Well 20 1,000 24 24 0:01:11 1:58:18 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25 2-2 30# Hybor G Mini-Frac 20 12,600 300 300 0:15:00 1:57:07 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25 2-3 30# WaterFrac-G Flush 20 5,126 122 122 0:06:06 1:42:07 1.00 30.00 0.15 2.00 0.25 2-4 Shut-In Shut-In 1:36:00 2-5 30# Hybor G Conditioning Pad Premium - 100m 0.25 20 25,000 595 602 6,250 0:30:06 1:36:00 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25 2-6 30# Hybor G Proppant Laden Fluid Wanli - 20/40 1.00 20 5,000 119 124 5,000 0:06:13 1:05:54 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25 2-7 30# Hybor G Proppant Laden Fluid Wanli - 20/40 2.00 20 9,000 214 234 18,000 0:11:41 0:59:41 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25 2-8 30# Hybor G Proppant Laden Fluid Wanli - 20/40 3.00 20 8,000 190 216 24,000 0:10:50 0:47:59 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25 0.25 2-9 30# Hybor G Proppant Laden Fluid Wanli - 20/40 3.50 20 16,000 381 441 56,000 0:22:05 0:37:10 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25 0.25 2-10 30# Hybor G Proppant Laden Fluid Wanli - 20/40 4.00 20 10,000 238 281 40,000 0:14:05 0:15:05 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25 0.50 2-11 30# WaterFrac-G Flush 4,339 103 103 0:01:00 1.00 30.00 0.15 2.00 0.25 2-12 Freeze Protect Freeze Protect 20 840 20 20 0:01:00 0:01:00 1000.00 2-13 Shut-In Shut-In 1/2/19 Liquid Additives Dry Additives 50-103-20776 905166662 Interval 0Cairn@ 14315 - 14345 ft 140.2 Interval 1Cairn@ 14315 - 14345 ft 140.2 °FInterval 2Cairn@ 14182 - 14203 ft 140.2 °FConocoPhillips Alaska, Inc. - KRU 2S-315 Planned Design 36 Customer: Well: Date: Formation: SO#: Day: Tank Type Water Source Inches Gallons Barrels Temperature (°F)Inches Gallons Barrels 1 Atigan CPF2 102 19,175 457 114 103 19,368 461 2 Atigan CPF3 105 19,755 470 104 104 19,562 466 3 Atigan CPF4 105 19,755 470 122 103 19,368 461 4 Atigan CPF5 105 19,755 470 90 17 2,722 65 5 Atigan CPF6 105 19,755 470 122 16 2,540 60 6 Atigan CPF7 106 19,949 475 117 9 1,262 30 7 Atigan CPF8 105 19,755 470 80 9 1,262 30 8 Atigan CPF9 105 19,755 470 100 9 1,262 30 9 Atigan CPF10 105 19,755 470 88 9 1,262 30 Gallons Barrels Gallons Barrels Gallons Barrels 177,409 4,224 68,608 1,634 108,801 2,591 Zones:1 2 3 4 5 6 7 Volume Needed for X Intervals (BBL):810 3,450 5,590 8,000 Number of Tanks Needed:2 7 12 17 0 0 0 Tank Bottoms (BBL):379 86 -152 -420 469 469 469 Pre-Job Barrel Bottoms General Beginning Strap Ending Strap Location Summary Starting Volume Ending Volume Total Used Minifrac-Zone 1 Conoco Phillips Alaska, Inc. Kuparuk River #2S-315 1/1/2019 Cairn 905166662 ConocoPhillips Alaska, Inc. - KRU 2S-315 Water Straps - D-Fit-Interval 1 37 Customer: Well: Date: Formation: SO#: Day: Tank Type Water Source Inches Gallons Barrels Temperature (°F)Inches Gallons Barrels 1 Atigan CPF2 98 18,401 438 96 9 1,262 30 2 Atigan CPF3 104 19,562 466 90 9 1,262 30 3 Atigan CPF4 103 19,368 461 103 9 1,262 30 4 Atigan CPF5 105 19,755 470 102 9 1,262 30 5 Atigan CPF6 105 19,755 470 102 9 1,262 30 6 Atigan CPF7 101 18,981 452 101 53 9,535 227 7 Atigan CPF8 106 19,949 475 97 95 17,821 424 Gallons Barrels Gallons Barrels Gallons Barrels 135,771 3,233 36,190 862 99,581 2,371 Zones:1 2 3 4 5 6 7 Volume Needed for X Intervals (BBL):810 3,450 5,590 8,000 Number of Tanks Needed:2 7 12 17 0 0 0 Tank Bottoms (BBL):346 -31 -337 -681 462 462 462 Zone 2 Conoco Phillips Alaska, Inc. Kuparuk River #2S-315 1/4/2019 Cairn 905166662 Pre-Job Barrel Bottoms General Beginning Strap Ending Strap Location Summary Starting Volume Ending Volume Total Used ConocoPhillips Alaska, Inc. - KRU 2S-315 Water Straps - Interval 2 38 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Pre-Crosslink pH Post-Crosslink pH Crosslink Bacteria -°F mg/L mg/L mg/L mg/L mg/L mg/L cP ----(Y/N)BQ Value Tank #Hydrometer Digital Thermometer Strip Titration Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe Probe -Mycometer 1 1.024 74.3 0 17,000 800 920 1,280 2,200 31 7.1 7.1 9.9 10.1 Y 647 2 1.026 74.8 0 16,200 800 347 1,733 2,080 29 7.1 7.2 10.0 10.2 Y 5,022 3 1.024 74.3 0 17,000 800 600 1,440 2,040 27 7.2 7.3 9.7 9.7 Y 845 4 1.026 69.6 0 17,400 800 560 1,760 2,320 28 7.1 7.5 9.8 9.8 Y 2,433 5 1.024 69.9 0 17,400 800 800 1,640 2,440 27 7.1 7.3 9.8 10.0 Y 740 6 1.026 65.8 0 16,400 800 600 1,840 2,440 28 7.1 7.2 9.7 9.8 Y 435 7 1.026 65.8 0 18,000 800 480 1,720 2,200 28 7.5 7.7 10.0 9.9 Y 2,844 8 1.026 64.5 0 17,200 800 507 1,627 2,133 27 7.2 7.3 9.8 9.8 Y 1,783 9 1.026 63.8 0 17,800 800 520 1,520 2,040 27 7.0 7.4 9.9 9.9 Y 1,299 Average 1.025 69.2 0 17,156 800 593 1,618 2,210 28 7.2 7.3 9.8 9.9 -1,783 Maximum 1.026 74.8 0 18,000 800 920 1,840 2,440 31 7.5 7.7 10.0 10.2 -5,022 Minimum 1.024 63.8 0 16,200 800 347 1,280 2,040 27 7.0 7.1 9.7 9.7 -435 Range 0.002 11.0 0 1,800 0 573 560 400 4 0.5 0.6 0.3 0.5 -4,586 Well Name:KRU 2S-315 Water Source:CPF 2 Alaska District Field QC Prejob Water Analysis on Location Company: Conoco Phillips ConocoPhillips Alaska, Inc. - KRU 2S-315 Water Report Interval 1 39 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Pre-Crosslink pH Post-Crosslink pH Crosslink Bacteria -°F mg/L mg/L mg/L mg/L mg/L mg/L cP ----(Y/N)BQ Value Tank #Hydrometer Digital Thermometer Strip Titration Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe Probe -Mycometer 1 1.024 74.3 0 17,000 800 920 1,280 2,200 19 7.1 7.4 9.8 9.9 Y 647 2 1.026 74.8 0 16,200 800 347 1,733 2,080 18 7.1 7.5 9.9 10.0 Y 5,022 3 1.024 74.3 0 17,000 800 600 1,440 2,040 18 7.2 7.5 10.0 10.1 Y 845 4 1.026 69.7 0 17,200 800 640 1,760 2,400 19 7.2 7.4 9.8 9.9 Y 1,577 5 1.024 67.0 0 17,600 1,200 560 1,600 2,160 19 7.2 7.5 9.7 9.9 Y 4,934 6 1.026 65.0 0 17,400 800 720 1,680 2,400 20 7.3 7.5 9.8 10.0 Y 2,641 7 1.024 69.0 0 17,800 1,200 560 1,520 2,080 17 7.4 7.6 9.7 9.9 Y 3,623 Average 1.025 70.6 0 17,171 914 621 1,573 2,194 19 7.2 7.5 9.8 10.0 -2,486 Maximum 1.026 74.8 0 17,800 1,200 920 1,760 2,400 20 7.4 7.6 10.0 10.1 -5,022 Minimum 1.024 65.0 0 16,200 800 347 1,280 2,040 17 7.1 7.4 9.7 9.9 -647 Range 0.002 9.8 0 1,600 400 573 480 360 3 0.3 0.2 0.3 0.2 -4,375 Alaska District Field QC Prejob Water Analysis on Location Company: Conoco Phillips Well Name:KRU 2S-315 Water Source:CPF 2 ConocoPhillips Alaska, Inc. - KRU 2S-315 Water Report Interval 2 40 XL Linear Linear XL Interval Stage Visc pH Temp °F pH Interval Stage Visc pH Temp °F pH 1 Mini-Frac 14 7.4 78.5 9.9 2 MiniFrac 20 7.1 74.4 9.6 1/6/2019 Pad 21 7.1 77.3 9.6 Pad 21 7.1 76.6 9.7 1#19 7.2 78.7 9.8 1#24 7.1 72 9.8 2#19 7.1 75.5 9.7 2#23 7.2 73.5 10 3#16 7.2 86.6 9.8 3#20 7.1 72.5 9.8 3.5#16 7.1 83.2 9.8 4#20 7.1 73.5 9.8 4#16 7.3 96.6 9.7 5#20 7.2 73.6 9.9 5#17 7.2 76.1 9.8 6#19 7.2 68.6 9.9 Comments Comments 1/3/2019 During Pad the viscosity was as high as 33cP. Walked viscosity down using gel set points. During 1# viscosity began to creep up, the ADP setpoints were adjusted to maintain a viscosity. Customer:ConocoPhillips Alaska, Inc. Wellname & #:2S-315 Date:January 3, 2019 ConocoPhillips Alaska, Inc. - KRU 2S-315 Real-Time QC 41 ConocoPhillips Alaska, Inc. Cairn KRU 2S-315 50-103-20776 Description OD (in)ID (in)Wt (#)Grade FUF (gal/ft) MD Top (ft)MD Btm (ft)Volume (gal)Tubular Burst Pressure (psi) Tubing 3.5 2.992 9.3 L-80 0.3652 0 14,299 5,222 10,159 Casing 7.625 6.875 29.7 L-80 1.9284 14,299 14,654 685 10,160 Total 14,654 5,907 17.39047619 3716.588 88.49019048 780 18.57142857 ft 1.41 ft 140.2 124.3302531 5608.733888 5176.71 ft 345.0164294 Flush 139 5179.2664 5179.2664 16 5221.6296 217.2848 123.3158667 ft 1.41 30.848 5179.2664 5252.4776 5.173447619 120.3158667 ft 140.2 125.0647293 123.3158667 125.05899 13836.98357 ft 102.0647293 120.3158667 122.05899 345.0164294 5053.2664 5126.4776 Top MD (ft)Btm MD (ft)Average TVD (ft)Interval #Formation Descriptor Average Interval Temperature (F) Ball Drop Time (HH:MM) Ball Hit Time (HH:MM) JSV Drop (bbl) JSV Slow Down (bbl)JSV Hit (bbl)Early (bbl) Surface Seat Pressure (psi) Surface Peak Pressure (psi) Surface Differential (psi) BH Seat Pressure (psi) BH Peak Pressure (psi) BH Differential (psi) Rate at Shift (bpm) Proppant Conc. @ Sleeve (lb/gal) Toe 14,315 14,345 5,690 0 Cairn 140.2 NA NA NA NA NA NA NA NA NA NA NA NA NA NA 14,315 14,345 5,690 1 Cairn 140.2 NA NA NA NA NA NA NA NA NA NA NA NA NA NA Heel 14,182 14,203 5,690 2 Cairn 140.2 NA NA NA NA NA NA NA NA NA NA NA NA NA NA5,179 123.3 Displacement to Top Sleeve/Perf (gal) with 3 bbl under flush (BBLS) 5,252 125.1 5,126 122.1 Interval # 0 Max Pressure (psi) 5,745 Isolation Type Cemented Casing Treatment Tubulars Customer Formation Lease API Date Temperature Data Temp. Gradient (°F/100 ft) BHST (°F) Directional Data 5,690 N/A 14,654 Directional Data N/A 1/2/2019 KOP Temperature Data Sleeve/Perf Depth Sleeves 1 2 Temp. Gradient (°F/100 ft) BHST (°F)TVD at Bottom Perf MD at Bottom Perf 5,690 14,345 KOP Avg. TVD Total MD ConocoPhillips Alaska, Inc. - KRU 2S-315 Wellbore Information 42 Seq No.Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Gauge BH Pres 1 09:53:55 (01/02/19)Start Job Starting Job 0 15 15 0 15 1 09:53:55 (01/02/19)Next Treatment Treatment Interval 1 0 15 15 0 15 2 11:34:47 Prime Pumps Prime Pumps 0 45 69 0 15 3 14:06:05 Pressure Test Pressure Test - Globals 0 1409 1446 0 2426 4 14:06:41 Pressure Test Pressure Test - Locals 0 2025 2101 0 2426 5 14:09:17 Pressure Test Pressure Test - Max Pressure 0 6105 6257 0 2426 6 14:11:25 Pressure Test Pressure Test - Good Test 0 5937 6049 0 2426 7 14:43:05 Open Well Open Well 0 127 78 0 2429 1 14:50:36 Next Stage Load Well 0 39 36 0 2439 8 14:51:45 Other Fluid to Tank by Stinger 1.28 20 16 0 2381 9 14:52:30 Other Stinger Shut in Well 1.32 19 14 1.1 2421 10 14:55:41 Other Pressure Test Cups 1.33 297 314 0 2705 11 14:57:03 Other Failed Pressure Test on Stinger 1.34 96 49 0 2447 12 15:08:43 Other Stinger Open Well 2.64 44 29 0 2446 13 15:10:43 Other Resume Pumping 2.64 49 51 0 2460 14 15:11:46 Break Formation Break Formation 2.68 1714 1785 0 4143 2 15:15:17 Next Stage Minifrac 22.62 2998 3078 8.6 3801 3 15:27:11 Next Stage Flush 122.12 2731 2814 8.4 3764 15 15:28:20 Alarm Delta Stage At Top Perf = 1 131.73 2724 2809 8.3 3778 16 15:31:04 Alarm Delta Stage At Top Perf = 2 154.54 2733 2822 8.4 3796 17 15:42:07 Other Freeze Protect 246.78 2733 2818 8.4 3803 4 15:42:11 Next Stage LVT 247.33 2734 2818 8.3 3803 18 15:42:37 Other LVT On Inline 251.09 2732 2816 8.4 3803 19 15:43:01 Alarm Delta Stage At Top Perf = 3 254.43 2706 2772 8.4 3797 20 15:43:41 Other Full LVT at inline 259.99 2714 2809 8.3 3798 21 15:46:29 ISIP ISIP 281.7 1159 1205 0 3476 22 15:51:30 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 281.7 1113 1150 0 3391 23 15:54:10 Other Shut In Well 281.7 1096 1131 0 3375 24 15:54:10 Other Bleed off Well 281.7 1096 1131 0 3375 25 15:56:30 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 281.7 4 16 0 3363 26 16:01:30 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 281.7 14 20 0 3342 27 16:04:37 Other Fan Pumps 281.7 15 21 0 3329 Event Log D-Fit (1/2/2019) ConocoPhillips Alaska, Inc. - KRU 2S-315 Event List -DFIT 43 Seq No.Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Gauge BH Pres 1 11:05:40 (01/03/19)Start Job Starting Job 0 15 15 0 15 1 11:05:40 (01/03/19)Next Treatment Treatment Interval 1 0 15 15 0 15 2 15:02:43 Prime Pumps Prime Pumps 0 11 17 0 2559 3 15:37:29 Other Re-Oriented Hoses 0 70 71 0 2561 4 15:59:54 Other Fixing Tub Fill Valve 0 136 63 0 2558 5 16:13:08 Pressure Test Pressure Test - Globals 0 564 476 0 2556 6 16:13:36 Pressure Test Pressure Test - Locals 0 879 913 0 2556 7 16:15:11 Other Walk around 0 2713 2629 0 2556 8 16:22:41 Other Bad Lo-Torq 0 4437 4512 0 2556 9 16:23:17 Other Bleed Off to replace LoTorq 0 4351 4390 0 2556 10 16:40:10 Other Leak On T close to Pop-Off 0 7155 6667 0 2555 11 16:40:45 Other Bleed Down 0 7094 6464 0 2555 12 16:51:49 Other Leak on Pump 0 7343 7392 0 2554 13 16:53:47 Other Bleed Off 0 6885 6886 0 2554 14 17:00:56 Other Bad Union Seal on iron 0 7219 7306 0 2553 15 17:01:55 Other Fan Truck to blender 0 -2 28 0 2553 16 17:10:52 Other Prime Up Pump 0 39 21 0 2553 17 17:14:04 Pressure Test Pressure Test - Max Pressure 0 7309 7442 0 2553 18 17:17:05 Other Good Test- No Visual Leaks 0 6922 7000 0 2553 19 17:21:04 Other Setting Nitrogen Regulator 0 31 18 0 2552 20 17:28:05 Other Test Pop-Off 0 51 42 0 2552 21 17:29:00 Other Good Test- Pop At 6737 0 6611 6745 0 2552 22 17:32:14 Other Other - Pop at -6911 0 6827 6925 0 2552 23 17:34:46 Other Pop At 6851 0 6723 6866 0 2552 24 17:54:05 Open Well Open Well 0 366 322 0 2563 1 17:56:54 Next Stage Load Well 5.08 3472 3549 10.1 3798 25 17:57:29 Other Truck Kicked 7.45 5514 5713 14.2 3814 26 17:58:14 Other Truck Kicked 16.53 5383 5521 14.2 3769 27 18:00:47 Other Leak on Growler 52.02 2745 2864 6.6 3746 28 18:11:24 Other Resume Pumping 52.08 1119 1153 0 3320 2 18:15:08 Next Stage Pad 100.2 3773 3848 14.9 3738 29 18:16:52 Alarm Delta Stage At Top Perf = 1 131.93 4274 4364 20.1 3868 30 18:21:52 Alarm Delta Stage At Top Perf = 2 232.16 3987 4067 20.1 3723 3 18:30:16 Next Stage Flush 401.02 3890 3970 20.1 3708 31 18:36:24 Other Shut down for Data Analysis 523.45 150 109 0 3697 4 18:36:32 Next Stage Shut-In for FET Analysis 523.45 1378 50 0 3520 32 18:36:48 ISIP ISIP 523.45 1027 21 0 3531 5 19:06:06 Next Stage Conditioning Pad 523.45 1126 1125 0 3407 33 19:06:53 Alarm Delta Stage At Top Perf = 3 533.08 3396 3477 20 3726 34 19:12:28 Alarm Delta Stage At Top Perf = 5 656.75 3954 4202 22.7 3711 6 19:32:39 Next Stage 1.00 Wanli -20/40 1121.49 4575 4663 23.1 3743 7 19:37:58 Next Stage 2.00 Wanli -20/40 1243.99 4593 4689 23 3737 35 19:38:21 Alarm Delta Stage At Top Perf = 6 1252.79 4595 4689 22.9 3737 36 19:43:42 Alarm Delta Stage At Top Perf = 7 1375.56 4783 4887 22.9 3737 8 19:47:54 Next Stage 3.00 Wanli -20/40 1472.08 4640 4733 23 3741 37 19:53:37 Alarm Delta Stage At Top Perf = 8 1603.69 4814 4908 22.9 3743 9 19:57:08 Next Stage 3.50 Wanli -20/40 1684.35 4849 4940 22.9 3743 10 19:59:24 Next Stage 4.00 Wanli -20/40 1736.31 4881 4990 22.9 3751 38 20:02:52 Alarm Delta Stage At Top Perf = 9 1815.74 4995 5086 22.9 3752 39 20:05:10 Alarm Delta Stage At Top Perf = 10 1868.43 5041 5140 22.9 3757 11 20:14:40 Next Stage 5.00 Wanli -20/40 2085.82 5260 5367 22.9 3765 40 20:19:48 Other Pump Kicked out 2202.48 5826 5938 22.7 3776 41 20:20:33 Alarm Delta Stage At Top Perf = 11 2218.15 5443 5546 21.3 3764 12 20:28:16 Next Stage Flush 2380.92 5226 5325 21.1 3807 13 20:33:57 Next Stage Flush 2501.61 4679 4772 21.3 3778 42 20:34:28 Alarm Delta Stage At Top Perf = 12 2512.63 5184 5270 21.4 3770 43 20:34:45 ISIP ISIP 2515.49 1351 1310 0 3609 44 20:39:46 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 2518.19 1271 1285 0 3536 45 20:43:46 Other Shut-In 2518.19 1244 1259 0 3499 46 20:44:45 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 2518.19 53 28 0 3492 47 20:49:46 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 2518.19 59 48 0 3460 48 20:50:13 Other Fan Trucks 2518.19 216 227 0 3458 Event Log Interval 1 (1/3/2019) ConocoPhillips Alaska, Inc. - KRU 2S-315 Event List -Interval 1 44 Seq No.Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Gauge BH Pres 1 07:41:41 (01/06/19)Start Job Starting Job 0 15 15 0 15 1 07:41:41 (01/06/19)Next Treatment Treatment Interval 1 0 15 15 0 15 2 07:45:52 (01/06/19)Next Treatment Treatment Interval 2 0 21 38 0 15 2 10:23:32 Pause Suspending Job 0 15 15 0 15 3 10:25:04 Resume Resuming Job 0 14 44 0 2724 4 11:31:39 Other Stinger Stabbing On 0 29 15 0 2536 5 14:00:01 Prime Pumps Prime Pumps 0 14 61 0 2711 6 16:07:03 Pressure Test Pressure Test - Globals 0 178 24 0 2700 7 16:09:30 Pressure Test Pressure Test - Locals 0 970 994 0 2699 8 16:13:28 Pressure Test Pressure Test - Max Pressure 0 8000 8040 0 2699 9 16:15:17 Pressure Test Good Pressure Test 0 7798 7782 0 2699 10 16:18:01 Other Adjusting Nitrogen 0 861 279 0 2699 11 16:20:05 Other No-Pop 0 7664 7800 0 2699 12 16:21:30 Other Bleed down to reset 0 7279 7346 0 2699 13 16:25:30 Other Good Test Pop @ 7608psi 0 7471 7623 0 2698 14 16:28:34 Other Second Test Pop @ 7651psi 0 7510 7666 0 2698 15 17:05:17 Open Well During Open Well Hydraulic leak on Stinger 0 446 17 0 2827 16 17:12:54 Open Well Open Well 0 800 87 0 2794 1 17:13:25 Next Stage Load Well 0 798 88 0 2793 17 17:15:15 Other Switching to Mag Meter 16.83 5832 5952 15.1 4211 2 17:19:46 Next Stage Pad 84.84 4540 4627 15.3 4073 18 17:21:55 Alarm Delta Stage At Top Perf = 1 130.33 5874 5985 23.9 4214 19 17:25:31 Alarm Delta Stage At Top Perf = 2 215.29 5172 5280 23.5 4162 20 17:29:15 ISIP ISIP 295.82 1300 324 0 3652 3 17:36:36 Next Stage Flush 384.88 4683 4777 23.2 4109 4 17:41:52 Next Stage Flush 505.57 10 98 0 4077 21 17:42:03 ISIP ISIP 505.57 1078 23 0 3667 5 17:57:28 Next Stage Shut-In for FET Analysis 505.57 1057 9 0 3556 6 17:59:27 Next Stage Conditioning Pad 509.65 4085 4198 21.2 4131 22 17:59:42 Alarm Delta Stage At Top Perf = 3 515.29 4077 4166 22.9 4109 23 18:04:32 Alarm Delta Stage At Top Perf = 5 637.22 4709 4815 25.2 4092 24 18:04:39 Alarm Delta Stage At Top Perf = 6 640.16 4729 4843 25.3 4092 7 18:23:04 Next Stage 1.00 Wanli -20/40 1104.38 5096 5192 25.2 4021 8 18:28:13 Next Stage 2.00 Wanli -20/40 1233.17 4996 5107 25.1 3979 25 18:28:15 Alarm Delta Stage At Top Perf = 7 1234.44 4997 5105 25.1 3978 26 18:33:24 Alarm Delta Stage At Top Perf = 8 1363.5 5143 5261 25 3924 9 18:37:42 Next Stage 3.00 Wanli -20/40 1471.13 5220 5339 25 3910 27 18:42:54 Alarm Delta Stage At Top Perf = 9 1601.08 5598 5734 25 3905 10 18:48:29 Next Stage 3.50 Wanli -20/40 1740.23 5615 5738 24.9 3899 28 18:53:42 Alarm Delta Stage At Top Perf = 10 1870.2 5954 6079 24.8 3902 11 19:02:51 Next Stage 5.00 Wanli -20/40 2097.94 6154 6289 24.9 3923 29 19:08:06 Alarm Delta Stage At Top Perf = 11 2228.43 6625 6758 24.8 3942 12 19:13:12 Next Stage 6.00 Wanli -20/40 2354.39 6636 6772 24.8 3967 13 19:16:30 Next Stage Flush 2435.15 6692 6841 24.5 3972 30 19:18:31 Alarm Delta Stage At Top Perf = 12 2484.76 6352 6474 24.9 4000 14 19:20:48 Next Stage Freeze Protect 2540.88 5282 5391 25.3 3975 31 19:21:49 ISIP ISIP 2560.46 1786 31 0 3740 15 19:21:52 Next Stage Shut-In 2560.46 1381 20 0 3756 32 19:26:47 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 2560.46 1300 5 0 3601 33 19:30:36 Shut In Well Shut In Well 2560.46 1060 9 0 3561 34 19:31:48 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 2560.46 15 10 0 3552 35 19:34:47 Other Fanning Trucks Out 2560.46 20 11 0 3534 36 19:36:49 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 2560.46 21 12 0 3524 Event Log Interval 2 (1/6/2019) ConocoPhillips Alaska, Inc. - KRU 2S-315 Event List -Interval 2 45 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Test mini Frac Pad Pad 3PPG 86.6 9.80 1.00 1.00 0.50 0.50 2.00 0.50 2.00 70.2 9.90 1.00 81.1 9.70 1.00 1.00 0.50 77.3 9.60 1.00 1.00 0.50 0.50 2.00 1.00 0.50 0.50 2.00 Temp 0F PH LOSURF-300D CL-22 UC CL-31 MO-67 Optiflo-III Z. Thomas Hydration Visc:14 70.2 All chemical concentrations below are in gallons per thousand / pounds per thousand 5500 Water pH:7.10 Carin Hydration pH:7.20 KRU 2S-315 Stage(s):1 140 Water Source:CPF 2 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date:1/3/2019 ConocoPhillips Project No: 0 500 1000 1500 2000 2500 3000 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp) Time (min:sec) Zone 1 Crosslink Tests mini Frac Pad Pad 3PPG Fluid is broken at 200cp ConocoPhillips Alaska, Inc. - KRU 2S-315 Fann 15 Minute Zone 1 46 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Mini Frac Pad Pad 1ppg 3ppg 4ppg 73.5 7.15 1.00 1.00 0.40 0.50 2.00 1.00 1.00 72 7.11 1.00 1.00 0.40 72.5 7.14 1.00 1.00 0.40 0.50 2.00 0.50 2.00 1.00 71.8 7.18 1.00 1.00 0.40 0.50 2.00 1.00 1.0076.6 7.12 1.00 1.00 0.40 0.50 2.00 0.50 2.0059.9 7.14 1.00 1.00 0.40 1.00 Temp 0F PH LOSURF-300D CL-22 UC CL-31 MO-67 Optiflo-III Optiflo-II Z. Thomas Hydration Visc:20 74.4 All chemical concentrations below are in gallons per thousand / pounds per thousand 5500 Water pH:7.14 Cairn Hydration pH:7.22 KRU 2S-315 Stage(s):2 140 Water Source:CPF 2 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date:1/6/2019 ConocoPhillips Project No: 0 500 1000 1500 2000 2500 3000 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp) Time (min:sec) Zone 2 Crosslink Tests Mini Frac Pad Pad 1ppg 3ppg 4ppg Fluid is broken at 200cp ConocoPhillips Alaska, Inc. - KRU 2S-315 Fann 15 Minute Zone 2 47 Chemical Lot Number's Loaded MO-67 CY-458429 CL-22 197-18-1 CL-31 KK8J0404A0 Lo-Surf 300D N/A M010516-11Z M091317-21Z M032918-31M G04018-210 G040318-11P G040418-31Q SP Breaker 2094378 WG-36 4/21/2018 OptiFlow-III OptiFlow-II ConocoPhillips Alaska, Inc. - KRU 2S-315 Chemical Lot Numbers Page 48 Laboratory Project ID Number: Customer: Well Name & Number: Fluid System: Date: Technician(s) Performing Testing: Reviewed & Approved By: Summary of Testing and Results First 10 minutes at 511 1/sec After 10 minutes the shear rate was decreased to 100 1/sec Field additive samples SL#947b, e and SL#961a, c ,e, f, g, h Prudhoe Bay Field Laboratory - Rockies NWA Hybor G January 1, 2019 Water SL#974 2065926-2 ConocoPhillips KRU 2S-315 Amanda Morrison Customer:Fluid System:Bob Type: Well Name:Water Source:Shear Rate (1/sec): Date:BHST (oF):Lab Project ID:2065926-2 Lot #Units ppt 2500 gpt ppt Chloride (ppm)23660 gpt 0 ppt >1200 ppt Ions tested using Strips in Lab pH 6.55 ppt Specific Gravity 1.028 ppt 75.00 ppt Test No: Water pH Min.Viscosity (cP)Temp. (oF): Base Gel (#)1 10.0 75 Base Gel Visc (cP)2 14.0 75 Base Gel pH 3 16.0 75 Base Gel Temp. (oF)4 17.0 75 Buffered pH 5 17.0 75 Crosslink pH 10 19 75 Final pH MO-67 CL31 CL-22 SP Breaker 0.25 0.45 0.25 0.500.25 2.00 Chemical Water Analysis Sample ID: SL#974 Optiflo III Optiflo II LoSurf 300D WG-36 2.00 1.00 JOB INFORMATION AND TESTING CONDITIONS Seawater 4 Total Hardness (ppm) 3 0.15 ConocoPhillips 0.15BE-6 1.00 0.15 25.0025.00 0.90 0.45 25.00 0.75 0.75 1.00 January 1, 2019 511 / 100 25.00 KRU 2S-315 Test No:5 140 Chemical Concentrations FLUID DESIGN 0.15 0.90 0.45 0.75 0.00 0.75 0.90 Gel Hydration (511/s) *calculated values 7.55 19.0 6 140 1:06 Test Temp. (oF) 1:311:14 BREAK TEST CHART 140 5:00+ FLUID PROPERTIES 0 19.0 9.75 9.81 6.55 7.55 7.90 25.00 7.83 75 8.62 7.54 9.82 75 9.73 6.55 19.0 4 9.75 6.55 19.0 25.00 9.85 3 Test Notes: Break Time (hr:min) 5 9.80 7.46 75 75 6.55 9.81 0.90 0.45 0.00 0.25 Iron (mg/L) 120 Sulfate (mg/L) B5Hybor G 0 8.02 140 140 1.00 Alkalinity (ppm as CaCO3) 6 Temperature (oF) 25.00 25.00 0.00 0.00 2.00 0 20 40 60 80 100 120 140 160 0 100 200 300 400 500 600 700 800 0:00 1:12 2:24 3:36 4:48 6:00Viscosity, cP/Shear Rate, s-1 Time, h:mm Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Temperature Temperature Temperature Temperature Temperature Temperature Laboratory Project ID Number: Customer: Well Name & Number: Fluid System: Date: Technician(s) Performing Testing: Reviewed & Approved By: Summary of Testing and Results First 10 minutes at 511 1/sec After 10 minutes the shear rate was decreased to 100 1/sec Field additive samples SL#947b, e and SL#961a, c ,e, f, g, h Prudhoe Bay Field Laboratory - Rockies NWA Hybor G January 3, 2019 Water SL#980 2065926-5 ConocoPhillips KRU 2S-315 Amanda Morrison Customer:Fluid System:Bob Type: Well Name:Water Source:Shear Rate (1/sec): Date:BHST (oF):Lab Project ID:2065926-5 Lot #Units ppt 4250 gpt ppt Chloride (ppm)20210 gpt 0 ppt >1200 ppt Ions tested using Strips in Lab pH 6.72 ppt Specific Gravity 1.027 ppt 75.00 ppt Test No: Water pH Min.Viscosity (cP)Temp. (oF): Base Gel (#) Base Gel Visc (cP) Base Gel pH Base Gel Temp. (oF) Buffered pH Crosslink pH Final pH MO-67 CL31 CL-22 SP Breaker 0.25 0.50 0.00 0.000.00 0.00 Chemical Water Analysis Sample ID: SL#980 Optiflo III Optiflo II LoSurf 300D WG-36 2.00 1.00 JOB INFORMATION AND TESTING CONDITIONS Seawater 2 Total Hardness (ppm) 1 0.15 ConocoPhillips 0.15BE-6 1.00 0.15 25.0025.00 1.00 0.50 25.00 1.00 1.00 1.00 January 3, 2019 511 / 100 25.00 KRU 2S-315 Test No:3 140 Chemical Concentrations FLUID DESIGN 0.15 1.00 0.50 1.00 0.25 1.00 1.00 Gel Hydration (511/s) *calculated values 4 140 1:30 Test Temp. (oF) 1:56 BREAK TEST CHART 140 FLUID PROPERTIES 0 8.01 25.00 7.32 9.859.85 6.72 19.0 2 19.0 25.00 9.96 1 Test Notes: Break Time (hr:min) 3 9.96 7.32 75 75 6.72 1.00 0.50 0.50 0.25 Iron (mg/L) 400 Sulfate (mg/L) B5Hybor G 0 8.18 1.00 Alkalinity (ppm as CaCO3) 4 Temperature (oF)0.25 2.00 2.00 0 20 40 60 80 100 120 140 160 0 100 200 300 400 500 600 700 0:00 0:14 0:28 0:43 0:57 1:12 1:26 1:40 1:55 2:09 2:24Viscosity, cP/Shear Rate, s-1 Time, h:mm Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Temperature Temperature Temperature Temperature Temperature Temperature Laboratory Project ID Number: Customer: Well Name & Number: Fluid System: Date: Technician(s) Performing Testing: Reviewed & Approved By: Amanda Morrison 2065926-4 ConocoPhillips KRU 2S-315 Water SL#980 January 2, 2019 Hybor G Prudhoe Bay Field Laboratory - Rockies NWA Field additive samples SL#947b, e and SL#961a, c ,e, f, g, h First 10 minutes at 511 1/sec After 10 minutes the shear rate was decreased to 100 1/sec Summary of Testing and Results Customer:Fluid System:Bob Type: Well Name:Water Source:Shear Rate (1/sec): Date:BHST (oF):Lab Project ID:2065926-4 Lot #Units ppt 4250 gpt ppt Chloride (ppm)20210 gpt 0 ppt >1200 ppt Ions tested using Strips in Lab pH 6.72 ppt Specific Gravity 1.027 ppt 75.00 ppt Test No: Water pH Min.Viscosity (cP)Temp. (oF): Base Gel (#)1 15.0 75 Base Gel Visc (cP)2 17.0 75 Base Gel pH 3 20.0 75 Base Gel Temp. (oF)4 22.0 75 Buffered pH 5 23.0 75 Crosslink pH 10 27 75 Final pH 30.00 0.25 2.00 2.00 Temperature (oF) 4 1.00 Alkalinity (ppm as CaCO3) 0 8.06 140 140 B5Hybor G Iron (mg/L) 400 Sulfate (mg/L)1.00 0.50 0.50 0.25 9.91 7.73 75 75 6.72 9.98 1 Test Notes: Break Time (hr:min) 3 75 9.89 6.72 27.0 2 9.82 6.72 27.0 30.00 30.00 9.91 8.22 30.00 8.02 75 8.03 7.73 9.89 27.0 9.87 9.95 6.72 7.50 FLUID PROPERTIES 0 2:18 140 1:445:00+ BREAK TEST CHART 140 3:55 Test Temp. (oF) 27.0 4 7.81 Gel Hydration (511/s) *calculated values 1.00 0.50 1.00 0.25 1.00 1.00 Test No:3 140 Chemical Concentrations FLUID DESIGN 0.15 1.00 January 2, 2019 511 / 100 30.00 KRU 2S-315 30.00 1.00 0.50 30.00 1.00 1.00 1.00 0.15 30.00 ConocoPhillips 0.15BE-6 0.15 1.00 JOB INFORMATION AND TESTING CONDITIONS Seawater 2 Total Hardness (ppm) 1 Chemical Water Analysis Sample ID: SL#980 Optiflo III Optiflo II LoSurf 300D WG-36 2.000.00 MO-67 CL31 CL-22 SP Breaker 0.25 0.50 0.00 0.000.00 0 20 40 60 80 100 120 140 160 0 100 200 300 400 500 600 700 800 900 1000 0:00 1:12 2:24 3:36 4:48 6:00Viscosity, cP/Shear Rate, s-1 Time, h:mm Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Temperature Temperature Temperature Temperature Temperature Temperature Laboratory Project ID Number: Customer: Well Name & Number: Fluid System: Date: Technician(s) Performing Testing: Reviewed & Approved By: Summary of Testing and Results First 10 minutes at 511 1/sec After 10 minutes the shear rate was decreased to 100 1/sec Field additive samples SL#947b, e SL#961 g, h SL#982 a,b,c,d Prudhoe Bay Field Laboratory - Rockies NWA Hybor G January 5, 2019 Water SL#981 2066010-1 ConocoPhillips KRU 2S-315 Amanda Morrison Customer:Fluid System:Bob Type: Well Name:Water Source:Shear Rate (1/sec): Date:BHST (oF):Lab Project ID:2066010-1 Lot #Units ppt 12500 gpt ppt Chloride (ppm)20210 gpt 0 ppt >1200 ppt Ions tested using Strips in Lab pH 6.87 ppt Specific Gravity 1.028 ppt 75.00 ppt Test No: Water pH Min.Viscosity (cP)Temp. (oF): Base Gel (#)1 13.0 75 Base Gel Visc (cP)2 16.0 75 Base Gel pH 3 17.0 75 Base Gel Temp. (oF)4 18.0 75 Buffered pH 5 19.0 75 Crosslink pH 10 20 75 Final pH MO-67 CL31 CL-22 SP Breaker 0.25 0.40 0.00 0.000.00 0.00 Chemical Water Analysis Sample ID: SL#980 Optiflo III Optiflo II LoSurf 300D WG-36 2.00 1.00 JOB INFORMATION AND TESTING CONDITIONS Seawater 2 Total Hardness (ppm) 1 0.15 ConocoPhillips 0.15BE-6 1.00 0.15 25.0025.00 1.00 0.40 25.00 0.50 0.50 1.00 January 5, 2019 511 / 100 25.00 KRU 2S-315 Test No:3 140 Chemical Concentrations FLUID DESIGN 0.15 1.00 0.40 0.50 0.25 0.50 1.00 Gel Hydration (511/s) *calculated values 7.65 20.0 4 140 2:30 Test Temp. (oF) 1:463:49 BREAK TEST CHART 140 2:20 FLUID PROPERTIES 0 20.0 9.81 9.88 6.87 7.58 8.18 25.00 8.45 75 8.31 7.53 9.779.77 6.87 20.0 2 9.84 6.87 20.0 25.00 25.00 9.82 1 Test Notes: Break Time (hr:min) 3 75 9.82 7.53 75 75 6.87 9.90 1.00 0.40 0.50 0.25 Iron (mg/L) 400 Sulfate (mg/L) B5Hybor G 0 8.33 140 140 1.00 Alkalinity (ppm as CaCO3) 4 Temperature (oF) 25.00 0.25 2.00 2.00 0 20 40 60 80 100 120 140 160 0 100 200 300 400 500 600 700 0:00 0:28 0:57 1:26 1:55 2:24 2:52 3:21 3:50 4:19 4:48Viscosity, cP/Shear Rate, s-1 Time, h:mm Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Temperature Temperature Temperature Temperature Temperature Temperature
