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218-095
DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180950 Well Name/No. HANSEN H -16A Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-01-00 MD 22310 TVD 7031 Completion Date 12/14/2018 REQUIRED INFORMATION Mud Log X16 Completion Status 1 -OIL Samples Tlo" 1 Current Status 1 -OIL UIC No Directional Survey Yes V / DATA INFORMATION List of Logs Obtained: GR/RES/DEN/NEU, Mudlogs (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop P CH Received Comments ED C 30245 Digital Data _ 14626 22274 1/15/2019 Electronic Data Set, Filename: BlueCrest_H16A_EcoScope Images_RM_LAS.Ias ED C 30245 Digital Data 14519 22310 1/15/2019 Electronic Data Set, Filename: BlueCrest_H 16A_EcoScope_RM_LAS.las ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A_EcoScope Images — RM — DLIS.dlis ED C 30245 Digital Data 1/15/2019 ElectroniFil: BlueCrest_H16A_EcoScope Images —RM _DLIS.html ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A_EcoScope_RM_DLIS.dlis ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A_EcoScope_RM_DLIS.html ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H 16A_EcoScope_2in_RM_InvertT VD. Pdf ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H 16A_EcoScope_2in_RM_MD.Pdf ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A_EcoScope_5in_RM_InvertTVD. Pdf ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H 16A_EcoScope_5in_RM_MD. Pdf ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H 16A_EcoScope_I mage_5in_RM_MD .Pdf AOGCC Page 1 of 7 Friday, April 5, 2019 AOGCC Page 2 of 7 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180950 Well Name/No. HANSEN H -16A Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051.01-00 MD 22310 TVD 7031 Completion Date 12/14/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A_DD Surveys_Final.pdf ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A_DD Surveys_Final.xlsx ED C 30245 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A_Final Surveys.csv Log C 30245 Log Header Scans 0 0 2180950 HANSEN H -16A LOG HEADERS ED C 30245 Digital Data 0 0 Electronic File: H16A ASP Final Survey.xlsx ED C 30245 Digital Data 0 0 Electronic File: H16A ASP Final Survey.pdf ED C 30543 Digital Data 14450 22350 4/3/2019 �x Electronic Data Set, Filename: H16A MAIN.Ias_ MN` U ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Reports 11-18-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-19-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-20-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-21-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-22-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-23-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-24-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-25-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-26-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-27-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-28-18.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-29-18.pdf AOGCC Page 2 of 7 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180950 Well Name/No. HANSEN H -16A MD 22310 TVD 7031 Completion Date 12/14/2018 ED C 30543 Digital Data ED C 30543 Digital Data ED C 30543 Digital Data ED C 30543 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data 30543 Digital Data Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-01-00 Completion Status 1 -OIL Current Status 1-0I1. UIC No 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-30-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-1-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-10-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-11-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-12-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-13-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-2-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-3-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-0-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-5-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-6-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-7-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-8-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 12-9-18.pdf 4/3/2019 Electronic File: H16A-Main.dbf 4/3/2019 Electronic File: H16A-Main.mdx 4/3/2019 Electronic File: H16A-Main_SCL.DBF 4/3/2019 Electronic File: H16A-Main_SCL.MDX 4/3/2019 Electronic File: H16A-MAIN TVD.DBF 4/3/2019 Electronic File: H16A-MAIN TVD.mdx AOGCC Page 3 of 7 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/512019 Permit to Drill MD 22310 2180950 Well Name/No. HANSEN H -16A TVD 7031 Completion Date 12/14/2018 Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-01-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30543 Digital Data 4/3/2019 Electronic File: BLUE CREST ENERGY H -16A FINAL REPORT.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A-MAIN - Drilling Dynamics Log MD.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A-MAIN - Formation Log MD.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A-MAIN - Gas Ratio Log MD.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A-MAIN - LWD Combo Log MD.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A-MAIN - Drilling Dynamics Log MD.tif ED C 30543 Digital Data 4/3/2019 Electronic File: H16A-MAIN - Formation Log MD.tif ED C 30543 Digital Data 4/3/2019 Electronic File: H16A-MAIN - Gas Ratio Log MD.tif ED C 30543 Digital Data 4/3/2019 Electronic File: H16A-MAIN - LWD Combo Log MD.tif ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 1 14715- 15087 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 1 14715- 15087 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 10 18055- 18240 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 10 18055- 18240 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 11 19270- 19790 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 11 19270- 19790 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 12 19835- 20190 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 12 19835- 20190 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 13 20460- 20815 page 1.pdf AOGCC Page 4 of 7 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180950 Well Name/No. HANSEN H -16A Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-01-00 MD 22310 TVD 7031 Completion Date 12/14/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 13 20460- IED 20815 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 14 20460- 20815 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 14 20460- 20815 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 15 21195- 21540 page t.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 15 21195- 21540 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 16 21600- 21850 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 16 21600- 21850 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 17 22000- 22124 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 17 22000- 22124 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 2 15170- 15300 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 2 15170. 15300 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 3 15440- 15725 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 3 15440- 15725 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 4 15800- 16010 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 4 15800- 16010 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 5 16060- 6060.16234 16234page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 5 16060- 16234 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 6 16870- 17077 page 1.pdf AOGCC Page 5 of 7 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180950 Well Name/No. HANSEN H -16A Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-01-00 MD 22310 TVD 7031 Completion Date 12/14/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 6 16870- Name Start Stop 17077 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 7 17095- INFORMATION RECEIVED Completion Report O Directional / Inclination Data YD Mud Logs, Image Files, Digital Data Y& 17270 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 7 17095- YO Daily Operations Summary I Y , Cuttings Samples /-Y. Laboratory Analyses Y /ZA 17270 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 8 17300- 17725 page t.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 8 17300- 17725 page 2.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 9 17755- 18005 page 1.pdf ED C 30543 Digital Data 4/3/2019 Electronic File: H16A Show Report 9 17755- 18005 page 2.pdf Log C 30543 Log Header Scans 0 0 2180950 HANSEN H -16A LOG HEADERS Well Cores/Samples Information COMPLIANCE HISTORY Completion Date: 12/14/2018 Release Date: 9/13/2018 Description Date Comments AOGCC Page 6 of 7 Friday, April 5, 2019 Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings 14580 22310 11/26/2018 1680 INFORMATION RECEIVED Completion Report O Directional / Inclination Data YD Mud Logs, Image Files, Digital Data Y& Core Chips Y / CA) Production Test Information YMechanical Integrity Test Information Yom/ NA Composite Logs, Image, Data Files�Y Core Photographs Y/ A Geologic Markersfrops YO Daily Operations Summary I Y , Cuttings Samples /-Y. Laboratory Analyses Y /ZA COMPLIANCE HISTORY Completion Date: 12/14/2018 Release Date: 9/13/2018 Description Date Comments AOGCC Page 6 of 7 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180950 Well Name/No. HANSEN H -16A MD 22310 TVD 7031 Completion Date 12/14/2018 Comments: Compliance Reviewed By: Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-01-00 Completion Status 1-0I1 Current Status 1-0I1 UIC No a. AOGCC Page 7 of 7 Friday, April 5, 2019 ^lueCst Energy BlueCrest Alaska Operating LLC 3301 C Street, Suite 202 Anchorage, AK 99503 Tel: (907) 754-9550 Fax: (907) 677-0204 Transmittal 21 00g,5 30543 --- _ Today's Date: 4/3/2019 Transmittal #: , 2019-05 ----- ... i_ To: Ms Meredith Guhl From: Andrew Buchanan I------ ------------------ —�– .- ...- _...._ Company AOGCC Company: BlueCrest Alaska Operating LLC Re: Mud Logging Data –H16A I Well: H16A Included Information: 8 CD's with Mud Logging Data for Well H 16A. Regards Andrew Buchanan BlueCrest Energy RECEIVED APR 0 3 2019 AOOCC THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY February 7, 2019 Mr. Larry Burgess HSE Manager BlueCrest Alaska Operating LLC 3301 C Street, Suite 202 Anchorage, Alaska 99503 C Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov RE: Docket Number: CO -18-040 Request for a waiver of the gas oil ratio limitations of 20 AAC 25.240(a) for wells Hansen 16A (PTD 218-095) and Hansen lA (PTD 203-004) Dear Mr. Burgess: By letters dated December 10, 2018, BlueCrest Alaska Operating LLC (BlueCrest) requested waivers through November 1, 2019, of the gas -oil ratio limitations in 20 AAC 25.240(a). The basis for the request is to allow long term testing of the Hansen 16A well (Hansen 16A) (PTD 218-0951) and Hansen IA well (Hansen IA) (PTD 203-0042) in the Cosmopolitan Unit to acquire reservoir performance data to help determine the potential for additional reservoir development. BlueCrest's request is granted under the conditions below. The Hansen 16 was drilled in November 2016, completed in March 2017, and plugged for redrill in October 2018. Like the recently drilled Hansen 12 well the Hansen 16A will have a motherbore and multiple laterals to maximize the amount of the formation contacted by the well. The Hansen 16A has not been drilled yet, but the well and its laterals have been permitted by the Alaska Oil and Gas Conservation Commission. The Hansen I well was the subject of a previous GOR waiver that was issued on July 18, 2016, and valid for a period of 2 years. During this two-year test period the well loaded up with asphaltenes and it was not feasible to restore the well to production so the well was shut in in September 2017. Unexpectedly when pressure was bled from the Hansen IA well in order to remove the wellhead for a rig move, reservoir fluids reached the surface. BlueCrest flowed the well for a short period of time (September 25 to October 1, 2018) before shutting in the well for the planned Hansen 16A drilling program. Once drilling of Hansen 16A is complete and the rig is moved off to the next well BlueCrest would like to return the Hansen IA well to production and resume gathering reservoir performance data. BlueCrest plans to drill additional wells from its onshore production In addition to the main wellbore the Hansen 16A will also contain seven laterals. The permit to drill numbers for these laterals will be 218-096, 218-097, 218-098, 218-099, 218-100, 218-101, and 218-102. 3 Hansen I has a single lateral with permit to drill number 207-079. SCANNED FEB 1 1 2019 Mr. Larry Burgess February 7, 2019 Page 2 of 2 facility to further develop the field. The GOR waiver for the Hansen 16A and Hansen I is to allow B1ueCrest to gather additional information about reservoir performance to help evaluate future development options, including the potential for the initiation of an enhanced oil recovery project. Existing GOR waivers for the purpose of gathering reservoir performance data for the Cosmopolitan field expire on November 1, 2019, so it is appropriate that the GOR waivers for these two wells expire at the same time. In accordance with 20 AAC 25.240(b)(3) BlueCrest's request is granted on the following conditions: 1) The Hansen 16A and Hansen 1A wells must be tested in accordance with 20 AAC 25.230 and tested at least twice per month while flowing. 2) The GOR waiver expires on November 1, 2019. 3) On a quarterly basis, the operator must submit copies of all well tests for the Hansen 16A and Hansen 1 A wells showing the GOR at the time of the test. 4) Prior to November 1, 2019, the operator must meet with the AOGCC to discuss results during this test period and future development plans for the Cosmopolitan Unit. DONE at Anchorage, Alaska and dated February 7, 2019. Daniel T. Se ount, Jr. Commissioner Cath P. Foerster Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. (this language was removed from the statute a few years ago) In computing a period of time above, the date of the event or default after which the designated period begins to ran is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. IlueBlueCrest Alaska Operating LLC Est 3301 C Street, Suite 202 / Eneir$y Anchorage, AK 99503 December 10, 2018 E !VED Catherine Foerster DEC 10 2018 Commissioner 333 W 7th Ave, Ste 100 Anchorage, Alaska 99501 Dear Mrs. Foerster, In accordance with 20 AAC 25.240.B.3, BlueCrest Alaska Operating LLC (BlueCrest), as operator of the Cosmopolitan Unit and sole working interest owner of ADLs 384403, 391902, 391903, 391904, and 18790, hereby requests a waiver of the gas oil ratio limitations for Well Hansen 16A (PTD 218-096, 218- 097, 218-098, 218-099, 218-100, 218-101, and 218-102) for a reservoir evaluation through November 2019 (the expiration of H14 GOR waiver) to acquire reservoir performance (gas, oil, and water trends) and pressure data to help determine the potential for additional reservoir development. The laterals of H16A are being drilled shallower in structure than the previous multi lateral (1-112) in an attempt to reduce the GOR and assess how fast the gas might cone down through the stratigraphic layers in the reservoir. During this period, production of fluids from the Hansen 16A well will be produced through the Bluecrest Cosmo facility and commingled at the surface. Well Hansen16A will be periodically tested with a portable well test separator for readings of the liquid and gas production. Prior to November 1, 2019 BlueCrest will meet with the commission to discuss the appropriate way forward for this well. Should you have any questions, please contact Alecia Wood, Production Engineer at 907-394-2485. Sincerely, Larry Burgess Alaska Manager BlueCrest Alaska Operating LLC ]lluNst 3301CStreet, Suite 202 Energy Anchorage, AK 99503 December 10, 2018 Catherine Foerster DEC 1 Commissioner AOGCC 333 W 7th Ave, Ste 100 Anchorage, Alaska 99501 Dear Mrs. Foerster, AOGCC. In accordance with 20 AAC 25.240.13.3, BlueCrest Alaska Operating LLC (BlueCrest), as operator of the Cosmopolitan Unit and sole working interest owner of ADLs 384403, 391902, 391903, 391904, and 18790, hereby requests a waiver of the gas oil ratio limitations for Well Hansen #1A (PTD 203-004) for a continued reservoir evaluation program through November 2019 (the expiration of H14 GOR waiver) to acquire reservoir performance (gas, oil, and water trends) and pressure data to help determine the potential for additional reservoir development. A GOR waiver was granted on July 18, 2016 for a period of two years expiring on June 1, 2018. During this two year time frame the well loaded up with asphaltenes and was unable to be restored to production as of September 2017. After discussions with Dave Roby the waiver was allowed to expire as the well was uneconomic to return to production. While bleeding the well in preparation to remove the tree for an upcoming rig move fluid reached the surface. Dave Roby and Jim Regg were notified, the well was brought online, the SVS tested, and the well was flowed from September 25th through October V 2018 before being shut in due to proximity to an upcoming side track of H16. After the rig is moved onto the next well (1-104) we would like to return HS to production under a new GOR waiver. During this period, production of fluids from the Hansen#1A well will be produced through the Bluecrest Cosmo facility and commingled at the surface. Well Hansen#1A will be periodically tested with a portable well test separator for readings of the liquid and gas production. Prior to November 1, 2019 BlueCrest will meet with the commission to discuss the appropriate way forward for this well. Should you have any questions, please contact Alecia Wood, Production Engineer at 907-394-2485. Sincerely, Larry urges Alaska Manager Schlumberger Drilling & Measurements Product Delivery Customer BlueCrest Energy, LLC Dispatched To: Well No H16A Date Dispatched: 21 8095 50245 Transmittal #: 14JAN19-SP01 AOGCC: Abby Bell 14 -Jan -19 Service Order # 18AKA0052 Dispatched By: Stephanie Pacillo Product Description Harccopy Digital Copy Lo in Date Color Log Prints: N/A Contents on CD 22 -Nov -18 EcoScope' 5" MD N/A x 2" MD N/A x 5" Invert TVD N/A x 2" Invert TVD N/A x 5 EcoScope Image N/A JPO x Digital Data Contents on CD Recorded Mode DLIS / LAS Data P x G P� Survey NIA Contents on CD Directional Survey Nad27 x EOW CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Survey: XLS/PDF x Please sign and email a copy to: Please sign and email a copy to: abuchanan(a)bluecrestenergy.com AlaskaPTSPrintCenter(a)slb.com Attn: Andrew Buchanan Attn: Stephanie PaciHo Received By: Min �Ii I IECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION J WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil F41 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 2oAAC25.105 20AAC25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: BlueCrest Alaska Operating LLC Comp: 12/14/2018 218.095 3. Address: 3301 "C" Street, Suite 202, Anchorage, AK 99503 7. Date Spudded: 10/1 j2018 15. API Number: , 50-231.20051.01.00 4a. Location of Well (Governmental Section): H16A MAINBORE 8. Date TO Reached: 16. Well Name and Number: Surface: 2408' FSL, 1509' FEL, Sec 2, T4S, R15W, SM 11/18/2018 1416A r Top of Productive Interval: 9. Ref Elevations: KB: 180.25' 17. Field / Pool(s): 2663' FSL, 1350' FEL, Sec 33, T3S, R15W, SM GLA45.81 RKB:180.4 Hansen,Undefined Cosmopolitan Oil Total Depth: 1685' FSL, 2505' FEL, Sec 29, T3S, R15W, SM 10. Plug Back Depth MD/TVD: 22310' MD / 7031' TVD 18. Property Degignation: 1 Fee Hansen,ADL18790,ADL 384403 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 168861.855 y- 2144856.07 Zone- 4 22310' MD / 7031' TVD LOCI 14-007 TPI: x- 158612.43 y- 2150676.24 Zone- 4 12. SSSV Depth MDfTVD: 20. Thickness of Permafrost MDfrVD: Total Depth: x- 152294.39 y- 2155159.54 Zone- 4 543' MD / 542' TVD N/A 5. Directional or Inclination Survey: Yes L4J (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 1 N/A (ft MSL) 14,538' MD Window Top in 9-5/8" 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 ALL LOGS WERE SLB LWD: GR-Res--Den-Neu-PWD Final Mudlogging Report / Mud Log / Lithology Log (Nabors-CanRig) 21L' 3S Formation Log / LWD Combo Log / Gas Ratio Log / Drilling Dynamics LogA3 i8 23. CASING, LINER AND CEMENTING RECORD CASING WT' PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 20 0.500" wall A525 41 187 41 187 Driven N/A - Rotary Drilled/Driven N/A 13.375 72 L-80 40.5 4177 40.5 3175 17.5" 588 bbls Lead / 198 bbis Tail WA 9.625 47 P-110 40.6 13161 40.6 6688 12.25" N/A NIA 9.625 53.5 P-110 13161 14767 6688 7083 12.25" 178 bbls 15.8 ppg G -Tail N/A 4.5 15.2 P-110 14381 21510 7070 7068 8.5" Slotted Liner - no cement N/A 3.5 9.3 L80 26.4614435 26.46 7076 N/A Production Tubing String N/A 24. Open to production or injection? Yes ❑✓ No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 40 Weil completed with 4-1/2" slotted liner in mainbore and IJd; see attached lower liner tally for set depths and details. SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 14435' MD 14381' MD / 7070' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. CONIPLETION DATE Was hydraulic fracturing used during completion? Yes L No d Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED N/A N/A 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Press. Casinq Press: I Calculated 124 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corn): Form 10-407 Revised 5/2017 f ��'��9 CONT U D ON PAGE 2 Submit ORIGINIAL o ILI o.l sarn 28. CORE DATA Conventional C�.e(s): Yes ❑ No ❑Q Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, From/ro), 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. N/A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Upper Tyonek (H16) 5047 3347 Lower Tyonek (1-116) 12134 6096 Attach separate pages to this form, if needed, and submit detailed test Starichkof (1-116) 14453 6898 information, including reports, per 20 AAC 25.071. Hemlock 16605 7077 Hemlock (toe) 21720 7068 Well Test to be /. Top o1 Pybo(Mfrr 14552 ?065 covered in a subsequent /A& 10-407 See attached Table for all Formation Tops for each Lateral 1-01-1-07 Formation tops above are for the H16A Mainbore Formation at total depth: Hemlock 31. List of Attachments: Operations Summary, Actual Wellbore Diagram, List of Formation Tops, Mud Wt vs. Depth Data, Final Definitive Directional Surveys, Slotted Liner String Tally (4-1/2"), Tubing String Tally (3-1/2"), Wellhead & Tree Schematic, Pressure Test Results Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Larry Burgess Contact Name: Tom McKay Authorized Title: Alaska Manager Contact Email tom.mckavm@t uecrestenerov.com Authorized /%9` '�,(jContact Phone: 907-754-9566 ,(� 7, 011 Signature: r Date: V L v,I r `r INSTRUCTIONS 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-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 lue est Energy 3301 C Street, Suite 202, Anchorage, AK 99503 Thomas McKay, PE Phone: (907) 754-9566 Email: tom.mckay@bluecrestenergy.com January 9, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Cosmopolitan Project RE: Well Completion Report Form 10-407: Horizontal / Multilateral "Fishbone" Production Well H16A PTD No. 218-095 API No. 50-231-20051-01-00 Dear Commissioners, BlueCrest Alaska Operating LLC hereby submits a completed Form 10-407 Well Completion Report with Attachments for the onshore horizontal / multilateral production well H16A. This well was sidetracked, drilled, and completed using BlueCrest Rig #1. The well is currently undergoing an extended flow test on gas lift after installing the 4-1/2" slotted liner completion. Note that the flow test results, etc., as per AOGCC request, will be covered under a subsequent 10-407 package, along with other required well production tests and reports. Please find attached for the review of the Commission, the completed Form 10-407, and the information required by 20 ACC 25.070 for this wellbore, covering the sidetracking, drilling, and completion of the "fishbone" multilateral, and the running of the upper 3-1/2" tubing string. If you have any questions or require further information, please do not hesitate to contact Tom McKay at 907-754-9566 (office phone). Sincerely, Larry Burgess Alaska Manager BlueCrest Energy Alaska Formation Tops X Y Z MD TVD H16A Hemlock 156984.01 2151923.68 -6896.49 16605 7076.92 H16A Hemlock 152764.05 2154807.92 -6887.87 21720 7068.3 H16A-LOI none H16A-LO2 Hemlock 155887.24 2152665.21 -6755.34 17944 6935.77 H36A-11.03 Hemlock 155158.83 2153186.22 -6691.86 18851 6872.29 H16A-LO4 Hemlock 154480.46 2153630.53 -6687.77 19660.15 6868.2 H16A-LO5 Hemlock 153878.37 2154053.2 -6705.58 20396.49 6886.01 H16A-LO6 Hemlock 153397 2154395.54 -6776.29 20974 6956.72 H16A-LO7 Hemlock 152985.49 2154666.24 -6849.88 21459.92 7030.31 T. McKay, 31Dec2018 20" Conductor @ 187' BGL 13-3/8" 72# L80 BTC @ 4177' MD 3-Y2" 9.2# ELIE 8RD Production Tubing 4-Yz" x 9-5/8" Liner Hanger & Liner Top Packer H16A Lower Lateral ACTUAL Completion with Slotted Liner in Mainbore and Seven (7) Open Hole Fishbone Ribs NOTE: Well was sidetracked off a whipstock set at 14538' MD top of window in the 9-5/8" casing 9-5/8" 47.0/53.5# P110 H563 @ 14767' MD lu e)epst Energy Fishbone ribs are 8-Yz" open holes spaced approx every 800' with 4-Y2" slotted liner run in the mainbore after the seven ribs are drilled; ribs are drilled in order from L01 to L07 using open hole sidetracks to initiate each rib; ribs penetrate all layers of Starichkof and Hemlock pay sands LO1 L02 L03 L04 LOS L06 L07 4-%" 15.2# H563 Slotted Liner @ 21,510' MD 40 lue est Energy Cosmopolitan Project Wellhead/Tree I I I 'Yi.bG l� I I I 1 I �\ f SWI" L 6 5 P51 WlJGai S1A1 PItl.P L -M 631' uss' s,uSG P51 t U16' 5.90E PL MSP SL16' S,9W I51 MSP _14 � uur sam Pu I . I i I Y!'Qfi MGM L6M' i�� � � 1.1SM'SQ09PSI I—MAMANDRU MX+EM i � IA56' i i i i i i i i ® L -INT , aL i`.. Gf OILGN 4LLK" 115T[P 21 1 15-L161 9.616 1 .-I /7 014.1/11 W fLR 15111'00 CSG– - I - 'I�T L'3=.1i EI6 MI rPTICAL •NW:LM 95Po'00 W— -- L 112. 00 10-401 APD Attachments Wellhead/Tree 9 5/8" Casing Integrity Test (CIT) 10/14/2018 Blue Crest Alaska Operating, LLC 9 5/8" Casing 11.'east Cosmopolitan Project 14543'MD 7084.4'TVD Energy Hansen H16A Pumped Recovered 11111111M 13.6 bbls 13.5 bbls 5000 ------ --- --- --- - —- --- - - --- - - --- - -- -- --- --- ------------------------ --- - - - - - - --- - --- --- --- 4500 1 -----------. ---- --- ---- --- --- --- --- --- ---- 1--- __-_ ___ ___ ___ ___ ___ ___ N 4000 1--- --- --- --- 60 0 L.. _ .. -- --- --- --- - ------ --- ---- --- --- ------ --- --- --- --- --- --- ---- 3500 --- --- --- - ---- --- E _ _-- --_ ___ _—_ _ -----------------------7 - - --- --- -- -- ---- -- --- --- --- -- -- 50 O 3000 --- --- --- -- - —Standpipe Pressure N_- - --- --- --- _-- - --- --- --- 0. O. 2500 —Flow In (gpm) -- - - - --- --- --- 3 E---------------------- ----- --- --- --- --- --- --- O - - - --- --- --- LL a--------------—SPM - .__.__--__-. __- -------- --_ 2000 --- 30 d -- - - -- --- --- - - - - -- --- ------- --- ---- --- --- -- a ----------------- --- --- --- -- — — ------------------------ ----------------- ---- a 1500 -- — --- --- --- --- ---- --- --- ----- --- — — --- -- -- - — — — --- --- --- --- --- -------- E 20 E --_ — — --- _-- - ---------------------------------------- p loo0 --- --- --- - - --- 1 > 2 j— --- ------- --- --- ---- --- --- --- --- --- -- --- - --- ----t--- --- --- ---------------------------------- -- --- 10 w 500 ------ --- -- -- --- 1 _. -- --- ---- --- --- --- --- — ----------------- --- ------------ - ------ - j --- - ---- ----- --- ---- ----.__. - --- -- ---- - - - 0:00 0:05 0:10 0:15 0:20 0:25 0:30 0:35 0:40 0:45 0:50 0:55 1:00 1:05 1:10 1:15 1:20 Elapsed Time (min) 3:49am to 5:05am Cummulative Volume Pumped = 13.6 bbls Total Volume Bled Back = 13.5 bbls �i1Ul NABORS runs ...... bolo 5°0 000 i �So rio 1 !Ih no 00 0 /"' �c'� MP -6000 -IHR a o $ o CHART N0. MC o S�� pFURT PUT 1D -IH gi 1j1uec est r . E+.. r Av Formation Integrity Test Blue Crest Alaska Operating, LLC Cosmopolitan Project Hansen H16A 14569' MD 10/19/2018 2000 1500 - -- — 70 60 50 - —Standpipe Pressure _Flow In (bpm) —SPM -- -- -- N C IL1000 — -- — 40 ti a — — — — a w -- 30 —20 500 i 0 zoo — — J 10 -- --- — 0 01.00 0:05 0:10 0:15 0:20 0:25 Elapsed Time (min) 2:05am to 2:29am Cummulative Volume Pumped = 7.9164 Total Volume Bled Back = 0 01 NABORS uns \o - o'ell, O J Np N O .N O pO O� n p O O O O e � 9 C o ►� o o S_ ice: 0O A. PRESSURE INTEGRITY TEST Blue Crest Well Name: H 16a Rig: Rig 7 Date: 12.07.2018 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Rowland Lawson / R. Wall Pump use #z Mud Pump Strokes 0.0924 Bbls/Strk 5.00 Strk/min Type of Test: Other - see Comments IV Pumping down annulus.1WCasing Test Pressure Integrity est Hole Size: 8-1/2" Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF:l 34.61 Ft 14380.0 TD 7050.0 Ft -TVD I 14,569' TD 17086,01TVD Strks I psi Min I psi Strks psi Min psi Casino Size and Description: 9-5/8" 40#/Ft L-80 FITC vI 01 0 01 2580 0.00 Casin Test PressureInt e rit Test 10 300 1 2580 0.25 Mud Weight:1 9.2 ppg Mud 10 min Gel: Lb/100 Ft2 Test Pressure: 2500.0 psi Rotating Weight: Lbs Blocks/Top Drive Weight: Lbs Estimates for Test: 10.4 bbls Mud Weight: 9.2 ppg Mud 10 min Gel: Lb/100 Ft2 Rotating Weight: Lbs Blocks/Top Drive Weight: Lbs Desired PIT EMW: 0.0 ppg Estimates for Test: -3373 psi 20 560 5 2540 0.50 30 850 10 2515 1.00 1.50 2.00 40 1090 20 2505 50 1370 30 " -00 60 1630 -767880 35 2.50 1 3.00 wk I V 80 2150 3.50 E W = Leak -off Pressure + Mud Weight = Go to PIT Plot.+ 9 2 0.052 x TVD 0.052 x 7050 EMW at 14380 Ft -MD 7050 Ft -TVD = #### PIT 15 Second Shut-in Pressure, psi 90 2410 4.00 961 2580 1 4.50 Fill in FIT Columns =_> 5.00 soap Lost 80 psi during test, 30 5.50 6.00 6.50 2500 7.00 7.50 8.00 2000 8.50 LU Aw 9.00 � 9.50 10.00 U) 1500 W of IL 1000 500 0 1 2 3 4 5 6 7 8 9 10 Barrels -01�CASING TEST --M--LEAK-OFF TEST 0 5 10 15 20 25 Shut -In time, Minutes 0 PIT Point Volume S Volume 5 Volume S LVolume S Comments: Test liner top packer, and casing. Pumped down ack side via kill line. Unscrewed from top drive. n Ier1 caner Hanger t asmg I est-It-ui-7tt Summary \10 w h � \ p OG 00 OO OOS Z O 00 O A r r\ o O O p O O L 0009_` __-- OOQV OS -------- -- eo Ilps 0 3.84' I N WELL 16 O W J U 0 5 la Q) L===6=mmJ ( IN FEET ) _J 1 inch = 10 it. W OF 11 ,�PqE ...is # .F s*:'49TH NOTE: i ........ ..... 1. STATE PLANE AND GEOGRAPHIC COORDINATES ARE ALASKA STATE i „ • _ �/` PLANE, ZONE 4, N.A.D.83 AND AND N.A.D.27 AS LABELED. i c:,IACOB GERONDALE:,o 2. COORDINATES ESTABLISHED FROM STATIC GPS OBSERVATIONS. �i s'•, LS -11758 3. ALL DISTANCES SHOWN ARE GROUND. iI`IFy�o,/N'I� ,•OyJ= 4. THE NGS COORDINATE CONVERSION AND TRANSFORMATION TOOL fill II ItIt„` `IO`;`���� (NCAT) WAS USED FOR NAD83(2011) TO NAD 27 CONVERSIONS. (9- AS BUILT CONDUCTOR LOCATION I 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 APRIL 21, 2016. AS BUILT SURVEY BLUECREST ENERGY WELL 16 WITHIN SECTION 2 T4S R15W S.M., AK. LOUNSBURY & ASSOCIATES, INC. Surveyors - Engineers - Planners 5300 A STREET, ANCHORAGE, ALASKA 272-5451 FIELD BOOK No.: 16-014-1 1 AS BUILT 4/21/16 GRID: ANCHOR POINT RECERT 12/11/18 4t EKE .K x N ""50 4S R15 WELL #16 SEC 2 sc y 9 ,+R, w ' R ° N.A.D.83 i /YRN RASE ° N: 2144611.05 E: 1308885.77 s LAT: 59'51'29.83"N LON: 151'48'12.84"W °r T4S R15W N.A.D.27q� SEC 1 '4 N: 2144851.95 E: 168857.79 LAT: 59'51'32.00"N LON: 151'48'05.10"W THIS SURVEY 1494' F.E.L. 2345' F.S.L. TOP OF CONDUCTOR T4S R15W SEC 11 PLANT: 100.01' VICINITY MAP I" = 1/2 MILE NAVDB8: 147.71' 3.84' I N WELL 16 O W J U 0 5 la Q) L===6=mmJ ( IN FEET ) _J 1 inch = 10 it. W OF 11 ,�PqE ...is # .F s*:'49TH NOTE: i ........ ..... 1. STATE PLANE AND GEOGRAPHIC COORDINATES ARE ALASKA STATE i „ • _ �/` PLANE, ZONE 4, N.A.D.83 AND AND N.A.D.27 AS LABELED. i c:,IACOB GERONDALE:,o 2. COORDINATES ESTABLISHED FROM STATIC GPS OBSERVATIONS. �i s'•, LS -11758 3. ALL DISTANCES SHOWN ARE GROUND. iI`IFy�o,/N'I� ,•OyJ= 4. THE NGS COORDINATE CONVERSION AND TRANSFORMATION TOOL fill II ItIt„` `IO`;`���� (NCAT) WAS USED FOR NAD83(2011) TO NAD 27 CONVERSIONS. (9- AS BUILT CONDUCTOR LOCATION I 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 APRIL 21, 2016. AS BUILT SURVEY BLUECREST ENERGY WELL 16 WITHIN SECTION 2 T4S R15W S.M., AK. LOUNSBURY & ASSOCIATES, INC. Surveyors - Engineers - Planners 5300 A STREET, ANCHORAGE, ALASKA 272-5451 FIELD BOOK No.: 16-014-1 1 AS BUILT 4/21/16 GRID: ANCHOR POINT RECERT 12/11/18 Well Name H-16 Supervisor Yoakum Objective Well Kill File: H-16 Time Operation SEP/20/2018 Operations 6:00 POLLARD ON LOCATION 6:30 TGSM, JOBSCOPE WITH CREW AND OPERATIONS 7:00 BEGIN RIG UP TO WELL. 8:15 PT 3,000 PSI, SMALL LEAK AT WELL CONECTION, FIX LEAK, PT TO 3,000 PSI - PASS. STANDBY BLEEDING DOWN TUBING. 9:45 BEGIN PUMPING DOWN TUBING. -2.25 BPM RATE AT 725 PSI. INCREASE RATE TO -3 BPM. 11:15 FINISH PUMPING 300 BBLS DOWN TUBING. TUBING ON VACUUM STANDBY BLEEDING I.A. 14:00 RIG UP I.A, PT 3,000 PSI, BEGIN PUMP DOWN I.A. 2.25 BPM RATE AT 200 PSI, INCREASE TO 3 BPM NOTE: AT -700 BBLS SLOW STEADY PRESSURE INCREASE TO 1,000 PSI @ 850 BBLS PUMPED. 20:45 FINISH PUMPING 1,000 BBLS TOTAL DOWN I.A. WAIT 10 MIN, PRESSURE DROP TO 700 21:15 RIG DOWN EQUIPMENT. 21:45 POLLARD OFF LOCATION SEP/21/2018 Operations 6:00 TUBING PRESSURE 0 WELL ON A VACUME, IA PRESSURE 235 PSI RIGGUP TO BLEED TO OPEN TOP 6:30 START BLEEDING IA 12:00 IA DOWN TO 180 PSI 3:00 IA DOWN TO 50 PSI 5:00 IA DOWN TO 10 PSI 5:40 0 PRESSURE ON IA SHUT IN AND START RIGGING DOWN TO PREP FOR TREE REMOVAL SEP/22/2018 Operations 9:00 GE ON LOCATION 9:30 TGSM, JOBSCOPE WITH CREW AND OPERATIONS 10:30 SET BPV 11:00 REMOVE TREE 13:00 SET TWO WAY CHECK 13:25 BOLT UP TREE CAP 14:00 TEST TO 5000 PSI 14:10 13:00 TEST GOOD CLEAN UP WORK AREA GE RELEASED WellViewe Well Name: H16A BC - Daily Recap Well Name ARILIWI Surface Leg el Location Licensett H16A 231-20051-01-00 2408'FSL, 1509' FEL,SEC.02T4S,R15W SM 218-095 Spud Date Rig Release Date Ground Elevation gq Ground Dema (ft) Well Subtype 10/16/2018 23:00 145.81 34.43 Fish bone Dally Operations Start Date End Date Spud Date blY Number of Rep" Total DaW of We1Wme (ftKB) 9/26/2018 22,310.00 Survey Data MD (RKB) I Ind I') A rn (y ND (i1KS) VS (fl) NS (ft) EW (a) 1 DLS (°/F Date 21,587.58 89.79 302.69 7,058.24 18,791.47 9,442.39 -10,245.95 0.46 21,681.42 90.35 303.05 x7,068.13 18,885.19 9,493.32 -16,325.76 0.71 21,774.79 1 89.901 303.32 1 7,067.93 18,97841 9.544.43 -1640391 0.56 Riga Contractor Rig Number Daily Operations RAIN Stmt Dab EM Dela Summary 1.0 9/2612018 9/27/2018 Repair annular BOP 2.0 9/27/2018 9/28/2018 skid rig 3.0 9/28/2018 9/29/2018 center rig over hole 4.0 9/2912018 9/30/2018 hook up lines from pits to sub base 5.0 9/30/2018 10/112018 SET STAIRS ON SUB BASE AND PITS 6.0 10/1/2018 10/212018 set berms for rig and pits/ mats for pits and set cuttings tanks 7.0,M 10/212018 10/3/2018 CENTER TOP DRIVE RAIL Finish pit liners around dg 8.0-09 10/3/2018 10/4/2018 fStart up boilers and function test top drive 9.0 10/4/2018 10/5/2018 Working on boilers/ preparing the pipe shed for picking up DP and stand it back. Taken some fresh water in the mud pits and test the mud pumps an high pressure mud lines. 10.0 10/512018 10/6/2018 Install bell nipple, choke and kill lines. Install koomey lines and secure stack tie downs. 11.0 10/612018 10/712018 Drilling line was slipped on and top drive quit working 12.0.: M 1017/2018 10/8/2018 Install new 3%" x 5%' VBR's in bottom ram. Install 3W' solid body style in top ram. Change out top drive A IBOP valve, and -re-test. Witnessed by AOGCC Jeff Jones. 'J D 13.0- - 10/8/2018 10/9/2018 PU 348 joints of 5 7d' XT 54 DP via mouse hole and stand back. This pipe will stay in the casing while drilling. Torque all connections to 49,000 ft/lbs. 14.0 1019/2018 10/10/2018 Pick up a total of 154 stands of 51,9" XT54 DP. Bull head 80 bbls 100° water down IA. Bull head 140 bbls down tubing. 100° water. Unseat hanger with 180k up weight. Free travel @ 160k. Tum on hole fill pump as hanger was coming up. Measure high levels of methane gas on rig floor, no pressure high volume, Re -land hanger, and bull head 100 bbls pill with 2.5# bbl 20 micron CaCI, Followed by 100 bbls water. bleed gas off IA. Pull hanger to floor. Well dead, no gas readings. Prepare to lay down tubing. 15.0 10/1012018 10/11/2018 Kill well, 18 PSI on backside.Bullhead tubing volume plus 10 bbls, bullhead 200bbis down IA, bleed residual gas off to production bleed tank. Lay down larding joint, hanger and pup. Open SSSV. Run chem line and [- Wire through sheaves, POOH laying down 3%" EUE 9.3# L-80 tubing from joint #461 to joint #282 . Retreive all cannon clamps. Fill hole with 5)'s displacement every 10 joints. 16.0 10/11/2018 10/12/2018 Comtete tubin ulI operations. 461 joints of 314" EUE 9.3# L-80, 3 GLM's, SSSV, Chem injection sub, seal assembly. All joints and equipment to be inspected prior to re -running. Remove casing bails, and GBR 75 ton tubing elevators, install drilling bails and drilling elevators. 17.0 10/12/2018 10/1312018 Rig down GBR tubing running equipment, remove tong bails, 75 ton elevators, cannon clamps, GLM's, all completion equipment from rig floor and pipe shed. Rig down and release Carrico spoolers, GBR. Strap 3 spiral DC's, 18 HWDP, TIH with Halliburton FZ drill SVB packer on XT 54 5%" OF. 18.0 _ 10/13/2018 10/14/2018 Td in hole with Halliburton EZ Drill Packer. Set 14620_ Mid joint. Fluid pack well with water. Circulate gas out t roug poor boy degassr. 920 units gas max down stream of degasser. 19i ' 10/14/2018 10/15/2018 Circulate surface to surface 4BPM through open super choke & poor boy degasses 920 Units max gas. 1. Conduct casing test to 3500 psi, 30 mins, charted. Good. Dispose of excess fluids in ph system. Displace well to 9.2 ppg OBM. Pump dry job. POOH strapping pipe. :0 10/15/2018 10/16/2018 TOOH from 4598' to surface. Lay down "Mechanical setting tool" after Halliburton CIBP run. Clean and clear rig floor. Pick up whipstock assembly with MWD tool. Orient. TIH to 1500'. Pulse test MWD tool. Mud pumps #2 & #3 were used. Both experienced pressure losses. Three cycles of pump pressure were recorded. Both pumps were isolated, and the cap gaskets were not properly installed. Both pumps put back together as per specification. Tested flowing through the choke manifold with 1500 PSI back pressure. Good. Decide to trip out for back up " Multi cycle by-pass tool". POOH to surface change out tools. Orient. TIH ® 457minute lowering speed. Trip to 1327'. crew change. 21.0 10/16/2018 10/17/2018 Shallow pulse test MWD tool @ 1325' MD. TIH W/ BHA#2 whipstock / Mill assembly to 3766'. Failed solenoid top drive elevators closing function. Replace solenoid. TIH to 6282'. Failed solenoid top drive handler function. Replace. TIH to 14551', stand #147. Orient Whipstock 38 right. Failed solenoid top drive pipe handler rotational locking device. Replace. Set whipstock @ 14,563' bottom of tool. TOW=14,538', BOW= 14,552'. Begin milling @ 14,538'. 22.0 10/17/2018 10118/21318 Milled window 14,535'to 14,543'. At 14.543'a pressure loss of 275psi was observed and milling torque fell as well. Varied parameters and made Vin 7hrs. POOH to inspect the BHA od mills. L/D Drill collars, MWD, HWDP Flex, running tool, and Mill. www.peloton.com Page 116 .5 f P �;'if ReportPrinted: 12126/2018 r WeliView Well Name: H16A BC - Daily Recap Daily Operations Rpt# Start Date EN Date Summary 23.0 10/18/2018 10/19/2018 UD BHA#2(bottom tri -mill badly junk damaged and 1/4" under gauge). P/U BHA#3(new tri -mill easy). RIH to 14,543" and MIII/Drill window and new formation to 14,569'- Pump sweep and circulate hole clean with 9.2 ppg mud wt in and out. POOH above window - R/U to perform FIT - 24.0 10/19/2018 10/20/2018 Circulate for FIT, R/U and perform FIT, formation broke down 7470 psi - R/D FIT assemably and monitored wellon TT.71ig oases affil a glel en mixing CL`lOrpr I, pump same, continued monitoring while mixing other LCM pill. Spotted 2nd pill and monitored losses. Began milling Q 15, 569'to 15,582'- Mill quit drilling - Observed well for losses - Pump out of hole 25.0 10/20/2018 10/21/2018 -C/O the grabber dies on the topdrive. -Pumped out of the hole 13,838' to 12,263'. -Pipe handler on the topdrive not functioning. Found a loose connection on a hydraulic line, tightened the connection and checked OK. -Pumped out of the hole 12,263'to 9,720'. -Serviced the rig. -Pumped out of the hole 9,720' to 3,171'. -Serviced the rig. -Average losses while pumping out 2BPH. 26.0 10/21/2018 10/22/2018 -Pumped out of the hole 3171'to 2983' -Pull out of the hole on elevators 298T to 576'. -L/D 18jnts of 5.5" HWDP. -UD mill easy, bottom 2 mills 114" under gauge. -Clean and Gear the rig floor. -P/U the wash tool and wash the BOPE stack. Recovered I lb of metal. -Pull the wear bushing and run the test plug and 5.5" test joint. -Test BOPE on 5.5" and 5" test joint 250/3500 psi 5 min. -Pull the test plug and Install the wear ring. -C/O the solenoid for the top drive compensator valve. -C/O topdrive washpipe from Tesco to mechanical. -P/U the motor BHA with crane assist. 27.0 10/22/2018 10/23/2018 -P/U 6 joints of 5.5" HT -55 drill pipe while RIH to 328'. -installed the mechanical washpipe. -Troubleshoot the topdrive grabber problem and installed a shorter saver sub and checked hydraulic pressure to the ram(OK). Verified that the saver sub could be broken out OK. -RIH to 2109' and filled the pipe and tested the MWD OK. -Continued to RIH to 7823' and serviced the rig - Trip in hole f17823' to 14,485'- Slip and cut 1 10'Drilling line - Adjusted COM - Calibrated block height - Trip in to TOW @ 14,538 take SCR's orient tools and run through the window. Open under gauge hole to 14,582'- drill new hole to 14,622" 28.0 10/2312018 10/24/2018 - Rotary Drill and Slide f/ 14,622' to 14,736'- WOB = 20/30K - 40 GPM = 1950 psi - 40 RPM - PIU WT = 305K - SIO WT = 150K - ROTANT = 21 OK - Average losses = 13 BPH - Backream OOH Fl 14, 735' to BOW 14,552- 4,552'Oriented Orientedthe motor and pumped out through window with 30 GPM with no excess drag - P/U WT 330K with 30 GPM - Begin clean up cycles and slowly bled in LCM pill 3. - 450 GPM C 1750 PSI - 80 RPM - Torque = 26K - PIU Wt = 220 K - Service TDS, drewworks, blocks, crown, clutches, upper bearing quill, choke, and IR - Monitoring well on TT with no losses - Pump out of hole as per K & M procedures F/ 14,209' to 7,983'. @ 9962' Attempted to adjust the topdrive grabber box lower limit. Found a washed out valve. Changed the safety chain on the topdrive grabber box. 29.0 • = 10/24/2018 10/25/2018 - Pumping out of hole Fl 7983' T/3853" -Continue POOH on elevators F/ 3853' to 130' as per K & M Trip schedule - R/U and UD BHA with crane - Remove wear bushing - Install test plug and test BOPE to 250 PSI 1 Low & 3500 PSI High - Remove test plug - Install Wear bushing - P/U New BHA - 30. 10/25/2018 10/2612018 - RIH picking up HT 55 Drill pipe to 2063'- Shallow test Directional tools with 460 GPM and 975 PSI - RIH picking up HT 55 DP to 3071'- Service Rig - Losses @ 1 BPH - P/U HT 55 DP to 5760' ( total jts picked up = j 174) Filled pipe every 20 Stds - Trip in hole from derrick @ controlled speed as per K & M Tripping 1 schedule T1 14,500'- CBU - Take SCRs - v ' RIH through Window to 14,640'- Begin Rotating from 14, 640 to 14,727- Drilled New hole to 14,795' - Unable to hold Tool Face due to erratic torque - Rotate and reciprocate pipe while conditioning mud (7� 31.0 1012612018 10/2712018 - Circulate and condition mud - Drill F/14,795' to 14,838'- Torque erratic - Tool Face control on the RSS was lost - Circulate and add Lube to active mud system to 0.5% - Drilling F/ 14,838' to 16,336' 32.0. 10/27/2018 10/2812018 ' - Drillino from 1 Schedule - Back Ream F/ 17,440' T/ 16,213' as per K&M Back Reaming Schedule Service Rig - UD (3) As DP with excessive wear - RIH F1 16,213' to 16,375' - Trenching and Time Drilling as per DO F/ 16,376 T/ 16,377' 33.0 10/28/2018 10/29/2018 - Time Drilling F/ 16,377'T/ 16,397'- Drilling ahead F/ 18 397' to 18 214' on Lateral # 2 34.0 10129/1018 10/30/2018 Worked Stuck pipe Free with applying torque in string and worked down, observed string free with 30K Torque - Clean hole back reaming F18,213' T 18,122'- Drilling L02 FI 18,213' to 18,390' (TD of Let 02 - Back ream FI 18,390; to 18,213'- Trouble shoot HPU for Overheating - Service rig - Baric Ream F/ 18,213' to 117,390'- 35.0 10/30/2018 10/31/2018 - Time Drilling F/17,138' T/ 17,143'- Drilling Main Bore F/ 17,143'T/17,746'- Service TDS - Drilling FI17,746' TN8,592' - ( KOP FI Lateral 03 17,933') Service Draw Works and ST 100 - Change Grabber diet t ` www.peloton.com Page 215 Report Printed: 1212612018 lam 1� WeliView" BC - Daily Recap Well Name: H16A 3 Daily Operations Rpt# Stan Date End Dale Summary 36.0 10/31/2018 11/1/2018 Directional Drill 8%" hole from 18,592'to 19,268'. TD of L03. Change out grabber dies in top drive. Back ream out to 17,950'. Hole in good shape. Begin troug-hing from 17,975' to 18,000' MD for L04. 37.0 11/1/2018 11/2/2018 Directional work. Low side sidetrack. trench from 17,975'to 18,000' MD. Time drill to 18,045'. Began pushing on BHA (A 18,045', WOB increased to 1Ok, and inclination dropped. Successful sidetrack. 38.0 1112/2018 11/3/2018 Directional Drill 814" hole with Exceed rotary steerable system from 18,122 to 19,249' MD. Drilling in L04. 39.0 11/3/2018 1114/2018 Directional Drill 8W" hole with Exceed rotary steerable system from 19,249' to TD of L04 @ 20,020' MD. CBU 5x's while back reaming. Back ream out to 19,280' MD 40.0 11/4/2018 11/5/2018 BROOH from 19,280'to the whipstock @ 14552' BOW. Pull slow into casing, no rotary. CBU 2x's inside casing. Service rig. Back ream one more full bottoms up. POOH pumping 100 GPM, no rotary, from 14,552' to 12,148' MD. Good hole fill. 41.0 11/5/2018 11/6/2018 Pump out of the hole 100 GPM, 350 PP, from 12,148'to 5930'. CBU 2x's. Pump dryjob. Trip out of the hole laying down singles. HT 55 drill pipe. From 5930' to Surface. Begin to lay down BHA#5. Constant hole fill using trip tank. 42.0 11/612018 11/72018 Lay down BHA#5. Lay down 180 joints of HT 55, and 360 joints of XT 54 from derrick and prepare for Premium Inspectors to machine on new hard banding. 43.0 1 V72018 11/82018 Lay down 5W' XT 54 drill pipe for hard banding. Repair HPU,install new fire rated hose coverings for Koomey room lines as per AOGCC. Install new XT 54 saver sub. Pull wear bushing, Install test plug. Begin testing BOPE with 5" TJ. 44.0 11/82018 11/912018 Conduct Bi -Weekly BOPE test W/ AOGCC Inspector. 5" and 5%" test joints. Rig down test equipment. PIU and stand back 78 joints of 5%" XT 54. ODS. Discover out of spec XO provided for new 5" XT DP. (Wall thickness below minimum. 3.5 ID versus 2.813", junk XO). Rig up and lest BOPE W1 4%" TJ to enable Rig Team to use XT 46 string. Pick up BHA#6. Single in hole with 5 joints HT 55. Repair broken hydraulic hose on top drive, adjust clamps on bails to reach mouse hole. 45.0 11/912018 11/1012018 Single in the hole with 246 joints of HT 55 DP. Fill pipe every 60 joints. Cross over to XT 46 DP. Continue strapping, drifting all pipe, and singling in the hole monitor the well on the trip tank. 120 joints of 4'N' in hole @ midnight. 46.0 11110/2018 11/112018 Continue to single in the hole with 4W' XT 46 from 10977' to 13,347'. Well Bore began to U-tube. Circulate bottoms up. Balance well. Single in remaining XT 46 pipe to 14,063'. 195 JTS total. Pick up and stand back 29 stands of XT 54 DP via mouse hole Slip and cut 120' of drill line. TIH to 14,434'. CBU, Downlink to Exceed tool. Record up and down weights. Trip past whip stock, and RIH to 15,194' MD. 47.0 11/112018 11/122018 TIH fr. 15,194' to 16,219'. Ream to 17,160'. Inadvertently entered build of L2. Pull back to 17,120', steer down with 70% defection to stay in Mother bore. Ream to 17,160'. TIH on elevators to 17,873'. Lose down weight. Ream from 17,873'to 18,770'. Sidetrack from 18,770' to 18,800'. First attempt to sidetrack was unsuccessful, second time drill sequence was good. Drilling ahead a 18,860' MD. 48.0 11/122018 11113/2018 Directional drill L05 W/ Exceed rotary steerable system, 814" hole from 18,860' to 20,538' MD. 49.0 11/132018 11/142018 Directional drill L05 W/ Exceed rotary steerable system, 8%d' hole from 20,538! to 20,743' MD. BROOH slow, perform clean up cycle. Pick up and stand back 6 stands of newly hard banded XT54 DP. BROOH to 19,500. Trough from 19,500 to 19,525'. Time drill to 19545', Begin drilling LO6 from 19,525'to 19,881' MD. 50.0 11/14/2018 11/152018 - Drilling 8 12" hole LO6 with Exceed Rotary steerable assembly F/ 19,881'T/ 21,340'- Circulate and clean hole, P/U 6 stds of DP while circulating - BROOH T/ 20,350' 51.0 11/152018 11/16/2018 - Back Ream F/20,350' T20,257' @ 15 FT/MIN - Service Rig - Troubleshoot and repair Reminder, Trenching as per DD F120,2W T20,279 - Time Drilling as per DD F/ 20,270' TI 20,295'- Drilling 8 12" hole as per DD & K&M parameters F/20,295' T/ 20,925' 52.0 1111612018 11/172018 - Drilling 8 ill" hole F/ 20,925'T/ 21,092'- Replaced Wash Pipe seals in TDS - Drilling F/ 21,092'T/ 21,850' - Service Rig 53.0 11/17/2018 11/18/2018 - Drilling F21,850' T/ 21,860' TD for L07 - Begin Clean up cycle and Pick up 5 STDS of XT 54 DP and Rads in Derrick - Back Ream F/ 21,745' T/ 21,145'- Begin trenching F/ 21,145' TI 21,165'- Time Drilling F1 21,165'T/ 21,194'- Drilling LOB F/ 21,194'T/ 21,850' 54.0 11/182018 11/19/2018 - Drilled 8 12" hole L08 as per DD & K&M Parameters F/ 21,850'T/ 22,310' TD - Performed Clean up cycle as per K&M Parameters - Flow check after the first cleanup cycle, no flow. Circulating Bottoms up x 6 and while back reaming @ 1 1/2 FT/MIN F/2 22,310'T/ 21,753'- Back reamed F/ 21,753' T/21,475' @ 15 _ FT/MIN - Serviced Rig 55.0 11/19/2018 1120/2018 - Back Reamed out of hjole F/ 21,475'T/ 19,787'- Worked through fight spot F/ 20,843'T/ 20,833'- Back Reamed F/ 19,787'T/ 18,660'- Service Rig Equipment - Back Reamed out of hole F/ 18,660' T/ 17,110' - RIH ( Had to rotate) TI 17211' and took survey to confirm still in Main Bore OK - Back Reamed F/ 17,211' T/ 15,003' - SLM 56.0 11/20/2018 11/212018 - Replace IBOP Actuator due to bearing seiwre(flow check, no gaindoss) - Back Reamed out of hole as per K&M Parameters F/15,003' TI 14,672" - POOH with BHA through window with 100/GPM & No Rotation FI 14,672' TI 14,510'- Back Reamed while performing Clean up Cycle to 14,165'- Changed out Saver Sub to XT 46 for(flow check no gain/loss) pulling 4 12" Drill Pipe - Pumped out of hole FI 14165'T/ 9,933' - SLM - Serviced Rig www.peloton.com Page 315 Report Printed: 12/26/2018 WeliView` Well Name: H16A BC - Daily Recap Daily Operations Rpt # Stan oat® End Date Sia mry 57.0 11/21/2018 11/22/2018 - PJSM - Pumped out of hole as per K&M Parameters F/ 9,933' T/ 8,047'- SLM - Break out XOs and M/U Safety valve - Changed out Saver Sub From XT 46 To HT 55 - Monitored Well on TT - Static - Pumped out of hole as per K&M Parameters F/ 8,047' T/ 6,600' - Serviced Rig and monitored well on TT - Static - Pumped out of hole as per K&M Parameters F/ 6,600'T/ 5,832'- Back Reamed out of hole while performing Clean up Cycle @ 1.5 FT/MIN F/ 5,832'T/ 5,732'- POOH on elevators as per K&M Trip Schedule F/5,732' T/ 3,526 - Monitor well displacement on TT - Back Reaming out of hole as per K&M Parameters while performing Clean _ Up Cycle F/ 3,525'T/ 3,430'- POOH on elevators as per K&M trip Schedule FI 3,430' T/ 163'- Lay down BHA 58.0 11/22/2018 11/23/2018 - Clean and organize Rig Floor - P/U 3 1/2" test joint - Made up Wear Bushing running toot and retrieve Wear Bushing - Made up 3 112" test assembly and tested BOPE to 250/3500 Psi for 5 MIN - RID 3 Ill" Test rr� assembly and M/U 5 1/2" Test Assembly - Test BOPE To 250/3500 PSI for 5 MIN - Test Gas Alarms - Remove test plug - Install Wear Bushing - Rig down Test assembly and Gear off rig Floor �( 59.0 11/23/2018 11/24/2018 - PJSM - RIM Pickin uD 4 1/2" Liner T/ 7.917' - Steam out ice on collars - Inspect box/pin - Graph monitor make up torque - Monitored displacement on Trip tank - Static - Change elevators - PIU and Make up PBR assembly - Service Rig and monitor well on TT - Remove long bails and elevators - Install short bails and Hydraulic elevators - M/U Liner Hanger and RIM to 8,085' - Establish circulation - RIH with 4 1/2" Liner on HT 55 Drill Pipe from derrick F/ 8,085' T/ 14,424' - Drifting each stand after # 36 - Monitor displacement on Trip Tank 60.0 11/24/2018 11/25/2018 - PJSM - Changed Saver Sub, Grubber dies, & installed bell guide and safety wire - Broke out XO from TIW - Made up Stand and checked Parameters - Broke circulation - RIM No drag passing through whip stock window- RIM T/ 17,140'- Hole taking weight - Made attempts to pass through - Made up TDS and rotated F/ 17,040' T/ 18,390' ( End of L02 ) POOH on elevators as per K&M Parameters FI 18,390'T/ 17,055' - Monitored well on Trip tank - RIM with 4 1/2" Liner as per K&M Parameters F/17,055' T/ 18,390'- ( End of L02 ) - Rotated as necessary - Monitored well on Trip Tank - POOH on elevators FI 11,390' T/ 16,021' - Monitor well on Trip Tank - Service Rig 61.0 11/25/2018 11/26/2018 - PJSM - POOH with 4 1/2" Liner as per K&M trip Schedule F/ 16,021' T/ 7,992' - Monitored well on Trip Tank i - Changed out Bails and Elevators to Lay down Liner - Serviced Rig - 62.0 11/26/2018 11/27/2018 - Clean Rig Floor of Base Oil and Inspect tools - PJSM - JaQH I a0ng down a 1n^ i {oar ao ppr KR�M h��n _ schedule F/ 4,852'T/ 4,157'- Break connections with rig longs until 4,300' - Inspected each Box and Pin with Tenaris Rep - Monitored well on Trip Tank - Had Safety Stand down Meeting with crews - POOH Laying down 4 1/2" Liner as per K&M trip Schedule F/ 4,157'T/1,732'- Using GBR Tubing Tongs to break all Joints after 4,300'- Inspected each Joint with Tenaris Rep - Monitored well on Trip tank - Serviced Rig and monitored well on Trip Tank - POOH Laying down 4 1/2" Liner as per K&M trip schedule F/ 1,732'T/ Surface - Inspected each Joint with Tenaris Rep - Monitored well on Trip Tank - Cleaned OBM from Rig Floor - _ _ Changed bails and elevators - Monitored Well on Trip Tank - Picked up BHA and RIM T/ 149' - RIM with HT - 55 Drill Pipe checking each connection with Premium for wear - Ran in Hole with 20 Stands - POOH with 20 Stands culling out bad Joints under 4 3/4" 63. 11/27/2018 11/28/2018 - PJSM - POOH laying down 5 1/2" Drill Pipe - Monitor well on Trip Tank - RIM with 5 1/2" HT 55 Drill Pipe from derrick F/ 149'T/ 2,068'- Break Circulation and shallow test MWD tools - RIH with 5 112" Pipe from derrick F/ 2,068'T/ 3,775' inspecting each connection with Premium Rep - Monitor well on Trip Tank - Service Rig - RIM with 5 1/2" HT 55 Drill Pipe from derrick F/ 3,775'T/ 5,691' inspecting each connection with Premium Rep -Cull out bad joints - Monitor well on Trip Tank - PJSM - RIM Picking up 73 joints of HT 55 Pipe from pipe shed F/ 5,691' T18,038' - Drift each joint in V -Door - Fill Pipe every 20 Stands - Monitor well on Trip tank while RIM - Make up XO - change elevator inserts to 4 1/2" - RIM with XT -46 Pipe F/ 8,038'T/ 14,145'- Monitor well on Trip Tank - Fill Pipe every 20 Stands - Changed elevator inserts to 5 112" - RIM with XT 54 Pipe T/ 14,424'- Break circulation with 100/GPM - P/U WT 295k - SIO WT 140k - Service Rig 64.0 11/28/2018 11/29/2018 Slip and cut 1 10'of drill lice. Inside casing 0 14,442'. Monitor well on TT. Static. TIH. Observe 5 to 10k drag as first two reamers crossed ramp. The third reamer required working the string to drop through. TIM on elevators from whipstock to 16,109' MD. Down weight 100k. Begin reaming. Ream to 16,389. TO grabber dies changed out. Ream to 16,948'. Service rig. Ream from 16, 948' to 17,205'. L02 exit point. Command rotary steerable tool to 100% lowside deflection, bring pumps up to 450 GPM, from 400 GPM, Increase RPM from 120 to 160 RPM. Work area from 17,208 to 17,285'. Hole unloaded with unconsolidated sand on first BU. Ream from 17,285' to 19,105' MD. MW=9.2 PPG in/out. 65.0 11/29/2018 11/30/2018 Ream to 21,826' MD. CBU Wl 500 GPM, 120 RPM. Service rig. BROOM from 21,826to 19,291' MD. 15' per minute, adding 5 BPH LVT, maintain 9.2 PPG MW in/out. Wellbore is static without ECD's applied, seepage losses remain around 1 BPH while pumping. SIMOPS: Rebuild liner tally. 192 good joints ready to go. 98 slotted, 94 solid. 66.0 11/30/2018 12/1/2018 Continue to BROOM. Slight pack off in known coal seam. 19,200'to 19,000'. Back ream to 17,605'. Install new grabber dies in top drive. Monitor well on TT. Static. BROOM to L02 exit point. Mimic liner run dropping back in 200 feet. Stayed in Mother Bore. Seismic Event: 7.2 Eath Quake centered 8 miles NW of ANC. Descion made to go back to bottom. Ream back in the hole from 17,100' to 21,264' MD. 67.0 12/1/2018 12/212018 Ream to 21,826'. CBU W/ 500 GPM, 120 RPM on first stand. Begin BROOM from 21,737' to 17,139. Mimic liner run past L02 exit point. Wellbore smooth. Continue to BROOM to 15,441' MD. Inadvertently add LVT to active. Monitor well, weight active back to 9.2 PPG. 68.0 12/2/2018 12/312018 Bring active pit volume back to 9.2 PPG MW. Circulate. 500 GPM, 120 RPM, 2480 PP, 28K TO, BROH slow. Circ light fluid into annulus. Depth 15,457'. BROOM to window. 14,710' Circulate 10 mins. Pull first string reamer into casing with 100 GPM. Second reamer required 25 RPM, 400 GPM. Pulled last reamer and bit into window with 400 GPM no rotary. CBU inside casing. 14,430'. Pump out of the hole from 14,430'to 9144' MD. 100 GPM, 350 PSI, 50 to 60'/min. www.peloton.com Page 415 Report Printed: 12/26/2018 WellView Well Name: H16A BC - Daily Recap Dally Operations Rpt# Start Dale End Dale Summary 69.0 12/3/2018 12/4/2018 Pump Out of the hole to the top to the XT 46. 9144' to 8036'.C/0 saver sub to HT 55. Grease wash pipe. Change out inserts to 5%". Pump out of the hole to 5800' > CBU Pump dry job. Drop 2.75" drift with wireline on stand #57. POOH on elevators to BHA. 70.0 12/4/2018 12/5/2018 C/O saver from HT 55 to XT 54 for liner run. Rig up and conduct Bi -weekly BOPE test. Witness waived by AOGCC. One fail/pass on the upper IBOP. Change out and retest. Rig down from test. Set wear bushing.Rig up long bails for liner run, dg up GBR power tongs, load 30 joints of liner in shed. 71.0 12/5/2018 12/6/2018 Pre job safety meeting. Rig up and run 4'h" 1520 P-110 HYD 563 liner to 7071'. 184 joints. Ave TQ=7,000 if/lbs. Premium Seat Guard dope used. All odd joints solids, all even joints slots. Every joint centralized. (Solid body spiral). Pick up PBR / Hanger assembly. TIH W/ 5'/i" DP to the Whipstock. 14,538'. record up/down weights. Rotate weight. TIH to 15,090'. 72.0 12/6/2018 12/712018 Run slotted liner to 18,390'. Entered 1-02 Pumped OOH to 17,060. Able to slide past L02 with no rotation. Began rotating again @ 17,154'. Rotate 15 RPM. Torque limiter set @ 28k ttflbs. Run liner to 21,510' MD. Drop ball to set hanger. Pressure up to 1500 PSI / 2200 PSI / 3000 PSI. Blew ball through seat. Hanger and Packer set on depth. Shoe depth 21.510'. Top of liner A 14 380.52'. 157 48' liner lap 73.0 12/7/2018 12/8/2018 Pull dogs out of liner packer. Set packer. Rig up and test casing & liner top packer to 2500 PSI. Charted for 30 mins. Good test. Displace to 9.2 PPG brine. Capture MOBM in tank farm. Lay doom singles from 14,254' to 5100' MD. 74.0 12/8/2018 12/9/2018 Continue to lay down drill pipe from 5100 to surface, all of the HT 55. TIH with remaining HT 55 and XT 54 to 1817. Lay down singles to surface. Vacuum foam bait through each joint, monitor well on the trip tank. SIMOPS: Cleaning pits. TIH with XT 46 DP to 6045'. Lay down singles to 2480'. Monitor well on the TT. Wellbore is static. 75.0 12/9/2018 12/10/2018 Complete the task of lying down the XT 46 singles from 2480 to surface. Pull wear ring. Remove power tongs for liner job, bring GBR power tongs for tubing run to floor. Inspect two pre-installed control line sheaves in derrick from Work over. Lubricate same. Make up landing joint & hanger. Make 'dummy run' with hanger, mark LJ and lay down in pipe shed. Measure 35.45' ULDS distance. Change out drilling elevators and drilling bails to casing bails, and 334" YT elevators. Hang 3rd sheave in derrick. String all three control line spools through sheaves in derrick. Load pipe shed with completion jewelry and 31W 9.3# L-80 Hyd 503 tubing. Make up seal assembly and run tubing tally as per Completion Eng tally from seal assembly to 3333'. 102 joints of 454 in the hole. 76.0 12/10/2018 12/11/2018 RIH W/ 3'h" tubing from 3333' 10 9716' as per tally. Joint # 308. Stopped going in hole due to lost handling pup. It was discovered that a 1.69' pup had been left on the bottom of nipple #1. Begin to trip out of the hole. Nipple # 1 depth 764'. 77.0 12/11/2018 12/12/2018 PJSM: Change in plans. Discuss tripping out and standing back tubing. POOH Fr 9685' to 6560'. Continue to trip out to 1550'. 607min racking back stands in derrick. 95k Up Wt. Crew change, continue to trip out with - 3%" tubing fr 1559to 760'. remove 1.69' handling pup from bottom of X Nipple assembly #1. The box end of pup was handy. TIH from 760' to 1551'. Reconnect control line for chemical injection sub, continue to trip in _ with stands to 4107'. 78. 12/12/2018 12/13/2018 - RIH F/Derrick 3 1/2" Com letion Tubin F/ 4 107'Instructions - install Cannon Clamp on eac onnectlon - Install X -Nipple - Rig up and fill pipe with Trip Tank Pump - RIH with Completion Tubing F/ Pipe Shed F/ 9,716'T/1 3,903' filling pipe on the fly and topping off every 45 AS - Continuous monitoring of the well - WU SSSV - SLB functioned x 3 and tested to 5000 PSI 15/MIN - RIH T/ 14,270' - Take P/U WT 138k - S/O WT115k - RIH and tag @ 14,434' with 1 Ok - Space out and M/U Hanger - Connect control lines and test to 5000 PSI 10/Min - Continuous monitoring well on Trip Tank. Simultaneous operations: Set the 4 upright tanks for the mud plant extension. Moved the welding shop to the north side of the pad. Set the roof over the resistor bank for the top drive back break. 79.0 12/13/2018 12/14/2018 - PJSM - Prepare all lines and valves for testing Tubing while connecting control lines to Hanger - Test lines to Hanger to 5000 psi - Land Hanger into wellhead - Energize lockdowns - R/U Testing assembly - Pressure test lines to 3500 psi - Test Tubing to 2500 psi for 10 minutes - Test through Annulus to 2000 psi for 10 minutes - Bring up Pump slowly and shear SO @ 2469 psi - Close SSSV with Schlumberger - Tested SSSV to 1500 psi for 10 minutes - Open SSSV and broke circulation - Spoil5bbls of 1 -VT in casing X tubing annulus for freeze protection. Remove Landing Jt and Install SPV - Blow Down hoses and choke manifold - R/D Tubing tongs and equipment - Change out bails - Remove all Tubing equipment from Rig Floor - Bleed Pressure from Accumulator- N/D Choke and Kill Lines - Cleaning Rig Floor for Rig Move - Pressure wash BOP and Mouse Holes - L/D Mouse Holes - Remove SLB sheaves from derrick - Flush Mud Pumps - Continue Cleaning Pits - Fill Test Pump with 4/1 Water/Methanol - Nipple Down BOPE and set on stand - Secure same - Continue preparing for Rig Move www.peloton.com Page 515 Report Printed: 1 212 61201 8 /IuerNS[ H16A Survey Geodetic Report SiiinftP Energy (Det Survey) diem: BlueClest Aden I. .......r,.,.., ., Vertical Section ArimuM: ...,.- e.....���.., 300.400 ° (I. NOM) Field: Slot Cosmopolitan Unit Pad/Hponitive � Vmtl.l Section Origin: 0.000 fl, OtowA Borc1ule.I H18A Easting "broad. Longitude R45.8100TMSL (-) P) RD GNic0unClEbvationevation: fle0ovee MSL MI 2005101 1111 Magnetic Dein ti.m: 14.609 ° Survey Name: Hi6A (°) M Total Gravity Field Strength: 1001.2613mgn (9.80665 Based) Survey Data November 18, 2018 0.00 Gravity Model: DO% Tort I ANO I DDI I ERD Ratio: 2776.630 ° l 19518.]5] R 17.23012954 0.00 Total Magnetic Field Strength: 55100.844 nT Coordinate Reference System: NAD27 Almelo Slob Pone, Zone 04, U8 Fast 0.03 Magnetic Dip Angle: 72.875 ° LecaRen 1 -at I Loop: N 59' 51'32.00254*. W 151. 40' 5.01 0.00 Declination Date: Novambet 17, 2018 Location Grid NIE Ya; N 2144851.950 RUS. E 168857.790 BUS 0.00 Magnetic Declination MOdeh MGM 2017 CRS Grid Convergence An91e: -1.5580 ° 0.00 North Reference: Two North Grid Scab Faclor. 1.0"Ob" 0.00 Grid Conventions* Used: 0.0000' Version I Patch: 2.10.5410 2144851.95 Total Corr Meg North- Tme North: 14.5092 ° Comments MD Incl Aden I. TVD33 TVD VSEL AM Closure NS EW 0113 Nordling Easting "broad. Longitude IRI (-) P) RD IRI OU MI Hill 1111 IRI 19100R1 INU81 INU ) (°) M RTE 0.00 0.00 0.00 -180.46 0.00 0.00 0.00 0.00 0.00 0.00 INA 2144051.95 168857.79 59.85888968 .151.60141581 0.03 0.00 0.00 -180.43 0.03 0.00 0.00 D.00 0.00 0.00 0.00 2144851.95 168857.79 59.85888960 .151.80141581 34.65 0.00 0.00 -145.61 34.65 0.00 0.00 0.00 0.00 0.00 Go 2144851.95 160857.79 59.85888960 -151.80141661 100.03 0.43 249.54 410.43 100.03 0.16 0.25 0.25 -0.09 -0.23 0.66 2144851.07 168/57.56 59.85888936 -151.80141706 200.03 1.02 252.78 19.56 200.02 1.00 1.51 1.51 -0.48 .1.43 0.59 2144851.51 168856.35 59.05888828 -151.80142360 300.03 2.42 320.54 119.52 299.98 3.56 4.23 3.73 D.89 -3.62 2.24 2144852.93 180854.19 59.85089202 451.80143652 400.03 5.40 313.69 219.28 399.74 9.47 11.02 995 6.74 V." 3.10 2144856.08 16885094 59.85090804 -151.80145409 500.03 7.61 323.52 318.63 499.09 19." 22.31 20.07 16.29 -13.05 2.49 2144868.59 166845.19 59.85893417 -151.80148677 600.03 9.91 303.00 417.48 597.94 34.11 37.39 35.75 28.31 .24.20 3.05 2144876.91 160034.31 59.85096157 -151.80154745 700.03 11.14 287.80 515.79 696.25 52.32 55.72 53.10 34.00 40.79 3.13 2144887.05 168817.94 59.85898282 -151.80163764 800.03 10.% 272.57 613.92 794.30 70.37 74.95 70.42 37.43 -59.65 2.96 2144890.99 168789.18 59.05889201 .151.80174023 900.03 8.37 273.40 71235 892.81 86.09 9260 Wait 38.34 .77.27 1.60 2144892.38 168781.69 59.85899449 -151.80183600 1000.03 10.13 294.04 810.91 991.39 102.12 109.35 102.61 42.41 43.43 3.56 2144896.89 168765.54 59.85900562 -151.80192400 1100.03 13.66 301.29 908.71 1089.23 122.68 129.94 123.14 52.13 -111.56 3.83 2144907.09 160747.60 59.85903221 -151.80202280 1200.03 16.58 303.80 10(5.30 1185.76 148]3 156.01 149.03 66.20 -133.51 2.99 2144921.M 188726.12 59.85907071 -151.80214200 1245.20 17.30 305.85 1046.51 1228.97 161.64 169.17 152.05 73.72 -144.31 2.07 2144920.57 168715.53 5505909128 -151.80220074 1344.32 19.34 305.59 1142.60 1323.06 192.84 200.33 192.81 91.91 .169.51 2.06 2144940.44 168690.74 $9.85914103 -151.80233832 1435.98 21.29 301.72 122656 1409.02 224.68 232.14 224.61 109.49 -196.11 2.58 214496694 168664.72 _ 69.85918913 -151.80248247 1529.07 23.66 301.2 1314.57 1495.03 250.17 267.74 260.18 126.01 -225.51 2.58 214,1981 16683/.89 59.85923981 -151.60264782 1623.25 25.95 300.17 1400.06 1550.52 299.70 307.26 299.70 146.12 -260.54 2.44 2145007.10 168801.37 50.85929481 -151.60283291 1717.56 26.63 300.05 1484.60 1665.06 341.46 349.03 341.47 169.07 -296.67 092 2145029.03 168565.02 59.85935213 -151.80302944 1611." 27.53 300." 1568.19 1740.65 384.20 391.77 384.20 190.52 -333.64 0.96 2145051.48 168529.45 $985941081 -151.00323049 1905.46 28.66 299.14 1651.13 1831.59 428.47 436.04 428.48 212.43 472.11 1.31 2145074.43 168491.50 59.85947075 -151.80343976 Mew 3532 298.11 1732.99 1913.45 474.75 482.33 474.25 234.60 412.75 1.05 2145097.69 168451.56 $9.85953139 .151.00366079 2093.56 32.53 297.94 1613.24 1993.70 523.76 531.37 Mies 257.64 456.04 2.35 2145121.9) 168408.92 59.85959441 -151.80389825 2188.08 35.54 296.74 1891.56 2072.02 5M.59 504.27 576.64 281.91 -503.03 3.26 2145147.44 166352.60 59.85966082 -151.80415187 1296.00 37.48 296.42 1978.30 2158.11 640.69 Si 640.79 310.64 -560.46 1.82 2145177.12 168305.97 59.85973940 -151.00446424 23M.68 39.21 297.75 2041.57 2222.03 890.68 698.54 690.82 333.44 405.02 2.36 2145201.72 168262.05 59.85980171 -151.00470661 2473.39 42.17 299.40 2114.89 2295.35 753.70 761.58 753.86 363.62 4660.37 3.25 2142233.39 168207.54 59.85908432 -151.80500257 2563.50 44.14 299.50 2180.62 2381.48 815.33 823.21 015.49 393.92 -014.03 2.19 2145265.15 188154.71 59.85996721 -151.80529958 2657.45 45.62 296]1 1247.20 2427.66 881.57 889.49 881.76 425.12 -772.51 2.62 2146297.93 168097.11 59.66005257 -151.00561113 2751.44 47.92 295.03 2311.57 2402.03 949.87 557.97 950.15 454.96 -034.13 2.77 2145328.45 168036.32 59.86013425 .151.80595280 280.545 60.92 294.28 2372.53 2552.99 102092 1029.13 1021.15 461.66 498.81 3.26 2145360.88 167972.47 59.86021643 -151.80630482 2938.95 53.66 293.61 2429.90 2610.38 1094.51 1103.34 1095.15 514.n -9156.63 2.97 2145392.82 167905.49 59.06029778 -151.80667154 3033.00 56.06 295.10 2484.03 2684.49 1171.03 1100.29 1171.90 546.49 -1036.67 2.86 2145428.44 167836.33 59MO38456-151.80M5454 3126.75 59.20 296.19 2534.21 2714.67 1249.97 1259.41 1251.02 580.n -1108." 3.49 2145462.64 167765.93 59.86047832 -151.80744273 3220.66 61.70 287.75 2580.53 2760.99 1331.55 1341.09 1332.70 SITED, -1180.83 3.03 2145501.67 1676".17 59.06057970 -151.80783866 3316.24 63.36 200.93 2524.14 28104.60 1415.43 1425.01 1416.61 657.68 -1254.66 2." 2145543.52 167621.42 59.86"8669 -15180624042 Cosmopolitan UnihCosmoplitan Pad1H16W16tH16 Driihng Ot6oe 2.10.302.0 . Schlumberger -Private 1!72019 3:32 PM Page 1 of 5 Lommems MD In41 Aom Tne TVDSS TVD VSEC AHD Cbsun NS EW DLS N9k I, Essting UNW6e LongRu6e MI 1.1 1'1 IRI IRI MI MI IRI MI (a) PROM/ Must MUST M 1.1 3406.17 64.84 299.90 2584.72 280.18 1499.02 1508.61 1500.17 693.74 -1327.50 1.83 2145586.54 167549.74 59.86080101 -151.00663653 3502.99 64.04 299.49 2705.63 2086.09 1584.56 1594.15 1585.68 741.12 -1401.81 0.93 214500.93 167476.62 59.86091692 -151.80904073 3596.91 64.55 29909 2746.36 2926.82 1669.19 1678.78 1670.27 782.52 -1475.62 0.67 2145674.32 167403.96 59.86103016 -151.80944223 3690.76 64.59 298.04 2786.65 2967.11 1753.92 1763.54 1755.02 823.05 -1550.06 1.01 2145716.86 167330.64 59.86114101 -151.80984717 3764.55 65.08 296.94 2826.53 3006.N 1838.72 1848.43 1839.0 862.23 -1625.36 1.18 2145750.07 167256.43 59.86124818 -151.81025680 3078.59 64.70 295.53 28%." 3046.0 1923.69 1933.50 1925.02 099.87 -1701.74 IA2 2145797.78 167181.11 59.86135113 -151.81067228 3972.35 64.14 296.20 2906.93 3087.39 2%8.04 2018.15 2009.54 936.77 -1777.84 0.88 2145836.73 1671%.04 59.86145203 -151.81108623 4066.28 64.20 29S.38 2947.85 3128.31 2092.40 2102.70 2094.06 974.21 -1853.64 0.18 2145076.22 167031.28 59.861554" -151.81149857 4126.10 64.99 295.8 2973.51 3153.97 2146.32 2156.73 2148.07 998.01 -1902.15 1.52 2145901.33 166543.43 59.86161952 -151.81176247 13-316- 417503 6651 29663 2994.00 3174.45 2190.66 2201.17 2192.49 1017.67 -1942.0 146 2145922.07 16694443 59.66167329 -151.81197925 4215.22 65.94 297.25 3010.52 3190.98 2227.24 2237.80 2229.12 1034.27 -1974.66 1.76 2145939.55 166911.93 59.86171869 -151.81215692 4261.49 66.12 296.74 3029.32 3209.78 2269.46 2280.% 2271.40 1053.46 -2012.33 1.0 2145959.76 166874.80 59.86177117 -151.81238155 4355.37 66.26 297.61 3067.22 3247.68 2355.25 2365.97 2357.29 102.68 -2088.74 0.86 2145001.05 166799.48 59.86167845 -151.81277751 4448.65 66.36 297.51 31U.70 3285.16 2"0.59 2451.39 2442.71 1132.21 -2164.47 0.15 2146042.61 156724.86 59.861986M -151.81318946 4542.46 %.07 296.67 3142.53 3322.99 2526.32 2537.23 2520.54 1171.30 -2240.09 0.88 2146083.77 166649.52 59.86209345 -151.81360521 4636.44 65.95 296.38 3180.74 3361.20 2812.04 2623.09 2614.40 1209.98 -2317.55 0.24 2146124.52 16%73.94 59.66219923 -151.81402222 4730.30 %.38 297.19 3218.73 3399.19 2697.76 2708.92 2700.22 1248.99 -2394.00 0.48 2146165.60 166498.58 59.86230592 -151.81443811 4624.27 0.97 297.98 3256.75 3437.21 2783.62 2794.86 2786.16 1288.78 -2470.16 0.85 2146207.45 166423.52 59.86241474 -151.81485246 4918.15 0.24 2%.97 3294.78 3475.24 2069.42 2880.69 2871.98 1329.71 -2545.61 1.01 21"250.41 166349.21 59.86252%5 -151.01526292 5012.24 66.06 298.87 9332.82 3513.20 2955.46 2966.75 2958.01 1371.32 -2620.94 0.21 2146294.% 166275.05 59.86264046 -151.01567270 5106.32 %.M 299.19 MTo5S 3551.02 3041.62 3052.92 3044.16 1413.14 -26%.29 0.69 2196337.91 166200.86 59.%275482 -151.81608263 5200.19 65.82 299.27 340840 3588.06 3127.52 3138.03 3130.04 1455.09 -2771.25 0.88 2146381.88 166127.06 59.86286954 -151.81649047 5294.81 66.18 299.72 3446.89 3627.35 3213.96 322627 3218.44 1497.65 -2046.49 0.58 2146426A7 166053.01 59.%298593 -151.8168979 5308.14 65.79 299.73 3404.87 3665.33 3299.21 3310.52 3301.64 1539.92 -2920.52 O.Q 2145470.74 165980.15 59.86310152 -151.81730256 5481.25 65.86 299.08 3523.00 3703.46 3384.15 3395.47 3385.53 1582.14 -2994.23 0.17 2146514.95 165907.61 59.%321698 -151.81770356 5575.30 66.01 299.57 3551.35 3741.81 3470.03 3481.M 3472.36 1624.72 -3060.81 0.34 2146559.55 165834.22 59.%333342 -151.8181%29 5669.M 66.32 299.52 3599.35 3779.61 35%.4 357.36 3558.35 1667.14 -3143.64 0.33 2148603.98 165760.57 59.86344941 -151.81851643 763.7 66.91 299.25 3636.79 3817.25 3642.62 3553.94 3644.% 1709.62 -3219.00 0.68 2146648.50 165686.31 59.86356558 -151.6189267 5857.71 66.26 299.29 3674.16 3854.62 3728.91 3740.24 3731.17 1751.81 -3294.36 0.69 214692.73 165612.20 59.66368095 .151.81933643 5951.71 66.29 299.63 3711.88 3892." 3814.96 3826.29 3817.20 1794.14 -3369.29 0.33 214737.7 165538.45 59.86379668 -151.8197449 6045.74 %.35 299.18 3749.75 3938.21 3901.07 3912.41 3903.29 1836.42 -M".31 0." 214781.38 165464.61 59.86391229 -151.82015224 6139.71 66.95 299.30 37%.99 3%7.45 3987.33 3998.68 3989.55 1878.56 -3519.59 0.65 2146825.55 1653%.50 59.86402753 -151.82058182 733.57 67.33 299.28 3823.46 4003.92 473.81 4085.17 4076.02 1920.87 -3595.02 0.41 2146869.90 165316.24 59.86414322 -151.8207222 027.38 7.19 299.53 3859.72 "".18 4160.33 4171.68 4162.51 1963.35 -3570.39 0.29 2146914.41 165242.05 59.86425937 -151.82138230 6421.39 67.60 299.49 3895.85 476.31 4247.11 425847 Q49.28 2006.10 470.92 0." 2146959.20 165167.71 59.%437626 -151.02179324 015.39 68.04 299.46 3931.34 4111.80 4334.15 4155.52 4336.30 2048.93 4821.70 0.4 214704.% 165093.13 59.86"9337 -151.82220554 6609.28 68.21 298.39 3986.32 4146.78 4421.26 4432.65 023.42 2091.7 -3097.96 1.07 2147048.27 165018.04 59.06460859 -151.02262045 6703.25 67.43 298.24 4%1.80 4182.26 4508.24 4519.66 4510." 2132.34 -3974.56 0.64 2147091.62 164942.58 59.664721" -151.82303725 7%.52 7.19 290.45 4037.78 4218.24 4594.26 4605.71 4$%.49 2173.20 4050.30 0.33 21471M.52 164567.99 59.06483314 -151.823"931 6890.99 67.49 298.37 4074.17 Q54.63 4681.40 4692.89 4683.66 2214.67 4126.% 0.33 2147178.06 16092.46 59.88494659 -151.82386652 6%5.40 67.65 298.27 4110.19 Q90.65 468.63 4M0.16 4770.93 2258.07 4203.80 0.20 2147221.54 164716.79 59.8650573 -151.82420451 777.95 7.22 298.39 4145.71 4326.17 4854.% 4865.62 4856.40 2296.63 4279.0 0.0 2147264.13 164642.89 59.56517061 _ -051.82469383 7171.18 7." 298.54 4181.64 4352.10 4940.06 4951.65 4942.42 2337.63 4354.65 0.28 21437.17 164568.21 59.86528271 -151.82510532 7265.18 7.94 298.21 4217.33 4397.79 5026.98 5038.61 5029.38 2378.96 -4431.17 0.62 214350.56 IW92.84 59.86539570 -151.82552165 7359.15 67.57 297.73 Q52.90 "33.36 5113.91 5125.59 5116.36 2419.75 457.98 0.62 2147393.43 16"17.16 59.86550722 -151.82593962 7452.94 67.45 297.57 4288.78 4469.24 5200.49 5212.25 5203.01 2459.97 4504.75 0.20 2147435.72 164Mi.52 59.86561716 -151.82635728 7546.0 7.26 297." 4324.96 4505.42 5287.15 52N.99 5289.75 2500.03 -4661.68 0.24 2147477.06 154265.70 59.86572668 -151.8277592 7640.96 67.49 297.84 4361.14 4541.60 5373.87 5385.78 5376.54 2540.29 4738.57 0.46 214520.20 154189.93 59.8658375 -151.82719429 7735.00 7.36 2%.41 437.24 4577]0 5460.06 502.62 5463.37 2581.23 4815.15 0.58 214563.20 154114.49 59.86594065 -151.62761099 7828.92 67.39 2N.11 "33.37 4613.03 5547.31 5559.31 5550.% 2622.27 4891.51 0.30 2147606.31 164039.27 59.86806%6 -151.82802648 7923.06 67.35 2%.35 4469.60 4650.% 5615.18 5646.22 5636.97 2663.38 496809 0.24 214649.49 IM963.64 59.86617324 -151.628"314 8016.85 7.68 296.16 4505.46 4605.92 5720.78 5732.86 5723.62 2704.40 -50".40 0.40 214692.56 163888.67 59.66628537 -151.82885042 8110.80 67.29 296.56 4541." 4721.90 5807.0 5819.65 5810.40 2745.62 -5120.78 0.57 2147735.85 163013." 59.86639805 -151.82927399 8204.75 7.33 298.81 45]7.68 4758.14 5894.19 5906.33 5897.08 2787.23 -5196.82 0.25 214779.51 163730.59 59.85651150 -151.62960777 82%.M 67.25 298.84 4614.00 494.46 5980.97 5993.12 5%3.7 2829.8 -5272.86 0.09 2147023.41 163663.68 59.86662619 -151.83010155 8392.78 7.30 2%.92 4650.29 4830.75 6067.60 679.P 6070.51 270.92 -5158.73 0.09 214867.31 163588.7 59.86674059 -151.83051"1 6485.76 67.25 290.52 4686.21 4866.7 753.15 6165.53 6156.27 2912.14 -5423.94 0.40 2147910.55 163514.91 59.86885324 -151.83092368 8579.76 67.37 298.57 4722.47 4902.93 6240.04 6252.26 6242.99 2953.58 -55%.12 0.14 2147954.05 163439.80 59.85696652 -151.83133824 %73.60 67.17 2%.21 4758.76 4939.22 6326.0 038.88 6329.62 2994.77 -5576.33 0.41 2147997.29 163364.02 59.8677911 -151.83175293 8767.71 67.30 297.52 4795.15 4975.61 6413.27 6425.59 6416.32 3035.29 -5652.98 0.69 2148039.89 10289.30 59.86718980 -151.83217004 8861.52 67.10 297.36 4831.50 5011.96 64N.66 012.7 6502.79 3075.14 -5729.73 0.26 2148081.81 163213.06 59.86729080 -151.0325769 8955.40 67.11 297.35 4868.03 5048.49 6586.06 6598.55 6589.27 3114.88 -5806.55 0.01 2148123.63 163137.95 59.8670742 -151.83300568 Cosmopolitan Unit\Cosmoplitan Pad"6\H16\H76 Drilling office 2.10.302.0 . Schlumberger -Private 1/7/2019 3:32 PM Page 2 of 5 MD Inel Adm Trve TVD68 TVD VSEC AND cw... NB M DLS N9rUlirg Eas6ng L481u6e L9nga08e COmmanb IRI I'1 1.1 1Rl IRI MI all IRI MI IRI ('I10M) IRO51 (USI M M 9049.36 67.35 297.49 4904.39 5084.85 6672.61 605.19 6675.90 3154.78 -5883.45 0.29 2148165.6D 163062.16 59.86)5164] -151.83342418 9143.37 67.56 29].4] 4940.43 5120.89 6759.35 6]]2.02 8762.72 3194.84 -5960.40 022 214820].]5 162986.24 59.86]6259] -151.83384335 9237.36 66.90 290.11 4976.81 515].2] 6845.95 6858.68 6849.38 3235.25 6037.15 a." 214025022 162910.70 59.86773 1 -151.83426057 9331.34 67.10 297.82 5013.53 5193.99 6932.40 6945.19 6935.89 3275.81 -6113.55 0.35 2140292.85 162835.42 59.06]84]28 -151.8346]63] 9425.31 67.59 29].]4 5049.73 5230.19 7019.05 7031.91 7022.60 3316.23 6190.28 0.53 2148335.34 162759.82 59.86795775 -151.83509390 9519.14 8].55 29].]0 5085.53 5265.99 ]105.]2 7118.64 7109.33 3356.63 -826].03 0.06 21483nal 162684.20 59.86806816 -151.835511% 9813.00 67.12 29].95 5121.70 5302.16 7192.27 7205.25 7195.94 3397.11 -6343.60 0,49 2148420.36 162608.76 59.86817880 -151.83592825 9706.89 67.11 297.99 5150.21 5338.67 7278.72 ]291.]5 ]282.44 3437.68 6419.99 0." 2148462.99 162533.49 59.86828968 -151.83634400 9800.85 67.00 298.28 519418 5375.24 7365,22 7378.30 ]368.99 3478.49 -6496.32 0.29 2148505.86 162458.30 59.86840122 -151.83675936 9894.74 67.13 298.35 5231.31 5411.]] 7451.68 7464.80 7455.49 3519.52 65M.46 0.09 2148548.95 162381.30 59.86851334 -151.8371]3]5 9988.50 67.37 298.74 526].5] 5448.03 7538.12 7551.26 7541.95 3560.84 -6648.42 0.46 2148592.31 162308.50 59.8686282] -151.83758711 10082.44 67.13 298.78 5303.89 5484.35 762413 7637.89 7628.58 3602.52 -6724.36 0.26 2148636.05 162233.71 59.86874018 -151.83000042 10176.40 67.50 298.59 5340.13 5520.59 7211.39 M24.58 9715.26 3644.13 -6800.41 0." 2140679.71 162158.82 59.86885391 -151.83841431 10270.39 67.07 298.56 5376.42 5556.88 "98.07 7811.28 7801.96 3685.60 -6876.55 0.46 2148723.24 162083.83 59.86896724 -151.83882868 10364.46 67.33 298.18 5412.88 5593.34 ]880.]5 7898.00 7808.68 3726.80 -6952.86 0.46 2148766.50 162008.67 59.86907985 -151.83924395 10458.39 67.26 29].]9 5449.13 5629.59 7971.35 7984.65 ]9]5.33 376-648 4029.37 0.39 2146809.23 16103.29 59.869190% -151.83966039 - 10552.47 67.36 297.80 5485.42 5665.88 8058.09 BD71.45 8062.13 3807.99 -7106.13 0.14 2148851.83 161857.66 59.85930172 -151.84007812 10646.49 67.19 298.14 5521.75 5702.21 0144.75 8158.17 8148.85 3848.72 -7182.69 0.31 2148894.62 161782.23 59.86941301 -151.84049481 10740.41 67.43 298.14 555].9] 5738.43 8231.36 8244.82 8235.50 3889.59 -7259.10 0.26 2148937.55 161706.96 59.86952469 -151.840910% 10834.44 67.42 297.28 5594.07 5774.53 0318.11 8331.65 8322.32 3929.% -7335.97 0." 2148980.00 161631.22 59.86963502 -151.84132900 10928.42 67.02 297.53 5630.46 5810.92 8404.87 8018.30 8408.% 3969.84 -7412.89 0.49 2149021.96 161555.40 59.88974400 -151.84174766 11022.46 67.47 297.34 6666.83 5847.29 0491.31 8505.02 8495.67 4009.80 -7489.86 0.51 2149064.00 161479.55 59.06985318 -151.84216656 11116.33 67.04 297.86 5703.13 5803.59 85]].80 8591.59 8502.24 4049.]] -7566.65 0.58 2149106.04 161603.87 59.86996240 -151.84258448 11210.32 67.57 298.03 5739.39 5919.85 6664.45 8678.30 8668.95 4090.27 -0603.32 0.67 2149148.62 16132833 59.87007300 -151.84300177 11304.23 67.00 297.86 5775.65 5956.11 8751.02 8764.93 8]55.5] 4130.87 -719.85 0.63 2149191.26 161252.94 59.87018400 -151.84341827 113%.18 66.99 298.30 5812.37 5992.83 8837.45 8851.40 8842.05 41]1.5] -7796.15 0.43 2149234.05 161177.77 59.07029523 -151.84383354 11492.17 67.67 2%.35 5848.60 6029.0 8924.14 8938.13 0928.78 4212.72 -]8]2.49 0.72 21492]].26 161102.57 59.87040787 -151.84424906 11585.98 67.32 298.21 5084.50 6064196 9010.76 9024.80 9015A5 4253.78 -7940.81 0.40 214020.38 161027.39 59.87051987 -151.04466446 11679.78 87.05 298.03 5920.88 6101.34 9097.18 9111.26 9101.91 4284.53 -8025.07 0.34 2149363.19 160952.27 59.87083121 -161.64507950 11773.81 67.25 29].9] 5957.39 6137.85 9183.78 9197,91 9188.56 4335.21 -0101.57 0.22 2149405.93 160876.90 59.87074237 -151.84549593 11887.69 67.20 297.61 5993.73 6174.19 9270.27 9284.47 9275.12 4375.57 -8178.15 0.36 2149448.36 160001.44 59.87085263 -151.84591272 11961.56 67.32 297.% 6030.02 6210.48 9356.78 9371.04 9361.69 4415.95 -8254.73 0.39 2149490.80 160725.99 59.87096295 -151.84632954 12055.24 67.36 298.12 6068.11 62M.57 9443.18 9457.49 9448.14 4456.61 -0331.02 0.13 214953152 160650.83 59.87107404 -151.84674479 12149.23 67.45 298.30 6102.22 6282.60 9529.91 9544.27 9534.91 4497.63 -8607.49 0.20 2149576.61 160575.50 59.87116612 -151.84716100 12243.22 67.40 298.67 6138.30 6318.76 9616.67 9631.06 9621.70 4539.02 -0483.77 0.37 2149620.06 160500.37 59.87129921 -151.84757621 1233].0] 5].00 298.26 6174.67 6355.13 9703.16 9717.57 9708.21 4580.25 -8559.83 0.59 2149663.35 160425.46 59.87141187 -151.84799019 12431.03 67.24 20.80 6211.20 6391.66 9789.69 9804.14 9794.78 4621.60 -8635.88 0.59 2149706.75 160350.56 59.07152484 -051.84840417 12524.90 67.12 299.14 6247.61 6428.0] 9076.20 9890.66 9881.29 4663.51 -8711.58 0.30 2149750.70 160276.03 59.87163934 -151.84881620 12818.71 66.54 299.30 6284.52 6464.98 9962.44 9976.91 9967.52 4705.61 -0786.85 0." 2149794.83 160201.0 59.8]1]5437 -151.84922590 12712.75 66.27 299.24 6322.16 6502.62 10048.61 10063.08 10053." 4]4].74 -8862.02 0.29 2149839.00 160127.0 59.87186949 -151.84961511 12806.48 66.08 298.93 6359.42 6539.88 10134.60 10149.09 10139.88 4789.65 -8937.18 0.72 2149882.83 160053.93 59.8]1983]1 -151.85004422 12900.56 66.35 298.45 6396.76 6577.22 10220.93 10235.44 10226.02 4831.00 -9012.93 0.73 2149926.33 159979.33 59.8M0%97 -151.85045655 12994.85 66.82 297.87 64M.23 6614.69 10307.41 10321.97 10312.55 4871.84 -9089.22 0.75 2149969.22 159904.19 59.8722052 -151.8508]1]9 13008.74 66.40 297.06 6471.51 8651.97 10393.50 10408.14 10398.72 4911.58 4%5.68 D.91 2150011.03 159828.83 59,8M31710 -151.85128798 13182.31 66.93 296.08 6508.57 6689.03 10479.30 10494.06 10484.61 4950.55 -9242.25 0.59 2150052.07 159753.35 59.87242354 -151.851]04]9 13276.06 67.07 297.25 6545.20 6725.66 10565.48 10580.35 10570.89 4989.81 -9319.10 0.39 2150093.41 159672.59 59.87253080 -151.85212309 13370.08 67.44 297.93 6581.55 6762.01 10652.11 10867.06 1057.60 $029.97 -9395.94 D.77 2150135.64 1595D1.87 59.87264050 -151.85254140 13484.12 67.29 297.02 661].]5 6798.21 10738.82 10753.86 107".39 5070.01 -9472.95 D.91 2150177.77 159525.98 59.87274989 -151.85296057 13556.83 67.28 295.68 6853.55 6834.01 10824.17 10839.38 10829.86 510].9] -9549.58 1.33 2150217.79 159450.40 59.87285356 -151.85337271 13650.69 67.38 295.80 6689.72 6870.18 10910.53 10925.98 10916.39 $145.58 -9627.60 0.16 2150257.52 1593]3." 59.87295630 -151.85380237 137".69 67.31 295.36 6725.93 6908.39 10997.02 11012.73 11003.05 5183.04 -9705.84 D." 2150297.00 159296.24 59.87305859 -151.85422828 13838.77 67.04 295.25 6762.43 6942.89 11083.45 11099." 11089.67 5220.10 -9784.23 0.31 2150336.27 159218.88 59.87315902 -151.85465499 13932.71 70.95 295.26 6706.09 6976.55 11170.83 11187.12 11172.24 5257.51 -9863.53 4.16 2150375.82 159140.63 59.8]326198 -151.05508665 14026.51 75.05 29&97 6823.51 7003.97 11260.24 11276.81 11266.84 5206.29 -99".40 4.43 2150416.78 159060.84 59.BM36709 -151.85552684 14120.50 77.03 296.91 6846.19 7026.65 11351.28 11358.02 11358.01 5336.90 -10026.06 2.32 2150459.80 158980.31 59.87247881 -151.85597140 14214.49 79.71 297.59 6865.13 7045.59 11"3.22 11480.07 11450.06 5379.05 -10107.90 2.94 2150503.96 158899.65 59.BM59394 -151.85641687 14308.30 81.38 299.05 6880.56 7061.02 11535.79 11552.68 11542.66 5422.99 -10189.42 2.35 2150560.10 158819.35 59.87371395 -151.85686067 14402.77 83.74 299.93 6892.78 7073.24 11629.38 11646.27 1166.22 5469.06 -10270.80 2.67 21505%.37 158]39.1] 59.8]383981 -151.85730415 Tlein Survey 14496.25 05.49 299.95 8%1.55 7082.01 11722." 11739.33 11729.23 5515.51 -10351.53 1.87 2150646.99 158659.82 59.87396669 -151.85774318 14530.00 86.65 29992 6904.41 ]684.8] 11764.09 11780.98 11770.06 5536.29 -10387.62 2.78 2150688.75 158624.30 59.87402346 -151.85793969 Cosmopolitan Unit\CDsmoplitan Pad\H16NH16Ui16 Dulling Office 2.10.302.0 Schlumberger -Private 1!7/2019 3:32 PM Page 3 of 5 comma MD Incl Asim Trve TVDSS TVD VSEC AHD Cl98un NS EW Me N9Min9 Eastin9 1.4119.6. Long8u4e IMI VI 111 Ml INI INI no MI MI IRI I-noo 1 IMISI IMS) 1'1 Vl 14552.00 88A2 301.30 6905.01 7005.47 19"8.08 11)94.9] 11284.84 5543.42 -10399.68 16.03 2150676.20 158612.46 59.87 04292 -151.85800522 14614.42 87.63 302.96 6907.16 7087.62 11840.41 11852.35 11847.06 5576.59 -10452.48 2.94 2150210.80 158%0.55 59.824133% -151.85829283 14667,09 87.66 304.38 6909.36 7089.82 11893.73 11910.78 11900.23 5606.21 -104%.95 2.65 2150741.62 158516.91 59.87421448 -151.85853490 14762,38 87.72 3%.91 6913.17 7093.63 11987.67 12005.19 110183 5681.23 -10573.66 2.68 21507%.70 158441]2 59.87436481 -151.85695262 14855,19 WA4 309.65 6916.52 70%.98 12D79.45 12092.94 1205.14 5718,68 -10846.46 2.9B 2150058,11 158370.50 59.87452181 -151.85934904 14949.38 89.76 311.02 6918.25 7090.71 12172.09 12192.11 12172.23 5"9.63 -10718.25 2.25 2150921.00 150300.40 59.87458839 -151.85973993 15043.62 91.30 368.37 6917.38 7097.84 12264.97 12206.34 12269.62 5639.81 AD790.75 3.25 215M3.13 158229.56 59.87485285 -151.88013425 15137.51 91.56 305.30 6915.03 7095.49 12368.15 12300.20 12362.47 58%.08 -10865.86 3.26 2151041.41 158156.01 59.0750%60 -151.86054376 15231.11 90.77 302.18 6913.13 7093.59 12451.52 12473.78 12455.65 5948.05 -10943.67 3.44 2151095.48 15BD79.64 59,87514858 -151.86096742 15326.49 90.93 3N.D3 6911.72 2092.16 12546.75 12%9.15 12550.71 6000.13 -11023.95 1.95 2151149.72 158001.20 59.87529088 -151,86140238 15420.28 91.54 308.18 6909.69 7090.15 12639.96 12%2.92 12843.65 6055.37 -11099.30 4A7 2151207.00 157926.98 59.87544102 -151.66181481 15514.17 91.54 307.91 6907.17 707.63 12732.69 12756.78 12736.25 6113.22 -11173.21 0.29 21512%.84 157854.67 59.87559987 -151.86221732 15607.37 91.11 3%.49 6905.01 7%5.47 12825.33 12849.95 12828.40 6169.55 -11247.43 1.59 2151325.17 15"82.01 59.87575379 -151.86262146 15701.02 90.43 305.64 6903.76 7084.22 12918.45 12943.59 12921.29 6224.67 .11323.12 1.16 2151382.33 15"07.04 59.87590441 -151.86303364 15294.85 90.41 386.29 6903.07 7083.53 13011.n 13037.42 13014.30 6279]8 -11399.06 0.69 2151439.40 157633.42 59.87605497 -151.86344718 15886.34 90.43 305.44 6902.38 7082.04 13104.76 13130.91 13107.18 6334.55 -11474.82 0.91 2151496.29 157559.18 59.87620461 -151.86385974 - 1598sn 90.20 3%.00 6901.45 2%1.91 13199.27 13225.88 13201.48 6390.00 -11551.93 0.65 2151553.82 157483.60 59.87635611 -151.86427963 18075.42 90.00 306.53 6900.24 7080.70 13290.61 13317.98 13292.83 6944.47 -11626.10 0.59 2151610.29 157410.86 59.8765N94 -151.86438398 16170.10 90.37 306.12 %99.27 7079.73 13384.91 13412.65 13386.74 6500,55 -11702.46 0.63 2151668.43 157336.13 59.87665817 -151.811509936 16264.16 90.46 305.50 6898.59 7079.05 13478.48 135%.71 13480.15 6555.59 -11"814 D.67 2151n5.52 157261.38 59.87680852 -151.%551474 TIe-In Survey 16386.71 91.26 303.76 6897.20 70n.68 13570.71 13599.25 13572.25 6608.17 -11854.% 2.07 2151100.15 157186.69 59.87695218 -151.85592938 16451.61 90.05 304.06 680.12 7076.58 13665.38 13694.14 13666,82 6661.11 -11933.63 1.31 2151835.22 157109.41 59.8"O9%D -15I.N635822 16544.% 89.74 303.61 68%.29 7076.75 13757.63 137%.59 13758.96 6712.59 -12D10.42 0.59 215180.76 157034.4 59.87723742 -151.86677890 16638.34 89.96 302.74 68%.54 70".00 13851.76 13880.82 13853.02 6764.18 -12089.34 0.95 2151942.48 156956.56 59.87731834 -151.86720611 16731.68 89.84 302.47 68%10 70".16 13905.00 13924.21 13946.20 8814.47 -12167.96 0.32 2151994% 1%879.33 59.82751572 -151.%763429 16825.40 89.92 MIM 6896.89 7077.35 1403862 14%7.93 14039.82 8%3.92 -12247.58 1.34 2152046.49 156801.09 59.87765077 -151.06806781 16919.29 90.27 301.55 6096.74 70n.20 14132.53 14161.82 14133.65 6912.82 -12327.73 0.51 2152097.55 1%722.29 59.87"8432 -151.%850427 17013.54 90.51 WAS 6896.10 7076.56 14n6,75 142%.06 14227.82 6%2.08 -124%.0 0.27 2152148.0 156643.31 59.87791587 -151.86894179 Ti"n Survey 17108.93 91.86 301.29 6894.12 7074.58 14322.09 14351.43 14323.13 7011.75 -12489.49 1.43 2152200,84 196563.28 59.87805452 -151.%938513 17201.27 9011 302.00 6892.05 707251 14414.36 14%3.75 14415.36 7060.24 -12568,04 1.51 2152251.45 156486.07 $9.87818695 -151.86981291 17293." 9DA7 WIN 6891.10 7071.56 145N.4D 14535.91 14507.34 7110.40 -12645.35 1.97 2152303.70 156410.15 59.87832391 -151.87023392 17387.35 9032 303.52 6890.54 7071.00 1460DAI 14629.82 14600.98 7162.51 -12723.48 0.47 2152357.91 156333.46 59.87846629 -151.87%5940 17481.25 90,79 303.23 6889.21 7070.17 14693.85 14n372 14696.65 7214.16 -128D1,99 0.0 2152411.68 156256.48 59.8780738 -151.87108642 17575.21 90.74 302.65 6888.46 7068.92 14787.62 14817.67 14780.42 7265.25 -12880.74 0.62 2152464.90 1%179.05 59.87874691 -151.87151582 17671.52 90.13 302.01 6887.73 7%8.19 14883.90 14913.97 14%4.80 7316.75 -12962.12 0.92 2152518.59 1%099.10 59.878%750 -151.87195899 17764.94 90.99 302.47 68%.81 7067.27 14977.24 15007,39 14972.91 7366.59 43041.13 1.04 2152570.56 156021.48 59.8790230 -151.67238928 11%7.58 so," 304.02 6885.27 7066.23 15069.72 15100.02 15070.34 7417.37 -13118.60 1.83 2152623.43 155945.41 59.82916238 -151.87281119 Tio-ln Survey 17162.67 90.90 305.17 68".n 70155.23 15164.50 15195.11 15165.04 7471.35 -13196.67 136 2152679.52 155868.64 59.870W983 -151.873237" 100".8 92.92 305.67 6881.71 7062.17 15255.99 15287.00 15256.45 7524.61 -13271.76 2.26 2152734.80 155785.22 59,87945531 -151.87364538 _ 18140.54 89.72 304.42 6879.0 7059.96 15351.49 15382.88 15351.89 7579.67 -13350.25 3.58 2152791.97 155710.25 59.87960569 -151.8740729C 18234.53 90.17 303.92 6879.59 700.05 15"5.23 15416.87 15"5.59 7632.46 43428.02 on 2152846.06 155841.95 59.87974988 -151.87"9643 18328.87 89.87 304.09 6079.56 200.02 15539.34 15571.21 15539.65 7685.22 -13506.23 0.37 2152901.73 155565.20 59.8798930 -151.87492238 1%22.51 69.75 301.99 6879.87 7060.33 15632.85 15664.85 15633.12 7736.27 -13584.72 2.25 2152954.89 155488.13 59,88003340 -151.875349% 18516.45 89.73 300.82 6080.29 7%0.75 15726.76 15258.29 15M7.01 7785.22 -13654.89 1.25 2153006.01 155409.31 59.8%16707 -151.07578853 111610.48 89.63 299.71 6880.82 7051.28 15020.78 15852.82 15821.04 7832.61 -13746.11 1.19 2153055.59 155329.41 59.11N29646 -151.87622881 Tio-ln Survey 18703.08 09.0 298.32 081.13 7%1.59 15913.38 15945.42 15913.64 7878.23 43826.69 0.57 2153103.38 155250.10 59.8842101 -151.87%67% 18773.37 0.97 301.48 000.55 7%1.01 15983.66 16015.71 1503.91 7913.79 -13%2.31 3.38 2153140.58 155190.47 59.8851812 -151.87699780 18%6.23 89.59 301.87 6880.10 7%0.56 16076.48 16108.56 16D76.71 7062.55 -13966.33 1,54 2153191.47 155112.8 59,08065127 -151.8"42820 18957.01 90.17 303.16 6880.29 700.75 16167.17 16199.34 16167.30 0011.35 -14042.88 1.56 2153242.33 155037.60 59.88078451 -151.87764512 19050.46 09.30 2%.16 6880." 7061.18 16260.58 16292.79 16260.70 8059.69 -14122.83 4.38 2153292.83 154958.99 59.%091651 -151.878280% 19145.05 90.11 303.40 6881.21 1%1.67 16355.12 16387.38 16355.31 810819 -14203.65 4.56 2153344.11 154879,54 59.%105058 -151.67872D74 19243.26 89." 3%.57 6881.59 7062.05 16452.94 16485.59 16453.10 8165.09 -14284.10 3.30 21534D2.58 154ND.64 59.88120435 -151.87915897 19338.32 89,54 307.03 082." 702.90 16547.33 16580.64 18547." 8222.03 -1438.22 0.50 2153461.57 154126.10 59.88135988 -151.87957359 19431.01 8.n 307.48 6883,00 7063.6 16640.07 16674.13 16640.14 8278.63 -1"34.63 0.54 2153520.17 159853.26 59,%151"7 -151.87997895 Tre In Survey 19524.85 90.62 307.32 6882.69 7063.15 16732.33 16767.17 16732.37 8335.14 -14508.54 0.93 2153578,67 154580.91 59.88966082 -151 880%159 19611.52 88.68 3%.77 6883.25 7063.71 16824.30 18859.83 16824.31 8390.% -14582.50 2.18 2153636.49 154500.49 59.88182130 -151.6807"N 19710.53 88.71 306.22 6805.37 7%5.83 16916.69 16952.82 16916.69 8446.27 -14657.25 0.59 2153693.80 154435.21 59.88197235 -151.88119172 Cosmopolitan UniMosmoplitan PaMIAMIi18\H16 Drilling Office 2.10.302.0 . Schlumberger -Private 1/7/2019 3:32 PM Page 4 of 5 Comments MD Met Aaim True TVDSS TVD VSEL AHD Closure NS EW DLS No Ming Easting Latitude Lon8Ru6e IRI 1-) 1.1 IRI IRI IR) (ft) 1111 IRI Iltl (.110011) (RIISI IRUS) 11 11 19800.71 88.43 305.59 6887.72 7068.18 17010.34 1]046.9] 17010.34 8501.48 -14733.51 on 2153751.07 15436054 59.80212315 -151.88160715 19899.23 89.98 300.59 589.03 7069.49 171N.47 17141.48 17104.47 8555.81 -14810.84 1.95 2153607.48 15428411 59.88227152 -151.80202840 1901 9044 303.46 6888.69 7069.15 17197.47 1]234.]1 17197.47 0607.97 -14888.11 1.31 2153861.73 154208.89 59,88241397 -151,88204929 20088.73 90.04 302." 6888.30 7068.76 1]291,61 17328.98 17291.62 8659.25 -14967.21 1.16 2153915.14 154131.20 59.88255397 -151.88288018 Tia1. Survey 20180.74 89.81 300.79 6888.42 7068.88 17305,58 17422.99 17385.59 8706.53 -1547.27 1.77 21539116.58 154052.52 59.88268852 -151.88331624 20274.59 89.]7 29939 6888.76 7069.22 17479.43 17516.84 17479." 8755.86 -15128.31 1.07 2154016.10 1539]2.80 59.88281773 -151.08375763 20367.92 89.27 300.32 6889.54 7070.00 17572.75 17810.16 1]572.]6 8802.60 -15209.08 0.78 2154065.02 153893.32 59.88294533 -151.88419761 20462.82 87.00 300.38 6892.63 7073.09 17667.59 17705.01 17867.61 8650.52 -15290.93 2.39 2154115.15 153812.80 59.88307615 -1$1.88464342 20557.21 86.67 300.14 6897.84 7078.30 17761.84 17799.25 17761.85 8898.02 -15372.33 0.43 2154164.84 153732.72 59.88320580 -151.88508682 20649.56 91.34 301.42 6899.45 ]0]9.91 17854.14 17891.56 17854.15 8945.25 -15451.64 5.24 2154214.22 153654.72 59,88333475 -151.88551080 207".09 91,04 301.38 597.48 7077.94 17948.61 17986.06 17948.63 8994.49 -15532.30 o32 21M265.63 153675.43 59.88346917 -151.88595818 20837.88 9186 301.83 6895.11 7075.57 18042.34 18079.83 18042.36 9043.63 -15612.16 1.00 21M316.92 153496.93 59.88360332 -161.88639320 20930.87 91.94 302.25 6892.03 7072.49 18135.22 18172.77 18135.25 9092.94 -1590.94 0.46 2151368.35 153419.52 59.88373793 -151.88682236 21024.10 90.64 302.48 6889.93 7070.39 18228.35 18265.97 18228.38 9142.83 -15769.67 1.42 215"20.37 153342.18 59.80387414 -151.80725122 Tie-in Survey 21118.72 9D.61 301.35 6888.90 7069.36 18322.91 1035.59 18322.94 9192.85 -15849.5 1.19 215"72.56 153263.25 59.88401089 -151.88768870 21212.17 90.55 302.41 6887.95 7068.41 18416.30 18454.03 18416.34 9242.20 -15929.33 1.14 2154524.05 153185.28 59.88414542 _ -151.80812095 21306.16 89.55 302.21 6887.87 7068.33 1851D.21 18548.02 18510.26 9292.44 -1506.76 1.09 2154576.43 153107.23 59.88428257 -151,8885559 21400.52 90.14 301.81 6888.12 7068,58 18804.51 18642.38 18604.57 9342.45 4588.78 0.76 2150628.60 153028.61 59.88441911 -151.88898957 21493.99 90.02 302.33 6887.99 7068.45 18697.92 18735.85 18697.99 9392.08 -16167.98 0.57 2154680.37 152950.78 59.88455459 -151.88942106 21587.58 89.79 302.69 6888.15 7068.61 18791.42 13029." 18791.50 9442.38 -16246.91 0.46 2154732.79 152873.25 59.88469191 -151.88985102 21681.42 son 303.05 6088.03 7058A9 18885.15 18923.28 18885.24 9493.31 -16325.72 0.71 2154785,85 152795.85 59.88483095 -151.89028040 21774.79 89.90 303.32 6887,03 7066.29 18978.37 19016.65 18978.08 95".41 -16403.86 0.5 2154839.06 152719.12 59.88497047 -151.89070611 21868.95 90.49 304.60 6887.51 7067.97 19072.30 19110.81 19072.43 9597.01 -16481.96 1.50 2154893.76 152842.48 5988511408 -151.09113160 21963.49 91.20 304,62 6888.12 705.5 19166,53 19205.34 19166.68 965]0 -16559.76 0.75 2154949.55 15256,17 59.8852507 -151.89155549 2205.50 94.21 304.80 688113 7062.19 19259.11 19298.23 19259.30 9703.60 -16636.13 3.24 2155004.51 152491.27 59.8054D510 -151.89197155 22150.45 96.46 305.13 6872.99 7053.45 19352.29 19391.77 19352.52 9757.20 -16712.78 2.02 21555.18 162416.10 59.88555145 -151.8923892D 22231.96 98.53 305.63 6862.38 7042.82 19432.75 19472.5 19433.01 Noses -16778.67 2.61 215510.74 152351.51 59.8857920 -151.89274820 22310.00 98.53 305.63 6850.78 7031.24 1959.55 19549.76 1959.05 9848.95 -16841.40 0.5 2155155.39 152290.02 59.8855196 -151.89308999 Survey Error MoBel: ISCWSA Rev 0 •-- 3D 95.000%Confeenca 2.7955 sigma SurvsY P"..; Dea ripthm Pertmy e w raw em wa��y.a.-..e Survey TOW Time Bo / Saw., 1 0.000 1200.030 AU Sine 17.500 13.375 SLB CNSG+CASING H16PS1 B1 IHi8Pa1 1 1200.030 4126.100 AU Sins 17.55 13.375 SLB_1WDSGMAG H16PB1 I H16PB1 1 4126.100 1"96.250 AU Sins 12.250 9.625 SLB VW MAG H16PB11 H16PB1 1 1"96.250 14762.380 AU Sins 8.50 0.50 SLB_M INCONLY_FILLER H16A-1-01I 1116A-101 1 14762.300 1635.710 AU Sins B.500 0.00 SLB MW GMAG HIM-LD1I 1-116A-101 1 1635.710 17108.930 AU Sins 8.50 0.50 SLB_1WDrGMAG 1-116A-1-021 1-116A-102 1 17100.930 17952.670 AU Stns 8.500 0.50 SLBMWD«GMAG 1-116A-1031 H16A-1-03 1 17952.670 18703.05 AU SMs 8.50 0.05 SLB_MWDrGMAG H16A-1_041 H16A-LD4 1 18703.OM 19524.85 AU Sine 8.50 0.000 SLBMWD+GMAG H16A-L051 Hi6A-1-05 1 19524.85 20180.740 AU SMs 8,500 0.05 SLBMWDtGMAG H16A-L06l HIM -LW 1 20100.740 21118.720 Ad SMs 8.55 0.05 SLB_MWD+GMAG H16ML07I HIM -1-07 1 21118.720 22231.960 Act Stns 8.55 5.500 SLB_MWD+GMAG HIM H16A 1 22231.960 22310.000 AU Stns 8.500 5.500 SLB_BUNDrTREND HIM /H16A Cosmopolitan Unit\Cosmoplitan Pad\H76\H16\H76 Drilling Office 2.10.302.0 . Schlumberger -Private 1/7/2019 3:32 PM Page 5 of 5 H16A Fishbone Well Naming & Numbering Index KOP TO Lateral Lateral Planned Actual Actual Footage Volume (bbls) H -16A Mainbore Well Name PTD No. from AOGCC API No. from AOGCC Final TD (MD) Notes 16382 16375 17440 1065 75 H16A Mainbore 218-095 50-231-20051-01-00 22310 Final completed wellbore with 4-1/2" slotted liner in 8-1/2" hole H16A-1-01 218-096 50-231-20051-60-00 17440 8-1/2" Open Hole completion H16A-L02 218-097 50-231-20051-61-00 18390 8-1/2" Open Hole completion H36A-L03 218-098 50-231-20051-62-00 19268 8-1/2" Open Hole completion H16A-L04 218-099 50-231-20051-63-00 20020 8-1/2" Open Hole completion H16A-L05 218-100 50-231-20051-64-00 20743 8-1/2" Open Hole completion H16A-L06 218-101 50-231-20051-65-00 21340 8-1/2" Open Hole completion H16A-1-07 218-102 50-231-20051-66-00 21860 8-1/2" Open Hole completion KOP TO Lateral Lateral Planned Actual Actual Footage Volume (bbls) H -16A Mainbore 14552 22310 7758 544 101 16382 16375 17440 1065 75 L02 17180 17130 18390 1260 88 L03 17980 18000 19268 1268 89 L04 18780 18770 20020 1250 88 L05 19580 19525 20743 1218 85 L06 2038220270 21340 1070 75 L07 21180 21165 21860 695 49 Total 15584 1094 X (NAD27) Y (NAD27) TVDSS TVD MD Legal Description H16A Mainbore KOP (Top of Production) 158612.43 2150676.24 -6905.01 7085.44 14552 2663' FSL, 1350' FEL, Sec. 33, T3S, R15W SM TD 152294.39 2155159.54 -6850.78 7031.21 22310 1685' FSL, 2505' FEL, Sec. 29, T3S, R15W SM H16A-LO3 KOP (Top of Production) 157171.72 2151790.8 -6896.63 7077.06 1637513737' FSL, 2820' FEL, Sec. 33, T3S, R15W SM TD 156331.17 2152368.86 -6616.64 6797.07 17440 4291' FSL, 3676' FEL, Sec. 33, T3S, R15W SM H16A-L02 KOP (Top of Production) 156545.57 2152212.42 -6893.22 7073.65 17130 4141' FSL, 3458' FEL, Sec. 33, T3S, R15W SM TD 155562.48 2152898 -6557.67 6738.1 18390 4798' FSL, 4459' FEL, Sec. 33, T3S, R15W SM H16A-L03 KOP (Top of Production) 155830.73 2152708.02 -6883.44 7063.87 18000 4616' FSL, 4186' FEL, Sec. 33, T3S, R15W SM TD 154839.79 2153390.79 -6517.97 6698.4 19268 5271' FSL, 5195' FEL, Sec. 33, T35, R15W SM H16A-L04 KOP (Top of Production) 155193.13 2153138.68 -6880.05 7060.48 18770 5029' FSL, 4835' FEL, Sec. 33, T3S, R15W SM TD 154212.01 2153816.15 -6536.42 6716.85 20020 396' FSL, 552' FEL, Sec. 29, T3S, R15W SM H16A-L05 KOP (Top of Production) 154580.74 2153578.86 -6882.68 7063.11 19525 169' FSL, 177' FEL, Sec. 29, T3S, R15W SM TD 153610.04 2154226.91 -6571.82 6752.25 20743 790' FSL, 1165' FEL, Sec. 29, T3S, R15W SM H16A-L06 KOP (Top of Production) 153976.65 2154013.78 -6887.91 7068.33 20270 587' FSL, 793' FEL, Sec. 29, T3S, R15W SM TD 153105.84 2154577.4 -6649.98 6830.41 2134011126' FSL, 1678' FEL, Sec. 29, T3S, R15W SM H16A-L07 KOP (Top of Production) 153224.51 2154498.02 -6887.64 7068.07 2116511050- FSL, 1558' FEL, Sec. 29, T3S, R15W SM TD 1 152675.821 2154902.24 -6759.78 6940.21 2186011438- FSL, 2117' FEL, Sec. 29, T3S, R15W SM H16A Actual MW vs. Depth Data Table Days Depth MW From MD ppg Operational Notes Spud 0 8.3 Kill well with water for sidetracking; pull tubing 3 0 8.3 Kill well with water for sidetracking; pull tubing 4 0 8.3 Kill well with water for sidetracking; pull tubing 5 0 8.3 Kill well with water for sidetracking; pull tubing 6 0 8.3 Kill well with water for sidetracking; pull tubing 7 0 8.3 Set Bridge Plug / Pressure Test Casing 8 0 9.2 Swap to 9.2 ppg CBM 9 0 9.2 RIH w/ Whipstock & Mill BHA 10 14538 9.2 Set Whipstock 11 14544 9.2 Mill Window in 9-5/8" Casing 12 14569 9.2 RIH w/ new mill BHA / drill new hole 14569', FIT to 11.9 ppg 13 14582 9.2 Cure losses w/ LCM / drill w/ mill to 14582' MD / POOH 14 14582 9.2 POOH / fix top drive / service rig 15 14582 9.2 POOH w/ mill BHA / test BOP / make up motor BHA / RIH 16 14622 9.2 RIH w/ motor BHA / drill new hole to 14622' MD 17 14735 9.2 Drill new 8-1/2" hole to 14735' MD / pump put for RSS BHA 18 14735 9.2 POOH w/ motor BHA / test BOP / RIH w/ RSS BHA 19 14795 9.2 RIH thru window and to TD / drill new hole to 14795' MD 20 16336 9.2 Drill w/ RSS BHA / hi torque add lubes / drill to 16336' MD 21 17440 9.2 Drill L01 lateral to 17440' MD / backream & trench for L02 22 18214 9.3 Trench / sidetrack / drill L02 lateral to 18214' MD 23 18390 9.2 IStuck pipe / backream / drill L02 to 18390' MD / trench to L03 24 18592 9.3 Sidetrack & drill L03 to 18592' MD 25 19268 9.2 Drill L03 to TD of 19268' MD. Backream and trench for L04 26 18122 9.2 Drill L04 lateral to 18122' MD 27 20020 9.3 Finish drilling L04 lateral to TD of 20020' MD and backream same 28 20020 9.3 Backream to casing window / CBU / prep to TOH for new BHA 29 20020 9.3 Backream to inside casing / pump out of hole 30 20020 9.3 Pump out / LDDP / DP management / inspect BHA 31 20020 9.2 LD BHA 05 / Manage & LD DP for hard banding 32 20020 9.2 BOP Test / manage DP / hardband / PU BHA 06 33 20020 9.2 BOP Test / PU RSS BHA 06 / RIH on 5-1/2" DP 34 20020 9.2 RIH BHA 06 managing DP, 5-1/2" x 4-1/2" x 5-1/2" design 35 20020 9.3 RIH / circ well clean / RIH to window depth 36 18860 9.2 RIH / search for LOS trench / drill ahead in LOS w/ RSS BHA 06 37 20743 9.3 Drill L05 lateral to TD of 20743' MD / C&C / BROOH for L06 38 19881 9.2 BR & trench for L06 lateral / drill L06 to 19881' MD 39 20350 9.2 Drill & TD L06 / BROOH to trench for L07 40 20925 9.2 Trench for L07 / Drill ahead to L07 KOP at 20925' MD 41 21850 9.2 Drill L07 fishbone lateral to 21850' MD 42 21850 9.2 Drill L07 to TD at 21860' MD / BROOH / Trench & ST for L08 43 22310 9.2 Drill L08 to well TD at 22310' MD / BROOH for liner 44 22310 9.2 IBROOH from well TD to 15003' MD 45 223101 9.2 IBROOH to inside 9-5/8" / BROOH / Pump out for liner/ LDDP 1 46 22310 9.2 BROOH to inside 9-5/8" / BROOH / Pump out for liner / LDDP 47 22310 9.2 Test BOPE / start picking up 4-1/2" liner 48 22310 9.2 Run 4-1/2" liner on drill pipe 49 22310 9.2 Run 4-1/2" liner on drill pipe / land in L02 - wrong lateral 50 22310 9.2 POOH w/ 4-1/2" liner after running into L02 wrong lateral 51 22310 9.2 MU Clean Out BHA & RIH 52 22310 9.2 JDP management / RIH w/ clean out BHA / ream L02 area 53 22310 9.2 Clean out mainbore in preparation for re -running liner 54 22310 9.2 Check L02 area for liner entry - OK; BROOH for liner re -run 55 22310 9.2 BROOH; 7.2 earthquake hit; ream back to bottom to check hole 56 22310 9.2 Clean out to 21826'; BROOH; check L02 area for liner run 57 22310 9.2 BROOH to window; CBU / pump out for liner re -run 58 22310 9.2 Pump out / POOH on elevators for liner re -run / test BOPE 59 22310 9.2 Test BOPE / MU flex joint shoe track and run 4-1/2" slotted liner 60 22310 9.2 RU & run 4-1/2" slotted liner w/ flex joint shoe track 61 22310 9.2 Run liner on 5-1/2" DP / work liner past L02 junction / set same at TD 62 22310 9.2 Drop ball / set hanger & liner top packer / test to 3K / swap to 9.2 ppg brine 63 22310 9.25 POOH LDDP / hole static w/ 9.2 ppg brine / clean pits 64 22310 9.25 LDDP / RU to run 3-1/2" upper completion w/ control lines 65 22310 9.25 Run 3-1/2" / stop since handling pup ran in error / POOH 66 22310 9.25 Take out incorrect pup / RIH w/ 3-1/2" upper completion 67 22310 9.25 1 Run & land upper completion / connect control lines 68 H16A TO 22310 9-5/8"TOW 14538 Lower Completion 4.5" Liner Set Depth 21510.00 Liner Lap 157 Joint Count Category Component Length Cum Length BTM TOP OD 10 Drift Note Flex Joint WWT International Flex Jr. Assembly 21.95 21.95 21510.00 21488.05 5.22 3.86 3.86 I Liner_35.2ppf 1 38.87 60.82 21488.05 21449.18 4.50 3.83 3.70 2 Slotted Liner 15.2p 2 37.49 98.31 21449.18 21411.69 4.50 3.83 3.70 3 Liner_35.2ppf 3 38.66 136.97 21411.69 21373.03 4.50 3.83 3.70 4 SlotteCiLineE_15.2ppf 4 36.39 173.36 21373.03 21336.64 4.50 3.83 3.70 5 Liner_15.2ppf 5 38.78 212.14 21336.64 21297.86 4.50 3.83 3.70 6 Slotted Liner -15.2oDf 6 36.51 248.65 21297.86 21261.35 4.50 3.83 3.70 7 Liner_15.2ppf 7 39.42 288.07 21261.35 21221.93 4.50 3.83 3.70 8 Slotted Liner 15.2ppf 8 36.43 324.50 21221.93 21185.50 4.50 3.83 3.70 9 Liner 15.2ppf 9 38.66 363.16 21185.50 21146.84 4.50 3.83 3.70 L07 TOP =21165' 30 Slotted Liner 15.2ppf 10 36.18 399.34 21146.84 21110.66 4.50 3.83 3.70 11 Liner_15.2ppf 11 38.96 438.30 21110.66 21071.70 4.50 3.83 3.70 12 Slotted Liner 15.Zppf 12 39.03 477.33 21071.70 21032.67 4.50 3.83 3.70 13 Liner_15.2ppf 13 35.89 513.22 21032.67 20996.78 4.50 3.83 3.70 14 Slotted trier 15.2 pf 14 36.72 549.94 20995.78 20960.06 4.50 3.83 3.70 15 liner_15.2ppf 15 38.62 588.56 20960.06 20921.44 4.50 3.83 3.70 16 Slotted -Liner -35.2 pf 16 35.24 623.80 20921.44 20886.20 4.50 3.83 3.70 17 Liner 15.2 f 17 39.14 662.94 20886.20 20847.06 4.50 3.83 3.70 18 Slotted Liner 15.2ppf 18 36.72 699.66 20847.06 2081D.34 4.50 3.83 3.70 19 Liner_35.2ppf 19 38.64 738.30 20810.34 20771.70 4.50 3.83 3.70 20 Slotted Liner_15.2ppf 20 36.25 774.55 20771.70 20735.45 4.50 3.83 3.70 21 Liner_I5.2ppf 21 38.98 813.53 20735.45 20696.47 4.50 3.83 3.70 22 Slotted Liner_35.2ppf 22 35.89 849.42 20696.47 20660.58 4.50 3.83 3.70 23 Liner_35.2ppf 23 38.65 888.07 20660.58 20621.93 4.50 3.83 3.70 24 Slotted Liner 15.2ppf 24 38.54 926.61 20621.93 20583.39 4.50 3.93 3.70 25 Liner_35.2ppf 25 35.24 961.85 20583.39 20548.15 4.50 3.83 3.70 26 Slotted_ Liner_15.2ppf 26 38.65 1000.50 20548.15 20509.50 4.50 3.83 3.70 27 Liner_15.2ppf 27 38.66 1039.16 20509.50 20470.84 4.50 3.83 3.70 28 Slotted_ Liner_35.2ppf 28 36.59 1075.75 20470.84 20434.25 4.50 3.83 3.70 29 Liner_15.2ppf 29 38.98 1114.73 20434.25 20395.27 4.50 3.83 3.70 30 Slotted Liner_15.2ppf 30 30.71 1145.44 20395.27 20364.56 4.50 3.83 3.70 31 Liner_15.2ppf 31 39.27 1184.71 20364.56 20325.29 4.50 3.83 3.70 32 Slotted Liner 15.2o Df 32 35.78 1220.49 20325.29 20289.51 4.50 3.83 3.70 33 Liner_15.2ppf 33 39.64 1260.13 20289.51 20249.87 4.50 3.83 3.70 L06 KOP =20270' 34 Slotted Liner 15.2 pf 34 34.61 1294.74 20249.87 20215.26 4.50 3.83 3.70 35 Liner_15.2ppf 35 40.05 1334.79 20215.26 20175.21 4.50 3.83 3.70 36 Slotted Liner 15.2Dof 36 36.90 1371.69 20175.21 20138.31 4.50 3.83 3.70 37 Liner_15.2ppf 37 41.52 1413.21 20138.31 20096.79 4.50 3.83 3.70 38 Slotted Liner 15.2ppf 38 38.52 1451.73 20096.79 20058.27 4.50 3.83 3.70 39 Liner_15.2ppf 39 41.54 1493.27 20058.27 20016.73 4.50 3.83 3.70 40 Slotted_ Liner_15.2opf 40 38.98 1532.25 20016.73 19977.75 4.50 3.83 3.70 41 Liner_15.2ppf 41 40.09 1572.34 19977.75 19937.66 4.50 3.83 3.70 42 Slotted Liner 15.2ppf 42 36.64 1608.98 19937.66 19901.02 4.50 3.83 3.70 43 Liner_35.Zppf 43 41.55 1650.53 19901.02 19859.47 4.50 3.83 3.70 44 Slotted Liner_35.2ppf 44 36.08 1686.61 19859.47 19823.39 4.50 3.83 3.70 45 Liner_15.2ppf 45 41.47 1728.08 19823.39 19781.92 4.50 3.83 3.70 46 Slotted Liner 152ppf 46 36.60 1764.68 19781.92 19745.32 4.50 3.83 3.70 47 Liner 15.2ppf 47 41.51 1806.19 19745.32 19703.81 4.50 3.83 3.70 48 Slotted Liner_35.2ppf 48 35.76 1841.95 1970391 19668.05 4.50 3.83 3.70 49 Liner 15.2 pf 49 41.33 1883.28 19668.05 19626.72 4.50 1 3.83 1 3.70 50 Slotted-Liner_15.2ppf 50 36.33 1919.61 19626.72 19590.39 4.50 3.83 3.70 51 liner 15.2ppf 51 41.46 1961.07 19590.39 19548.93 4.50 3.83 3.70 52 Slotted Liner 15.2p f 52 39.54 2000.61 19548.93 19509.39 4.50 3.83 3.70 LOS KOP =19525' 53 Liner_15.2ppf 53 41.51 2042.12 19509.39 19467,88 4.50 3.83 3.70 54 Slotted_ Liner_35.2ppf 54 37.46 2079.58 19467.88 19430.42 4.50 3.83 3.70 55 liner_35.2ppf 55 39.16 2118.74 19430.42 19391.26 4.501 3.83 3.70 56 ISloti_15.Zppf 56 36.17 2154.91 19391.26 19355.09 4.50 1 3.83 3.70 77 Liner_15.2ppf n 41.30 2975.68 18575.62 18534.32 4.50 3.83 3.70 78 Slotted_ Liner_15.2ppf 78 36.70 3012.38 18534.32 18497.62 4.50 3.83 3.70 79 Liner 15.2ppf 79 41.27 3053.65 18497.62 18456.35 4.50 3.83 3.70 80 Slotted Liner 15.2 pf 80 40.19 3093.84 18456.35 18416.16 4.50 3.83 3.70 81 Liner_15.2ppf 81 41.49 3135.33 18416.16 18374.67 4.50 3.83 3.70 82 Slotted_ Liner_15.2ppf 82 36.61 3171.94 18374.67 18338.06 4.50 3.83 3.70 83 Liner_35.2ppf 83 41.50 3213.4 18338.06 18296.56 4.50 3.83 3.70 84 Slotted_ Liner_15.2ppf 84 36.73 3250.17 38296.56 18259.83 4.50 3.83 3.70 85 Liner_35.2ppf 85 41.57 3291.74 18259.83 18218.26 4.50 3.83 3.70 86 Slotted Liner 15.2ppf 86 38.66 3330.40 18218.26 18179.60 4.50 3.83 3.70 8] Liner_15.2ppf 87 41.47 3371.8] 18179.60 18138.13 4.50 3.83 3J0 88 Slotted_Liner_15.2ppf 88 36.09 3407.96 18138.13 18102.04 4.50 3.83 3.70 89 Liner_15.2ppf 89 41.3] 3449.33 18102.04 16060.67 4.50 3.83 3.70 90 Slotted_Liner_SS.ippf 90 38.95 3488.28 18060.67 18021.]2 4.50 3.83 3.70 91 Liner 15.2ppf 91 41.36 3529.64 18021.72 1]980.36 4.50 3.83 3.70 L03 KOP =18000' 92 Slotted Liner_15.2ppf 92 31.52 3561.16 17980.36 17948.84 1 4.50 1 3.83 3.70 117 Liner 15.2ppf 117 40.20 4516.80 17033.40 16993.20 4.50 3.83 3.70 118 Slotted_Liner 15.2ppf 118 36.90 4553.70 16993.20 16956.30 4.50 3.83 3.70 119 Liner_15.2ppf 119 3895 4592.65 16956.30 16917.35 4.50 3.83 3.70 120 Slotted_ Liner_ 15.2ppf 120 36.37 4629.02 16917.35 16880.98 4.50 3.83 3.70 121 Liner 15.2ppf 121 39.27 4668.29 16880.98 16841.71 4.50 3.83 3.70 122 Slotted Liner 15.2ppf 122 36.60 4704.89 16841.71 16805.11 4.50 3.83 3.70 123 Liner 15.2ppf 123 38.79 4743.68 16805.11 16766.32 4.50 3.83 3.70 124 Slotted Liner 15.2ppf 124 39.13 4782.81 16766.32 16727.19 4.50 3.83 3.70 125 Liner 15.2ppf 125 38.90 4821.71 16727.19 16688.29 4.50 383 3.70 126 Slotted Liner 15.2ppf 126 39.13 4860.84 16688.29 16649.16 4.50 3.83 3.70 127 Liner 15.2 pf 127 38.96 4899.80 16649.16 16610.20 4.50 3.83 3.70 128 Slotted_Liner _35.2 f 128 33.50 4933.30 16610.20 16576.70 4.50 3.83 370 129 Liner 15.2ppf 129 38.99 4972.29 16576.70 16537.71 4.50 3.83 3.70 130 Slotted_Liner_35.2ppf 130 36.68 5008.97 16537.71 16501.03 4.50 3.83 3.70 131 Uner_15.2ppf 131 38.50 5047.47 16501.03 16462.53 4.50 3.83 3.70 132 Slotted Liner 15.2ppf 132 35.89 5083.36 16462.53 16426.64 4.50 3.83 3.70 133 Liner_35.2ppf 133 39.12 5122.48 16426.64 16387.52 4.50 3.83 3.70 134 Slotted Liner 15.2ppf 134 35.94 5158.42 16387.52 16351.58 4.50 3.83 3.70 135 Liner 15.2ppf 135 38.94 5197.36 16351.58 16312.64 4.50 3.83 3.70 L01 KOP =16375' 136 Slotted -Liner 15.2ppf 136 39.29 5236.65 16312.64 16273.35 4.50 3.83 3.70 137 Liner _15.2ppf 137 39.28 5275.93 16273.35 16234.07 4.W 3.83 370 138 Slotted Liner 15.2ppf 138 40.23 5316.16 16234.07 16193.84 4.50 3.83 3.70 139 Liner 15.2ppf 139 38.64 5354.80 16193.84 16155.20 4.50 3.83 3.70 140 Sbtted_ Liner_15.ippf 140 36.27 5391.07 16155.20 16118.93 4.50 3.83 3.70 141 Liner 15.2ppf 141 38.97 5430.04 16118.93 16079.96 4.50 3.83 370 142 Slotted_Liner_15.2ppf 142 34.20 5464.24 16079.96 16045.76 4.50 3.83 3.70 143 Liner 15.2ppf 143 38.94 5503.18 16045.76 16006.82 4.50 3.83 370 144 Slotted-Liner-15.2ppf 144 35.06 5538.24 16006.82 15971.76 4.50 3.83 3.70 145 Liner 15.2ppf 145 38.97 5577.21 15971.76 15932.79 4.50 3.83 3.70 146 Slotted Liner 15.2ppf 146 38.96 5616.17 15932.79 15893.83 4.50 3.83 3.70 147 Liner 15.2ppf 147 39.28 5655.45 15893.83 15854.55 4.50 3.83 3.70 148 Slotted Liner 15.2ppf 148 38.52 5693.97 15854.55 15816.03 4.50 3.83 3.70 149 Liner 15.2ppf 149 37.48 5731.45 15816.03 15778.55 4.50 3.83 3.70 150 Slotted Liner 15.2ppf 150 34.66 5766.11 15778.55 15743.89 4.50 3.83 3.70 151 Liner 15.2ppf 151 38.78 5804.89 15743.89 15705.11 4.50 3.83 3.70 152 Slotted Liner 15.2ppf 152 38.34 5843.23 15705.11 15666.77 4.50 3.83 3.70 153 Liner 15.2ppf 153 37.91 5881.14 15666.77 15628.86 4.50 3.83 3.70 154 Slotted Liner 15.2 pf 154 36.31 5917.45 15628.86 15592.55 4.50 3.83 3.70 155 1-iner_35.2ppf 155 38.85 5956.30 15592.55 15553.70 4.50 3.83 370 156 Slofted-l.,ner_15.Zppf 156 35.72 5992.02 15553.70 15517.98 4.50 3.83 3.70 157 Liner IS 2ppf 157 38.97 6030.99 15517.98 15479.01 4.50 3.83 3.70 158 Slotted_Liner_3S.2ppf I58 38.96 6069.95 15479.01 15440.05 4.50 3.83 370 159 Liner 15.2ppf 159 38.97 6108.92 15440.05 15401.08 4.50 3.83 3.70 160 Slotted Liner_35.2ppf 160 36.78 6145.70 15401.08 15364.30 4.50 3.83 3.70 161 Liner 15.2ppf 161 38.65 6184.35 15364.30 15325.65 4.50 3.83 3.70 162 Slotted -Liner _15.2ppf 162 36.11 6220.46 15325.65 15289.54 4.50 3.83 3.70 163 Liner 15.2ppf 163 38.99 6259.45 15289.54 15250.55 4.50 3.83 3.70 164 Slotted-Liner35.2ppf 164 38.91 6298.36 15250.55 15211.64 4.50 3.83 370 165 Liner 15.2ppf 165 38.65 6337.01 15211.64 15172.99 4.50 3.83 3.70 166 Slotted_Llner_15.2ppf 166 35.96 6372.97 15172.99 15137.03 4.50 3.83 3.70 167 Liner_35.2ppf 167 38.96 6411.93 35137.03 15098.07 4.50 3.83 3.70 168 Slotted Liner 15.29pf 168 38.80 6450.73 15098.07 15059.27 4.S0 3.83 3.70 169 Liner 15.2ppf 169 39.13 6489.86 15059.27 15020.14 4.50 3.83 3.70 170 Slotted_ Liner 15.2ppf 170 33.47 6523.33 15020.14 14986.67 4.50 3.83 3.70 171 Uner_15.2ppf 171 39.60 6562.93 14986.67 14947.07 4.50 3.83 3.70 172 Slotted Liner 15.2ppf 172 35.72 6598.65 14947.07 14911.35 4.50 3.83 3.70 173 Liner 15.2ppf 173 39.13 6637.78 14911.35 14872.22 4.50 3.83 3.70 174 Slotted Liner 15.2 f 174 38.95 6676.73 14872.22 14833.27 4.50 3.83 3.70 175 Liner 15.2ppf 175 38.96 6715.69 14833.27 14794.31 4.50 3.83 3.70 176 ISlofted_ Liner_35.2ppf 176 36.88 6752.57 14794.31 14757.43 4.50 3.83 3.70 177 Liner 15.2ppf 177 39.15 6791.72 -- 14757.43 14718.28 4.50 3.83 3.70 178 Slotted _Uner_15.2ppf 178 38.96 6830.68 14718.28 14679.32 4.50 3.83 3.70 179 Liner_15.2ppf 179 38.65 6869.33 14679.32 14640.67 4.50F12 3.70 180 Slotted _Uner_35.2ppf 180 36.64 6905.97 14640.67 14604.03 4.503.70 181 Liner_15.2ppf 201 41.57 6947.54 14604.03 14562.46 4.503.70 182 Liner_15.2ppf 202 41.44 6988.98 14562.46 14521.02 4.503.70 183 Liner_15.2ppf 203 41.46 7030.44 14521.02 14479.56 4.503.70 184 Liner 15.2 pf 204 41.47 7071.91 14479.56 14438.09 4.503.70 CHECK SLB Equip Crossover 5-1/2" TSH-521 Boa a 41/2' TSH-569 Pin 1.53 7073.44 14438.09 14436.56 5.802.87 CHECK SLB E ui PBR 16.58 7090.02 14436.56 14419.98 6.004.75 CHECK SLB Equip 5-1/2' TSH-521 Pu Joint 14.68 7104.70 14419.98 14405.30 5.504.T7CHECK SLB E ui ColossusUnerRanger 24.78 7129.48 14405.30 14380.52 8.336.19 CHECK SLB Equip Handling Pup 11.03 7140.51 14380.52 14369.49 1 7.20 2.75 0.00 CHECK ISLE, Equip Crossover 41/2' IF Pin a HT-55 Boa 3.83 7144.34 14369.49 14365.66 1 6.97 3.00 0.00 TOW 14538.00 9-5/8 Shoe 14767.00 Shoe to TOW 229.00 TOL 14380.52 Liner Lap 157.48 Liner Shoe 21510.00 Locator Crossover 14380.52 ASSY# Std# Joint Count Category Component Length Cum Length BTM TOP OD ID Drift Note SLB_Equip Seal Assembly 1, 4.78 4.78 14434.55 14429.77 4.75 3.755 3.68 SLB_Equip 3-1/2 TSH -511 Pup Jt Assembly 49.25 54.03 14429.77 14380.52 3.50 2.992 2.867 SLB_Equip Locator Sub 1.25 55.28 14380.52 14379.27 8.50 2.992 2.867 SLB_Equip Crossover 3-1/2" TSH -563 Box x EU E Pin 2.92 58.20 14379.27 14376.35 4.25 2.99 2.87 1 Tubing_9.3ppf 1 31.08 89.28 14376.35 14345.27 3.50 2.992 2.867 2 Tubing_9.3ppf 2 31.13 120.41 14345.27 14314.14 3.50 2.992 2.867 LB_Equip SGM Bottom Pup (9.3# EUE8rd BOX x HS63 9.2# PIN) 9.62 130.03 14314.14 14304.52 5.12 2.992 2.867 1 SLB, Equip 3-1/2,9.30,SGM 6.5 136.53 14304.52 14298.02 5.12 2.918 2.867 -§Jj�jquip SGM Top Pup (94# K5-53 BOX x 9.3# EUE8rd PIN) 9.43 145.96 14298.02 14288.59 5.12 2.992 2.867 3 Tubing_9.3ppf 3 31.16 177.12 14288.59 14257.43 3.50 2.992 2.867 4 Tubing_9.3ppf 4 30.98 208.10 14257.43 14226.45 3.50 2.992 2.867 5 Tubing_9.3ppf 5 31.07 239.17 14226.45 14195.38 3.50 2.992 2.867 6 Tubing_9.3ppf 6 31.04 270.21 14195.38 14164.34 3.50 2.992 2.867 7 Tubing_9.3ppf 7 31.09 301.30 14164.34 14133.25 3.50 2.992 2.867 8 Tubing_9.3ppf 8 32.72 334.02 14133.25 14100.53 3.50 2.992 2.867 9 Tubing_9.3ppf 9 32.76 366.78 14100.53 14067.77 3.50 2.992 2.867 10 Tubing_9.3ppf 10 32.8 399.58 14067.77 14034.97 3.50 2.992 2.867 11 Tubing_9.3ppf 11 30.97 430.55 14034.97 14004.00 3.50 2.992 2.867 12 Tubing_9.3ppf 12 30.95 461.50 14004.00 13973.05 3.50 2.992 2.867 13 Tubing_9.3ppf 13 31.02 492.52 13973.05 13942.03 3.50 2.992 2.867 14 Tubing_9.3ppf 14 30.96 523.48 13942.03 13911.07 3.50 2.992 2.867 15 Tubing_9.3ppf 15 31.13 554.61 13911.07 13879.94 3.50 2.992 2.867 16 Tubing_9.3ppf 16 31.04 13879.94 13848.90 3.50 2.992 2.867 17 Tubing_9.3ppf 17 30.93 L jJ11111iff 13848.90 13817.97 3.50 2.992 2.867 18 Tubing_9.3ppf 18 31.11 13817.97 13786.56 3.50 2.992 2.867 19 Tubing_9.3ppf 19 31.13 678.82 13786.86 13755.73 3.50 2.992 2.867 20 Tubing_9.3ppf 20 31.1 709.92 13755.73 13724.63 3.50 2.992 2.867 21 Tubing_9.3ppf 21 30.92 740.84 13724.63 13693.71 3.50 2.992 2.867 SLB_Equip X -Nipple 1 Bottom Pup 19.3# EUE8rd BOX x H563 9.2# PIN) 9.66 750.50 1993-71 93.71 13684.05 4.48 2.992 2.808 SLB_Equip X -Nipple 1 Bottom X -Over (511 BOX X EUErd PIN) 1.24 751.74 13684.05 13682.81 3.75 2.992 2.808 2 SLB_Equip X -Nipple 1 1.3 753.04 13682.81 13681.51 3.95 2.813 2.808 SLB_Equip X -Nipple 1 Upper X -Over (EUEBRD BOX X WEDGE 511 PIN) 1.21 754.25 13681.51 13680.30 4.49 2.992 2.808 SLB_Equip X -Nipple 2 Upper Pup (9.2# HS63 BOX x 9.3# EUE8rd PIN) 9.85 764.10 13680.30 13670.45 4.26 2.992 2.808 22 Tubing_9.3ppf 22 30.98 795.08 13670.45 13639.47 3.50 2.992 2.867 96 23 Tubing_9.3ppf 23 31.03 826.11 13639.47 13608.44 3.50 2.992 2.867 24 Tubing_9.3ppf 24 31.14 857.25 13608.44 13577.30 3.50 2.992 2.867 25 Tubing_9.3ppf 25 31 888.25 13577.30 13546.30 3.50 2.992 2.867 1.B _Equip GE ottom Pup (9.3# EUE8rd BOX x H563 9.2# PI. - 9.58 897.83 13546.30 13536.72 4.48 2.992 2.867 3 95 SLB_Equip GLM -1, 3-1/2 MMG, Dummy w RK Latch 8.85 906.68 13536.72 13527.87 5.85 2.915 2.867 6823' TVD - SLB_Equip GLM -1 Upper Pup (9.2# H563 BOX x 9.3# EUE8rd PIN)s 9.63 916.31 13527.87 13518.24 4.76 2.992 2.867 26 Tubing_9.3ppf 26 31.07 947.38 13518.24 13487.171 3.50 2.992 2.867 27 Tubing_9.3ppf 27 31.09 978.47 13487.17 13456.08 3.50 2.992 2.567 94 28 Tubing_9.3ppf 28 30.86 1009.33 13456.08 13425.22 3.50 2.992 2.867 29 Tubing_9.3ppf 29 31.01 1040.34 13425.22 13394.21 3.50 2.992 2.867 30 Tubing_9.3ppf 30 31.00 1 1071.34 13394.21 13363.21 3.50 2.992 2.867 93 31 Tubing_9.3ppf 31 31.05 1102.39 13363.21 13332.16 3.50 2.992 2.867 32 Tubing_9.3ppf 32 31.08 - 1133.47 13332.16 13301.08 3.50 2.992 2.867 33 Tubing_9.3ppf 33 30.98 1164.45 13301.08 13270.10 3.50 2.992 2.867 92 34 Tubing_9.3ppf 34 31.05 1195.50 13270.10 13239.05 3.50 2.992 2.867 35 Tubing_9.3ppf 35 30.91 1226.41 13239.05 13208.14 3.50 2.992 2.867 36 Tubing_9.3ppf 36 30.99 1257.40 13208.14 13177.15 3.50 2.992 2.867 91 37 Tubing_9.3ppf 1 37 31.09 1288.49 13177.15 13146.06 3.50 2.992 2.867 38 Tubing_9.3ppf 38 31.02 1319.51 13146.06 13115.04 3.50 2.992 2.867 39 Tubing_9.3ppf 39 30.98 1350.49 13115.04 13084.06 3.50 2.992 2.867 90 40 Tubing_9.3ppf 40 31.09 1381.58 13084.06 13052.97 3.50 2.992 2.867 41 Tubing_9.3ppf 41 31.06 1412.64 13052.97 13021.91 3.50 2.992 2.867 42 Tubing_9.3ppf 42 30.92 1443.56 13021.91 12990.99 3.50 2.992 2.867 89 43 Tubing_9.3ppf 43 31.09 1474.65 12990.99 12959.90 3.50 2.992 2.867 44 Tubing_9.3ppf 44 31.03 1505.68 12959.90 12928.871 3.50 2.992 2.867 45 Tubing_9.3ppf 45 31.15 1536.83 12928.87 12897.72 3.50 2.992 2.867 SLB_Equip HPCI Bottom Pup (9.3# EUE8rd BOX x H563 9.2# PIN) 9.62 1546.45 12897.72 12888.10 5.02 2.992 2.867 SLB_Equip HPCI Bottom X -Over (TC -II BOX X EUE8rd PIN) 2.16 1548.61 12888.10 12885.94 5.02 2.992 2.867 4 88 SLB_Equip HPCI Chemical Injection Assembly 2.6 1551.21 12885.94 12883.34 5.02 2.942 2.867 SLB_Equip HPCI Top X -Over (EUE8rd BOX x TC -II PIN) 2.04 1553.25 12883.34 12881.30 5.02 2.992 2.867 SLB E ui PCI T P 9.2# H56 5,0)(x 9.3# EUE8rd PIN) 9.86 1563.11 12881.30 12871.44 5.02 2.992 2.867 46 Tubing_9.3ppf 46 31 1594.11 1 12871.44 12840.44 3.50 2.992 2.867 47 Tubing_9.3ppf 47 30.95 1625.06 12840.44 12809.49 3.50 2.992 2.867 87 48 Tubing_9.3ppf 48 31.04 1656.10 12809.49 12778.451 3.50 2.992 2.867 49 Tubing_9.3ppf 49 31.09 1687.19 12778.45 12747.36 3.50 2.992 2.867 50 Tubing_9.3ppf 479 31.06 1718.25 12747.36 12716.30 3.50 2.992 2.867 86 51 Tubing_9.3ppf 51 31.09 1749.34 12716.30 12685.21 3.50 2.992 2.867 52 Tubing_9.3ppf 52 31.11 1780.45 12685.21 12654.10 3.50 2.992 2.867 53 Tubing_9.3ppf 53 31.03 1811.48 12654.10 12623.07 3.50 2.992 2.867 85 54 Tubing_9.3ppf 54 31.04 1842.52 12623.07 12592.03 3.50 2.992 2.867 55 Tubing_9.3ppf 55 30.92 1873.44 12592.03 12561.11 3.50 2.992 2.867 56 Tubing_9.3ppf 56 31.16 1904.60 12561.11 12529.95 3.50 2.992 2.867 84 57 Tubing_9.3ppf 57 30.96 1935.56 12529.95 12498.99 3.50 2.992 2.867 58 Tubing_9.3ppf 58 31.08 1966.64 12498.99 12467.91 3.50 2.992 2.867 59 Tubing_9.3ppf 59 31.06 1997.70 12467.91 12436.85 3.50 2.992 2.867 83 60 Tubing_9.3ppf 60 31.1 2028.80 12436.85 12405.75 3.50 2.992 2.867 61 Tubing_9.3ppf 480 30.98 2059.78 12405.75 12374.77 3.50 2.992 2.867 62 Tubing_9.3ppf 62 31.11 2090.89 12374.77 12343.66 3.50 2.992 2.867 82 63 Tubing_9.3ppf 63 30.95 2121.84 12343.66 12312.71 3.50 2.992 2.867 64 Tubing_9.3ppf 64 31.02 2152.86 12312.71 12281.69 3.50 2.992 2.867 65 Tubing_9.3ppf 65 31.1 2183.96 12281.69 12250.59 3.50 2.992 2.867 81 66 Tubing_9.3ppf 481 3.. 04 2215.00 12250.59 12219.55 3.50 2.992 2.867 67 Tubing_9.3ppf 482 31.1 2246.10 12219.55 12188.45 3.50 2.992 2.867 68 Tubing_9.3ppf 68 31.03 -:, 2277.13 12188.45 12157.42 3.50 2.992 2.867 80 69 Tubing_9.3ppf 69 31.03 ? 2308.16 12157.42 12126.39 3.50 2.992 2.867 70 Tubing_9.3ppf 70 31.1 W 2339.26 12126.39 12095.29 3.50 2.992 2.867 71 Tubing_9.3ppf 71 31.01 2370.27 12095.29 12064.28 3.50 2.992 2.867 79 72 Tubing_9.3ppf 72 31.09 2401.36 12064.28 12033.19 3.50 2.992 2.867 73 Tubing_9.3ppf 73 31.16 2432.52 12033.19 12002.03 3.50 2.992 2.867 74 Tubing_9.3ppf 74 31.16 2463.68 12002.03 11970.87 3.50 2.992 2.867 78 75 Tubing_9.3ppf 75 31.09 2494.77 11970.87 11939.78 3.50 2.992 2.867 76 Tubing_9.3ppf 76 31.06 : 2525.83 11939.78 11908.72 3.50 2.992 2.867 77 Tubing_9.3ppf 77 31.08 2556.91 11908.72 11877.64 3.50 2.992 2.867 77 78 Tubing_9.3ppf 78 31.04 2587.95 11877.64 11846.60 3.50 2.992 2.867 79 Tubing_9.3ppf 79 31 2618.95 11846.60 11815.60 3.50 2.992 2.867 80 Tubing_9.3ppf 80 31.13 2650.08 11815.60 11784.47 3.50 2.992 2.867 76 81 Tubing_9.3ppf 81 31.13 2681.21 11784.47 11753.34 3.50 2.992 2.867 82 Tubing_9.3ppf 82 31.07 2712.28 11753.34 11722.27 3.50 2.992 2.867 83 Tubing_9.3ppf 83 30.95 2743.23 11722.27 11691.32 3.50 2.992 2.867 75 84 Tubing_9.3ppf 84 31.04 2774.27 11691.32 11660.28 3.50 2.992 2.867 85 Tubing_9.3ppf 85 30.89 2805.16 1 11660.28 11629.39 3.50 2.992 2.867 86 Tubing_9.3ppf 86 31.08 2836.24 11629.39 11598.31 3.50 2.992 2.867 74 87 Tubing_9.3ppf 87 30.96 2867.20 11598.31 11567.35 3.50 2.992 2.867 88 Tubing_9.3ppf 88 31.12 2898.32 11567.35 11536.23 3.50 2.992 2.867 89 Tubing_9.3ppf 89 31.1 2929.42 11536.23 11505.13 3.50 2.992 2.867 73 90 Tubing_9.3ppf 90 31.11 2960.53 11505.13 11474.02 3.50 2.992 2.867 91 Tubing_9.3ppf 91 31.12 2991.65 11474.02 11442.90 3.50 2.992 2.867 92 Tubing_9.3ppf 92 31.1 3022.75 11442.90 11411.80 3.50 2.992 2.867 72 93 Tubing_9.3ppf 93 31.11 3053.86 11411.80 11380.69 3.50 2.992 2.867 94 Tubing_9.3ppf 94 31.13 3084.99 11380.69 11349.56 3.50 2.992 2.867 95 Tubing_9.3ppf 95 31.14 3116.13 11349.56 11318.42 3.50 2.992 2.867 71 96 Tubing_9.3ppf 96 31.04 3147.17 11318.42 11287.38 3.50 2.992 2.867 97- Tubing_9.3ppf 97 30.97 3178.14 11287.38 11256.41 3.50 2.992 2.867 98 Tubing_9.3ppf 98 31.07 3209.21 11256.41 11225.34 3.50 2.992 2.867 70 99 Tubing_9.3ppf 99 31.06 3240.27 11225.34 11194.28 3.50 2.992 2.867 100 Tubing_9.3ppf 100 31.05 3271.32 11194.28 11163.23 3.50 2.992 2.867 101 Tubing_9.3ppf 101 30.97 3302.29 11163.23 11132.26 3.50 2.992 2.867 69 102 Tubing_9.3ppf 102 31.02 1 3333.31 111132.26 11101.24 3.50 2.992 2.867 103 Tubing_9.3ppf 103 31.14 3364.45 11101.24 11070.10 3.50 2.992 2.867 104 Tubing_9.3ppf 104 31.03 3395.48 11070.10 11039.07 3.50 2.992 2.867 68 105 Tubing_9.3ppf 105 31.13 3426.61 11039.07 11007.94 3.50 2.992 2.867 106 Tubing_9.3ppf 106 31.08 3457.69 11007.94 10976.86 3.50 2.992 2.867 107 Tubing_9.3ppf 107 31.11 3488.80 10976.86 10945.75 3.50 2.992 2.867 67 108 Tubing_9.3ppf 108 31.1 3519.90 10945.75 10914.65 3.50 2.992 2.867 109 Tubing_9.3ppf 109 31.01 3550.91 10914.65 10883.64 3.50 2.992 2.867 110 Tubing_9.3ppf 110 31 3581.91 10883.64 10852.64 3.50 2.992 2.867 66 111 Tubing_9.3ppf 111 31.11 3613.02 10852.64 10821.53 3.50 2.992 2.867 112 Tubing_9.3ppf 112 31.09 3644.11 10821.53 10790.44 3.50 2.992 2.867 113 Tubing_9.3ppf 113 31.03 3675.14 10790.44 10759.41 3.50 2.992 2.867 65 114 Tubing_9.3ppf 114 31.11 3706.25 10759.41 10728.30 3.50 2.992 2.867 115 Tubing_9.3ppf 115 31.1 3737.35 10728.30 10697.20 3.50 2.992 2.867 116 Tubing_9.3ppf 116 31.15 3768.50 10697.20 10666.05 3.50 2.992 2.867 64 117 Tubing_9.3ppf 117 31.12 3799.62 10666.05 10634.93 3.50 2.992 2.867 118 Tubing_9.3ppf 118 31.02 3830.64 10634.93 10603.91 3.50 2.992 2.867 119 Tubing_9.3ppf 119 30.98 3861.62 10603.91 10572.93 3.50 2.992 2.867 63 120 Tubing_9.3ppf 120 31.04 3892.66 10572.93 10541.89 3.50 2.992 2.867 121 Tubing_9.3ppf 121 31.09 3923.75 10541.89 10510.80 3.50 2.992 2.867 122 Tubing_9.3ppf 122 30.96 3954.71 10510.80 10479.84 3.50 2.992 2.867 62 123 Tubing_9.3ppf 123 30.99 3985.70 10479.84 10448.85 3.50 2.992 2.867 124 Tubing_9.3ppf 124 31.1 1 4016.80 10448.85 10417.751 3.50 2.992 2.867 125 Tubing_9.3ppf 125 30.98 4047.78 10417.75 10386.77 3.50 2.992 2.867 61 126 Tubing_9.3ppf 126 31.04 `' 4078.82 10386.77 10355.73 3.50 2.992 2.867 127 Tubing_9.3ppf 127 31.06 4109.88 10355.73 10324.67 3.50 2.992 2.867 128 Tubing_9.3ppf 128 31.02 4140.90 10324.67 10293.65 3.50 2.992 2.867 60 129 Tubing_9.3ppf 129 30.93 4171.83 10293.65 10262.72 3.50 2.992 2.867 130 Tubing_9.3ppf 130 31.08 4202.91 10262.72 10231.64 3.50 2.992 2.867 131 Tubing_9.3ppf 131 31.1 4234.01 10231.64 10200.54 3.50 2.992 2.867 59 132 Tubing_9.3ppf 132 31.04 4265.05 10200.54 10169.50 3.50 2.992 2.867 133 Tubing_9.3ppf 133 31.05 4296.10 10169.50 10138.45 3.50 2.992 2.867 SLB Equip GLM -2 Bottom Pup (9.3# EUE8rd BOX x H563 9.2# PIN) 9.66 4305.76 10138.45 10128.79 4.48 2.992 2.867 5 SLB_Equip GLM -2, 3-1/2 MMG, Dummy w RK Latch 8.86 4314.62 10128.79 10119.93 5.85 2.915 2.867 5498' TVD 58 SLB -Equip GLM -2 Upper Pup (9.2# H563 BOX x 9.3# EUE8rd PIN) ` 9.83 4324.45 10119.93 10110.10 4.26 2.992 2.867 134 Tubing_9.3ppf 134 31.06 4355.51 10110.10 10079.04 3.50 2.992 2.867 135 Tubing_9.3ppf 135 31.07 4386.58 10079.04 10047.97 3.50 2.992 2.867 136 Tubing_9.3ppf 136 30.91 - 4417.49 10047.97 10017.06 3.50 2.992 2.867 57 137 Tubing_9.3ppf 137 31 4448.49 10017.06 9986.06 3.50 2.992 2.867 138 Tubing_9.3ppf 138 31.06 4479.55 9986.06 9955.00 3.50 2.992 2.867 139 Tubing_9.3ppf 139 30.99 4510.54 9955.00 9924.01 3.50 2.992 2.867 56 140 Tubing_9.3ppf 140 31 4541.54 9924.01 9893.01 3.50 2.992 2.867 141 Tubing_9.3ppf 141 31.14 4572.68 9893.01 9861.87 3.50 2.992 2.867 142 Tubing_9.3ppf 142 31.05 4603.73 9861.87 9830.82 3.50 2.992 2.867 55 143 Tubing_9.3ppf 143 31.1 § 4634.83 9830.82 9799.72 3.50 2.992 2.867 144 Tubing_9.3ppf 144 30.97 4665.80 9799.72 9768.75 3.50 2.992 2.867 145 Tubing_9.3ppf 145 30.88 4696.68 9768.75 9737.87 3.50 2.992 2.867 54 146 Tubing_9.3ppf 146 31.11 4727.79 9737.87 9706.76 3.50 2.992 2.867 147 Tubing_9.3ppf 147 31.14 4758.93 9706.76 9675.62 3.50 2.992 2.867 148 Tubing_9.3ppf 148 31.06 4789.99 9675.62 9644.56 3.50 2.992 2.867 53 149 Tubing_9.3ppf 149 31.1 4821.09 9644.56 9613.46 3.50 2.992 2.867 150 Tubing_9.3ppf 150 31.06 4852.15 9613.46 9582.40 3.50 2.992 2.867 151 Tubing_9.3ppf 151 31.08 4883.23 9582.40 9551.32 3.50 2.992 2.867 52 152 Tubing_9.3ppf 152 31.12 4914.35 9551.32 9520.20 3.50 2.992 2.867 153 Tubing_9.3ppf 153 31.05 4945.40 9520.20 9489.15 1 3.50 2.992 2.867 154 Tubing_9.3ppf 154 31 4976.40 9489.15 9458.15 1 3.50 2.992 2.867 51 155 Tubing_9.3ppf 155 31.11 '. 5007.51 9458.15 9427.04 3.50 2.992 2.867 156 Tubing_9.3ppf 157 30.98 ' 5038.49 9427.04 9396.06 3.50 2.992 156 LD 2.867 157 Tubing_9.3ppf 158 31.1 - 5069.59 9396.06 9364.96 3.50 2.992 2.867 50 158 Tub g_9.3ppf 159 31.04 5100.63 9364.96 9333.92 3.50 2.992 2.867 159 Tubing_9.3ppf 160 31.09 5131.72 9333.92 9302.83 3.50 2.992 2.867 160 Tubing_9.3ppf 161 31.1 9302.83 9271.73 3.50 2.992 2.867 49 161 Tubing_9.3ppf 162 30.98 5193.80 9271.73 9240.75 3.50 2.992 2.867 162 Tubing_9.3ppf 163 31.03 5224.83 9240.75 9209.72 3.50 2.992 2.867 163 Tubing_9.3ppf 164 31.02 5255.85 9209.72 9178.70 3.50 2.992 2.867 48 164 Tubing_9.3ppf 165 31.07 5286.92 9178.70 9147.63 3.50 2.992 2.867 165 Tubing_9.3ppf 166 31.08 5318.00 9147.63 9116.55 3.50 2.992 2.867 166 Tubing_9.3ppf 167 31.01 5349.01 9116.55 9085.54 3.50 2.992 2.867 47 167 Tubing_9.3ppf 168 31 5380.01 9085.54 1 9054.54 j 3.50 2.992 2.867 165 Tubing_9.3ppf 169 31.07 5411.08 9054.54 1 9023.47 3.50 2.992 2.867 169 Tubing_9.3ppf 170 30.96 5442.04 9023.47 8992.51 3.50 2.992 2.867 46 170 Tubing_9.3ppf 171 30.95 5472.99 8992.51 8961.56 3.50 2.992 2.867 171 Tubing_9.3ppf 172 31.12 5504.11 8961.56 8930.44 3.50 2.992 2.867 172 Tubing_9.3ppf 173 31.09 5535.20 8930.44 8899.35 3.50 2.992 2.867 45 173 Tubing_9.3ppf 174 31.1 5566.30 8899.35 8868.25 3.50 2.992 2.867 174 Tubing_9.3ppf 175 31.06 5597.36 8868.25 8837.19 3.50 2.992 2.867 175 Tubing_9.3ppf 176 30.9 5628.26 8837.19 8806.29 1 3.50 2.992 2.867 44 176 Tubing_9.3ppf 177 30.98 5659.24 8806.29 8775.31 3.50 2.992 2.867 177 Tubing_9.3ppf 178 31.11 5690.35 8775.31 8744.20 3.50 2.992 2.867 178 Tubing_9.3ppf 179 31.15 5721.50 8744.20 8713.05 3.50 2.992 2.867 43 179 Tubing_9.3ppf 180 30.96 5752.46 8713.05 8682.09 3.50 2.992 2.867 180 Tubing_9.3ppf 181 31.08 5783.54 8682.09 8651.01 3.50 2.992 2.867 181 Tubing_9.3ppf 182 31.06 5814.60 8651.01 8619.95 3.50 2.992 2.867 42 182 Tubing_9.3ppf 183 31.12 5845.72 8619.95 8588.83 3.50 2.992 2.867 183 Tubing_9.3ppf 184 31.09 5876.81 8588.83 8557.74 1 3.50 2.992 2.867 184 Tubing_9.3ppf 477 31.05 5907.86 8557.74 8526.69 3.50 2.9921 2.867 41 185 Tubing_9.3ppf 186 31.05 5938.91 8526.69 8495.64 3.50 2.992 2.867 186 Tubing9.3ppf 187 31.1 5970.01 8495.64 8464.54 3.50 2.992 2.867 187 Tubing_9.3ppf 188 31.07 6001.08 8464.54 8433.47 3.50 2.992 2.867 40 188 Tubing_9.3ppf 189 31.1 6032.18 8433.47 8402.37 3.50 2.992 2.867 189 Tubing_9.3ppf 190 31.07 6063.25 8402.37 8371.30 3.50 2.992 2.867 190 Tubing_9.3ppf 191 31.05 6094.30 8371.30 8340.25 3.50 2.992 2.867 39 191 Tubing_9.3ppf 192 31.02 6125.32 8340.25 8309.23 3.50 2.992 2.867 192 Tubing_9.3ppf 193 31.1 6156.42 8309.23 8278.13 3.50 2.992 2.867 193 Tubing_9.3ppf 194 187.54 8278.13 8247.01 3.50 2.992 2.867 38 194 Tubing_9.3ppf 195 18.56 8247.01 8215.99 3.50 2.992 2.867 195 Tubing_9.3ppf 196 49.62 8215.99 8184.93 3.50 2.992 2.867 196 Tubing_9.3ppf 197 280.70 T31.17, 8184.93 8153.85 3.50 2.992 2.867 37 197 Tubing_9.3ppf 198 311.70 8153.85 8122.85 3.50 2.992 2.867 198 Tubing_9.3ppf 199 342.87 8122.85 8091.68 3.50 2.992 2.867 199 Tubing_9.3ppf 200 373.92 8091.68 8060.63 3.50 2.992 2.867 36 200 Tubing_9.3ppf201 405.01 8060.63 8029.54 3.50 2.992 2.867 201 Tubing_9.3ppf 202 6436.13 8029.54 7998.42 3.50 2.992 2.867 202 Tubing_9.3ppf 203 6467.13 7998.42 7967.42 3.50 2.992 2.867 35 203 Tubing_9.3ppf 204 A30.98 6498.11 7967.42 7936.44 3.50 2.992 2.867 Tubing_9.3ppf 205 6529.19 7936.44 7905.36 3.50 2.992 2.867 205 Tubing_9.3ppf 206 6560.29 7905.36 7874.26 3.50 2.9921 2.867 34 206Tubing_9.3ppf 207 31.12 7874.26 7843.14 3.50 2.992 2.867 207 Tubing_9.3ppf 208 31.03 6622.44 7843.14 7812.11 3.50 2.992 2.867 208 Tubing_9.3ppf 209 31.05 6653.49 7812.11 7781.06 3.50 2.992 2.867 33 209 Tubing_9.3ppf 210 31.13 6684.62 7781.06 7749.93 3.50 2.992 2.867 210 Ti g_9.3ppf 211 31.1 6715.72 7749.93 7718.83 3.50 2.992 2.867 211 Tubing_9.3ppf 212 31.07 6746 7718.83 7687.76 3.50 2.992 2.867 32 212 Tubing_9.3ppf 213 30.9 6777:0,R 687.76 7656.86 3.50 2.992 2.867 213 Tubing_9.3ppf 214 31.11 6808.80 7656.86 7625.75 3.50 2.992 2.867 214 Tubing_9.3ppf 215 31.06 6839.86 7625.75 7594.69 3.50 2.992 2.867 31 215 Tubing_9.3ppf 216 31.07 6870.93 7594.69 7563.62 3.50 2.992 2.867 216 Tubing_9.3ppf 217 30.94 6901.87 7563.62 7532.68 3.50 2.992 2.867 217 Tubing_9.3ppf 218 30.98 6932.85 7532.68 7501.70 3.50 2.992 2.867 30 218 Tubing_9.3ppf 219 31.11 6963.96 7501.70 7470.59 3.50 2.992 2.867 219 Tubing_9.3ppf 220 31.12 6995.08 7470.59 7439.47 3.50 2.992 2.867 220 Tubing_9.3ppf 221 30.98 7026.06 7439.47 7408.49 3.50 2.992 2.867 29 221 Tubing_9.3ppf 222 30.92 7056.98 7408.49 7377.57 3.50 2.992 2.867 222 ITubingj.3ppf 223 31.03 7088.01 7377.57 7346.54 3.50 2.992 2.867 223 Tubing_9.3ppf 224 31.06 7119.07 7346.54 7315.48 3.50 2.992 2.867 28 224 Ti g_9.3ppf 225 31.05 7150.12 7315.48 7284.43 3.50 2.992 2.867 225 Tubing_9.3ppf 226 31.02 7181.14 7284.43 7253.41 3.50 2.992 2.867 226 Tubing_9.3ppf 227 31.14 7212.28 7253.41 7222.27 3.50 2.992 2.867 27 227 Tubing_9.3ppf 228 31.08 7243.36 7222.27 7191.19 3.50 2.992 2.867 228 Tubing_9.3ppf 229 31.05 7274.41 7191.19 7160.14 3.50 2.992 2.867 229 Tubing_9.3ppf 230 31.15 7305.56 7160.14 7128.99 3.50 2.992 2.867 26 230 Tubing_9.3ppf 231 30.99 7336.55 7128.99 7098.00 3.50 2.992 2.867 231 Tubing_9.3ppf 232 30.98 7367.53 7098.00 7067.02 3.50 2.992 2.867 232 Tubing_9.3ppf 233 31.1 7398.63 7067.02 7035.92 3.50 2.992 2.867 25 233 Tubing_9.3ppf 234 31.08 7429.71 7035.92 7004.84 3.50 2.992 2.867 234 Tubing_9.3ppf 235 31 7460.71 7004.84 6973.84 3.50 2.992 2.867 235 Tubing_9.3ppf 236 30.89 7491.60 6973.84 6942.95 3.50 2.992 2.867 24 236 Tubing_9.3ppf 237 31.05 7522.65 6942.95 6911.90 3.50 2.992 2.867 237 Tubing_9.3ppf 238 30.99 7553.64 6911.90 6880.91 3.50 2.992 2.867 238 Tubing_9.3ppf 239 31 7584.64 6880.91 6849.91 3.50 2.992 2.867 23 239 Tubing_9.3ppf 240 31.07 7615.71 6849.91 6818.84 3.50 2.992 2.867 240 Tubing_9.3ppf 241 31.02 7646.73 6818.84 6787.82 3.50 2.992 2.867 241 Tubing_9.3ppf 242 31.13 7677.86 6787.82 6756.69 3.50 2.992 2.867 22 242 Tubing_9.3ppf 243 31.1 7708.96 6756.69 6725.59 3.50 2.992 2.867 243 Tubing_9.3ppf 244 31.13 7740.09 6725.59 6694.46 3.50 2.992 2.867 244 Tubing_9.3ppf 245 31.11 7771.20 6694.46 6663.35 3.50 2.992 2.867 21 245 Tubing_9.3ppf 246 31.12 7802.32 6663.35 6632.23 3.50 2.992 2.867 246 ITubingj.3ppf 247 30.87 7833.19 6632.23 6601.36 3.50 2.992 2.867 247 Tubing_9.3ppf 248 31.05 7864.24 6601.36 6570.31 3.50 2.992 2.867 20 248 Tubing_9.3ppf 249 31.1 7895.34 6570.31 6539.21 3.50 2.992 2.867 249 Tubing _9.3ppfppf 250 31.08 7926.42 6539.21 6508.13 3.50 2.992 2.867 250 Tubing_9.3 251 31.05 7957.47 6508.13 6477.08 3.50 2.992 2.867 19 251 Tubing_9.3ppf 252 31.08 7988.55 6477.08 6446.00 3.50 2.992 2.867 252 Tubin99.3ppf 253 31.11 8019.66 6446.00 6414.89 3.50 2.992 2.867 253 Tubing_9.3ppf 254 31.04 8050.70 6414.89 6383.85 3.50 2.992 2.867 18 254 Tubing_9.3ppf 255 31.13 8081.83 6383.85 6352.72 3.50 2.992 2.867 255 Tubing_9.3ppf 256 30.98 8112.81 6352.72 6321.74 3.50 2.992 2.867 256 Tubing_9.3ppf 257 31.14 8143.95 6321.74 6290.60 3.50 2.992 2.867 17 257 Tubing_9.3ppf 258 31.05 8175.00 6290.60 6259.55 3.50 2.992 2.867 258 Tubing_9.3ppf 259 31.07 8206.07 6259.55 6228.48 3.50 2.992 2.867 259 Tubing_9.3ppf 260 31.06 8237.13 6228.48 6197.42 3.50 2.992 2.867 16 260 Tubing_9.3ppf 261 31.11 8268.24 6197.42 6166.31 3.50 2.992 2.867 261 Tubing_9.3ppf 262 31.12 8299.36 6166.31 6135.19 3.50 2.992 2.867 262 Tubing_9.3ppf 263 30.97 8330.33 6135.19 6104.22 3.50 2.992 2.867 15 263 Tubing_9.3ppf 264 31.14 8361.47 6104.22 6073.08 3.50 2.992 2.867 264 Tubing_9.3ppf 265 30.93 8392.40 6073.08 6042.15 3.50 2.992 2.867 265 Tubing_9.3ppf 266 31.1 8423.50 6042.15 6011.05 3.50 2.992 2.867 14 266 Tubing_9.3ppf 267 31.08 8454.58 6011.05 5979.97 3.50 2.992 2.867 267 Tubing_9.3ppf 268 31 8485.58 5979.97 5948.97 3.50 2.992 2.867 268 Tubing_9.3ppf 269 31.03 8516.61 5948.97 5917.94 3.50 2.992 2.867 13 269 Tubing_9.3ppf 270 31.1 8547.71 5917.94 5886.84 3.50 2.992 2.867 270 Tubing_9.3ppf 271 31.11 8578.82 5886.84 5855.73 3.50 2.992 2.867 271 Tubing_9.3ppf 272 31.12 8609.94 5855.73 5824.61 3.50 2.992 2.867 12 272 Tubing_9.3ppf 273 31.12 = 8641.06 5824.61 5793.49 3.50 2.992 2.867 273 Tubing_9.3ppf 274 31.02 - 8672.08 5793.49 5762.47 3.50 2.992 2.867 274 Tubing_9.3ppf 275 30.92 8703.00 5762.47 5731.55 3.50 2.992 2.867 11 275 Tubing_9.3ppf 276 31.02 _ 8734.02 5731.55 5700.53 3.50 2.992 2.867 276 Tubing_9.3ppf 277 30.97 8764.99 5700.53 5669.56 3.50 2.9921 2.867 277 Tubing_9.3ppf 278 31.1 8796.09 5669.56 5638.46 3.50 2.992 2.867 10 278 Tubing_9.3ppf 279 31.1 8827.19 5638.46 5607.36 3.50 2.992 2.867 279 Tubing_9.3ppf 280 31.08 8858.27 5607.36 5576.28 3.50 2.992 2.867 280 Tubing_9.3ppf 1 281 31.07 8889.34 5576.28 5545.21 3.50 2.992 2.867 9 281 Tubing_9.3ppf 282 30.98 8920.32 5545.21 5514.23 3.50 2.992 2.867 282 Tubing_9.3ppf 283 31.01 8951.33 5514.23 5483.22 1 3.50 2.992 2.867 283 Tubing_9.3ppf 284 31.06 8982.39 5483.22 5452.16 3.50 2.992 2.867 8 284 Tubing_9.3ppf 285 30.98 9013.37 5452.16 5421.18 3.50 2.9921 2.867 285 Tubing_9.3ppf 286 31.08 9044.45 5421.18 5390.10 3.50 2.992 2.867 286 Tubing_9.3ppf 287 31.1 9075.55 5390.10 5359.00 3.50 2.992 2.867 7 287 Tubing_9.3ppf 288 30.1 9105.65 5359.00 5328.90 3.50 2.992 2.867 288 Tubing_9.3ppf 289 31.07 9136.72 5328.90 5297.83 3.50 2.992 2.867 289 Tubing_9.3ppf 290 31.15 9167.87 5297.83 5266.68 3.50 2.992 2.867 6 290 Tubing_9.3ppf 291 31.12 9198.99 5266.68 5235.56 1 3.50 2.992 2.867 291 Tubing_9.3ppf 292 31.11 9230.10 5235.56 5204.45 3.50 2.992 2.867 292 Tubing_9.3ppf 293 31.14 9261.24 5204.45 5173.31 3.50 2.992 2.867 5 293 Tubing_9.3ppf 294 31.02 9292.26 5173.31 5142.29 3.50 2.9921 2.867 294 Tubing_9.3ppf 295 31.13 9323.39 5142.29 5111.16 3.50 2.992 2.867 295 Tubing_9.3ppf 296 31.1 9354.49 5111.16 5080.06 3.50 2.992 2.867 4 296 Tubing_9.3ppf 297 31.15 9385.64 5080.06 5048.91 3.50 2.992 2.867 297 ITubingj.3ppf 1 298 31.06 9416.70 5048.91 5017.85 3.50 2.9921 2.867 298 ppf 299 31.09 5017.85 4986.76 3.50 2.992 2.867 3 299 ppf 300 31.06 9478.85 4986.76 4955.70 3.50 2.992 2.867 300 ppf 301 31.13 9509.98 4955.70 4924.57 3.50 2.992 2.867 2 301 ppf OEquip 302 30.98 9540.96 4924.57 4893.59 3.50 2.992 2.867 6 - X-Nf ' Bottom Pup, .:EUE8rd BOX x H563 9.2# PIN) X -Nipple 2 9.24 0.98 9550.20 9551.18 4893.59 4884.35 4884.35 4883.37 4.4 4.50 - 82 2.813 2.808 2.808 X -Nipple 2 Upper Pup (9.2# H563 BOX x 9.3# EUE8rd PIN) 9.85 9561.03 4883.37 4873.52 4.26 2.992 2.808 2 302 Tubing_9.3ppf 303 30.94 9591.97 4873.52 4842.58 3.50 2.992 2.867 303 Tubing_9.3ppf 304 31.02 9622.99 4842.58 4811.56 3.50 2.992 2.867 304 Tubing_9.3ppf 305 31.12 9654.11 4811.56 4780.44 3.50 2.992 2.867 1 305 Tubing_9.3ppf 306 31.14 9685.25 4780.44 4749.30 3.50 2.992 2.867 306 Tubing_9.3ppf 307 31.1 9716.35 4749.30 4718.20 3.50 2.992 2.867 307 Tubing_9.3ppf 308 31.1 9747.45 4718.20 4687.10 3.50 2.992 2.867 308 Tubing_9.3ppf 478 31.15 9778.60 4687.10 4655.95 3.50 2.992 2.867 309 Tubing_9.3ppf 310 31.09 9809.69 4655.95 4624.86 1 3.50 2.992 2.867 310 Tubing_9.3ppf 311 31.14 9840.83 4624.86 4593.72 3.50 2.992 2.867 311 Tubing_9.3ppf 312 31.1 9871.93 4593.72 4562.62 3.50 2.992 2.867 312 Tubing_9.3ppf 313 31.02 9902.95 4562.62 4531.60 3.50 2.992 2.867 LB_Equip GLM -3 Bottom Pup (9.3# EUE8rd BOX x H563 9.2# PIN)' 9.65 9912.60 4531.60 4521.95 4.48 2.992 2.867 7 LB_Equip GLM -3, 3-1/2 MMG 1.5" SOV 2500 psi w RKP Latch 8.86 9921.46 4521.95 4513.09 5.85 2.915 2.867 3311 SLB_Equip GLM -3 Upper Pup .9,2#H Ba , 9.3# 11E8rd PIN) 9.78 9931.24 4513.09 4503.31 4.25 2.992 2.867 313 Tubing_9.3ppf 314 31.15 9962.39 4503.31 4472.16 3.50 2.992 2.867 314 Tubing_9.3ppf 315 31.03 9993.42 4472.16 4441.13 3.50 2.992 2.867 315 Tubing_9.3ppf 316 31.1 10024.52 4441.13 4410.03 3.50 2.992 2.867 316 Tubing_9.3ppf 317 31.11 10055.63 4410.03 4378.92 3.50 2.992 2.867 317 Tubing_9.3ppf 318 31.06 10086.69 4378.92 4347.86 3.50 2.992 2.867 318 Tubing_9.3ppf 319 31.13 10117.82 4347.86 4316.73 3.50 2.992 2.867 319 Tubing_9.3ppf 320 31.09 10148.91 4316.73 4285.64 3.50 2.992 2.867 320 Tubing_9.3ppf 321 31.02 10179.93 4285.64 4254.62 3.50 2.992 2.867 321 Tubing_9.3ppf 322 31.11 10211.04 4254.62 4223.51 3.50 2.992 2.867 322 Tubing_9.3ppf 323 31.13 10242.17 4223.51 4192.38 3.50 2.992 2.867 323 Tubing_9.3ppf 324 31.07 10273.24 4192.38 4161.31 3.50 2.992 2.867 324 Tubing_9.3ppf 325 31.1 • 10304.34 4161.31 4130.21 3.50 2.992 2.867 325 Tubing_9.3ppf 326 30.08 .10334.42 4130.21 4100.13 3.50 2.992 2.867 326 Tubing_9.3ppf 327 31.11 10365.53 4100.13 4069.02 3.50 2.992 2.867 327 Tubing_9.3ppf 328 31.1 10396.63 4069.02 4037.92 3.50 2.992 2.867 328 Tubing_9.3ppf 329 31.13 10427.76 4037.92 4006.79 3.50 2.992 2.867 329 Tubing_9.3ppf 330 30.99 10458.75 4006.79 3975.80 3.50 2.992 2.867 330 Tubing_9.3ppf 331 31.09 10489.84 3975.80 3944.71 3.50 2.992 2.867 331 Tubing_9.3ppf 332 31 10520.84 3944.71 3913.71 3.50 2.992 2.867 332 Tubing_9.3ppf 333 31.12 10551.96 3913.71 3882.59 3.50 2.992 2.867 333 Tubing_9.3ppf 334 30.95 10582.91 3882.59 3851.64 3.50 2.992 2.867 334 Tubing_9.3ppf 335 31.1 10614.01 3820.54 3.50 2.992 2.867 335 Tubing_9.3ppf 336 31.07 10645.08 3789.47 3.50 2.992 2.867 336 Tubing_9.3ppf 337 31.07 10676.15 im 3758.40 3.50 2.992 2.867 337 Tubing_9.3ppf 338 31,- 10707.15 3727.40 3.50 2.992 1997 338 Tubing_9.3ppf 339 31.13 1 10739.M 3727.40 3696.27 3.50 2.992 2.867 339 Tubing_9.3ppf 340 31.13 10769.41 3696.27 3665.14 3.50 2.992 2.867 340 Tubing_9.3ppf 341 31.11 p 10800.52 3665.14 3634.03 3.50 2.992 2.867 341 Tubing_9.3ppf 342 30.97 10831.49 3634.03 3603.06 3.50 2.992 2.867 342 Tubing_9.3ppf 343 31.12 10862.61 3603.06 3571.94 3.50 2.992 2.867 343 Tubing_9.3ppf 344 30.99 10893.60 3571.94 3540.95 3.50 2.992 2.867 344 Tubing_9.3ppf 345 31.09 10924.69 3540.95 3509.86 3.50 2.992 2.867 345 Tubing_9.3ppf 346 31.06 10955.75 3509.86 3478.80 3.50 2.992 2.867 346 Tubing_9.3ppf 347 31.08 10986.83 3478.80 3447.72 3.50 2.9921 2.867 347 Tubing_9.3ppf 348 31.04 1 11017.87 3447.72 3416.68 3.50 2.992 2.867 348 Tubing_9.3ppf 349 31.07 11048.94 3416.68 3385.61 3.50 2.992 2.867 349 Tubing_9.3ppf 350 30.92 11079.86 3385.61 3354.69 3.50 2.992 2.867 350 Tubing_9.3ppf 351 30.98 11110.84 3354.69 3323.71 3.50 2.992 2.867 351 Tubing_9.3ppf 352 31 11141.84 3323.71 3292.71 3.50 2.992 2.867 352 Tubing_9.3ppf 353 31.11 11172.95 3292.71 3261.60 3.50 2.992 2.867 353 Tubing_9.3ppf 354 30.01 11202.96 3261.60 3231.59 3.50 2.992 2.867 354 Tubing_9.3ppf 355 31.03 11233.99 3231.59 3200.56 3.50 2.992 2.867 355 Tubing_9.3ppf 356 31.09 11265.08 3200.56 3169.47 3.50 2.992 2.867 356 Tubing_9.3ppf 357 31.1 11296.18 3169.47 3138.37 3.50 2.992 2.867 357 Tubing_9.3ppf 358 31.1 11327.28 3138.37 3107.27 3.50 2.992 2.867 358 Tubing_9.3ppf 359 31.11 11358.39 3107.27 3076.16 3.50 2.992 2.867 359 Tubing_9.3ppf 360 31.11 11389.50 3076.16 3045.05 3.50 2.992 2.867 360 Tubing_9.3ppf 361 31.01 11420.51 3045.05 3014.04 3.50 2.992 2.867 361 Tubing_9.3ppf 362 31.09 11451.60 3014.04 2982.95 3.50 2.992 2.867 362 Tubing_9.3ppf 363 31.07 11482.67 2982.95 2951.88 3.50 2.992 2.867 363 Tubing_9.3ppf 364 31.15 11513.82 2951.88 2920.73 3.50 2.992 2.867 364 Tubing_9.3ppf 365 31.09 11544.91 2920.73 2889.64 3.50 2.992 2.867 365 Tubing_9.3ppf 366 31.11 11576.02 2889.64 2858.53 3.50 2.992 2.867 366 Tubing_9.3ppf 367 31.13 11607.15 2858.53 2827.40 3.50 2.992 2.867 367 Tubing_9.3ppf 368 29.97 11637.12 2827.40 2797.43 3.50 2.992 2.867 368 Tubing_9.3ppf 369 31.09 11668.21 2797.43 2766.34 3.50 2.992 2.867 369 Tubing_9.3ppf 370 31.03 11699.24 2766.34 2735.31 3.50 2.992 2.867 370 Tubing_9.3ppf 371 31.05 11730.29 2735.31 2704.26 3.50 2.992 2.867 371 Tubing_9.3ppf 372 31.06 11761.35 2704.26 2673.20 3.50 2.992 2.867 372 Tubing_9.3ppf 373 31.11 11792.46 2673.20 2642.09 3.50 2.992 2.867 373 Tubing_9.3ppf 374 31.05 11823.51 2642.09 2611.04 3.50 2.992 2.867 374 Tubing_9.3ppf 375 31.12 11854.63 2611.04 2579.92 3.50 2.992 2.867 375 Tubing_9.3ppf 376 31.14 11885.77 2579.92 2548.78 3.50 2.992 2.867 376 Tubing_9.3ppf 377 30.98 11916.75 2548.78 2517.80 3.50 2.992 2.867 377 Tubing_9.3ppf 378 31.02 11947.77 2517.80 2486.78 1 3.50 2.992 2.867 378 Tubing_9.3ppf 379 31.13 11978.90 2486.782455.65 3.50 2.992 2.867 379 Tubing_9.3ppf 380 30.99 12009.89 2455.65 2424.66 3.50 2.992 2.867 380 Tubing_9.3ppf 381 31.08 12040.97 2424.66 2393.58 3.50 2.992 2.867 381 Tubing_9.3ppf 382 31.1 12072.07 2393.58 2362.48 3.50 2.992 2.867 382 Tubing_9.3ppf 383 31.01 12103.08 2362.48 2331.47 3.50 2.992 2.867 383 Tubing_9.3ppf 394 31.13 12134.21 2331.47 2300.34 3.50 2.992 2.867 384 Tubing_9.3ppf 385 31.1 12165.31 2300.34 2269.24 3.50 2.992 2.867 385 Tubing_9.3ppf 386 31.11 12196.42 2269.24 2238.13 3.50 2.992 2.867 386 Tubing_9.3ppf 387 31.1 12227.52 2238.13 2207.03 3.50 2.992 2.867 387 Tubing_9.3ppf 388 31.13 12258.65 2207.03 2175.90 3.50 2.992 2.867 388 Tubing_9.3ppf 389 31.13 12289.78 2175.90 2144.77 3.50 2.992 2.867 389 Tubing_9.3ppf 390 31.17 12320.95 2144.77 2113.60 3.50 2.992 2.867 390 Tubin 9.3ppf 391 31 12351.95 2113.60 2082.60 3.50 2.992 2.867 391 Tubing_9.3ppf 392 31.05 12383.00 2082.60 2051.55 3.50 2.992 2.867 392 Tubing_9.3ppf 393 31.01 12414.01 2051.55 2020.54 3.50 2.992 2.867 393 Tubing9.3ppf 394 31.1 12445.11 2020.54 1989.44 3.50 2.992 2.867 394 Tubing_9.3ppf 395 31.13 12476.24 1989.44 1958.31 3.50 2.992 2.867 395 Tubing_9.3ppf 396 31.16 12507.40 1958.31 1927.15 3.50 2.992 2.867 396 Tubing_9.3ppf 397 31.09 12538.49 1927.15 1896.06 3.50 2.992 2.867 397 Tubing_9.3ppf 398 31.04 12569.53 1896.06 1865.02 3.50 2.992 2.867 398 Tubing_9.3ppf 399 31.04 12600.57 1865.02 1833.98 3.50 2.992 2.867 399 Tubing_9.3ppf 400 30.95 12631.52 1833.98 1803.03 3.50 2.992 2.867 400 Tubing_9.3ppf 401 31.1 12662.62 1803.03 1771.93 3.50 2.992 2.867 401 Tubing_9.3ppf 402 31.1 12693.72 1771.93 1740.83 3.50 2.992 2.867 402 Tubing_9.3ppf 403 31.02 12724.74 1740.83 1709.81 3.50 2.992 2.867 403 Tubing2.3ppf 404 31.1 12755.84 1709.81 1678.71 3.50 2.992 2.867 404 Tubing2.3ppf 405 31.1 12786.94 1678.71 1647.61 3.50 2.992 2.867 405 Tubing_9.3ppf 406 30.96 12817.90 1647.61 1616.65 3.50 2.992 2.867 406 Tubing_9.3ppf 407 31.13 12849.03 1616.65 1585.52 3.50 2.992 2.867 407 Tubing_9.3ppf 408 30.99 ".12880.02 1585.52 1554.53 3.50 2.992 2.867 408 Tubing_9.3ppf 409 31.13 -- 12911.15 1554.53 1523.40 3.50 2.992 2.867 409 Tubing_9.3ppf 410 30.93 12942.08 1523.40 1492.47 3.50 2.992 2.867 410 Tubing_9.3ppf 411 31.15 12973.23 1492.47 1461.32 3.50 2.992 2.867 411 Tubing_9.3ppf 412 31.09 13004.32 1461.32 1430.23 3.50 2.992 2.867 412 Tubing 9.3ppf 413 31.08 13035.40 1430.23 1399.15 3.50 2.992 2.867 413 Tubing_9.3ppf 414 31.06 13066.46 1399.15 1368.09 3.50 2.992 2.867 414 Tubing_9.3ppf 415 31 13097.46 1368.09 1337.09 3.50 2.992 2.867 415 Tubing_9.3ppf 416 31.13 13128.59 1337.09 1305.96 3.50 2.992 2.867 416 Tubing_9.3ppf 417 31.07 13159.66 1305.96 1274.89 3.50 2.992 2.867 417 Tubing_9.3ppf 418 31.04 13190.70 1274.89 1243.85 3.50 2.992 2.867 418 Tubing_9.3ppf 419 30.95 13221.65 1243.85 1212.90 3.50 2.992 2.867 419 Tubing_9.3ppf 420 31.03 13252.68 1212.90 1181.87 3.50 2.992 2.867 420 Tubing_9.3ppf 421 31.12 13283.80 1181.87 1150.75 3.50 2.992 2.867 421 Tubing_9.3ppf 422 31.07 13314.87 1150.75 1119.68 3.50 2.992 2.867 422 Tubing_9.3ppf 423 31 13345.87 1119.68 1088.68 3.50 2.992 2.867 423 Tubing_9.3ppf 424 30.96 13376.83 1088.68 1057.72 3.50 2.992 2.867 424 Tubing_9.3ppf 425 30.5 13407.33 1057.72 1027.22 3.50 2.992 2.867 425 Tubing_9.3ppf 476 31.12 13438.45 1027.22 996.10 3.50 2.992 2.867 426 Tubing_9.3ppf 427 30.96 13469.41 996.10 965.14 3.50 2.992 2.867 427 Tubing_9.3ppf 428 31.28 13500.69 965.14 933.86 3.50 2.992 2.867 428 Tubing_9.3ppf 429 30.1 13530. 933.86 903.76 3.50 2.992 2.867 429 Tubing_9.3ppf 430 31.14 , 13561 903.76 872.62 3.50 2.992 2.867 430 Tubing_9.3ppf 431 31.06 13592.99 872.62 841.56 3.50 2.992 2.867 431 Tubing_9.3ppf 432 31.03 13624.02 841.56 810.53 3.50 2.992 2.867 432 Tubing_9.3ppf 433 31.13 13655.15 810.53 779.40 3.50 2.992 2.867 433 Tubing_9.3ppf 434 31.1 13686.25 779.40 748.30 3.50 2.992 2.867 434 Tubing_9.3ppf 435 31.08 13717.33 748.30 717.22 3.50 2.992 2.867 435 Tubing_9.3ppf 436 31.11 13748.44 717.22 686.11 3.50 2.992 2.867 436 Tubing_9.3ppf 437 31.13 13779.57 686.11 654.98 3.50 2.992 2.867 437 Tubing_9.3ppf 438 30.94 13810.51 654.98 624.04 3.50 2.992 2.867 438 Tubing_9.3ppf 439 31.03 13841.54 624.04 593.01 3.50 2.992 2.867 439 Tubing_9.3ppf 440 30.97 13872.51 593.01 562.04 3.50 2.992 2.867 8 SLB_Equip SLB Equip TRMAXX-5E Bottom Pup (9.2# TC -II BOX x H563 9.2# PIN) 3-1/2 TRMAXX-5E 5K SSSV 14.72 4.31 13887.23 13891.54 562.04 547.32 _ W 51,191. 3.89 5.18 2.992 2.915 2.808 2.808 440 SLB Equip A Tubing_9.3ppf Jill MAXX-SE Upper Pup (9.2# H563 BOX x 9.2# TC -II PIN) 441 14.83 31 13906.37 13937.37 543.01 528.18 528.18 497.18 4.26 3.50 2.992 2.992 2.808 2.867 441 Tubing_9.3ppf 442 31.14 13968.51 497.18 466.04 3.50 2.992 2.867 442 Tubing_9.3ppf 443 31.13 1 13999.64 466.04 434.91 1 3.50 2.992 2.867 443 Tubing_9.3ppf 444 31.1 14030.74 434.91 403.81 3.50 2.992 2.867 444 Tubing_9.3ppf 445 31.13 14061.87 403.81 372.68 3.50 2.992 2.867 445 Tubing_9.3ppf 446 31.13 14093.00 372.68 341.55 3.50 2.992 2.867 446 Tubing_9.3ppf 447 31.03 14124.03 341.55 310.52 3.50 2.992 2.867 447 Tubing_9.3ppf 448 31.08 14155.11 310.52 279.44 3.50 2.992 2.867 448 Tubing_9.3ppf 449 30.98 14186.09 279.44 248.46 3.50 2.992 2.867 449 Tubing_9.3ppf 450 31.08 14217.17 248.46 217.38 3.50 2.992 2.867 450 Tubing_9.3ppf 451 31.12 14248.29 217.38 186.26 1 3.50 2.992 2.867 451 Tubing_9.3ppf 452 30.94 14279.23 186.26 155.32 3.50 2.9921 2.867 452 Tubing_9.3ppf 453 31.09 14310.32 155.32 124.23 3.50 2.992 2.867 453 Tubing_9.3ppf 454 30.95 14341.27 124.23 93.28 3.50 2.992 2.867 454 Tubing_9.3ppf 455 31.11 14372.38 93.28 62.17 3.50 2.992 2.867 Pups 1 1.69 14374.07 62.17 60.48 3.50 2.992 2.867 455 Tubing_9.3ppf 456 31.05 14405.12 60.48 29.43 3.50 2.992 2.867 Pups HP 1.87 14406.99 29.43 27.56 4.50 3.958 3.833 Tubing Hanger Tubing Hanger 1.1 14408.09 27.56 26.46 113.63 3.900 3.900 RKB to LDS 35.25 Squat for 6k Ibf in Compression 8.79 MEMORANDUM TO: Jim Regg P. I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: 12/19/18 SUBJECT: Expro Well Test Unit Hansen H -16A - PTD 2180950 BlueCrest 12/17/18: 1 traveled to BlueCrest's Hansen Pad. I met with BlueCrest representative Vance Yoakum and we discussed how he was going to do a pressure test of the safety system on the Expro well test unit. I first witnessed a passing function test done on the H -16A surface safety valve (SSV) and the subsurface safety valve — there was no differential pressure to do a performance test on the well safety valve system valves. The Expro test unit had their own SSV about eight feet downstream of the well. Test results were as follows: Wellhead to Expro's SSV test: Pre -Test 0 psi Start 1860 psi 15 min 1854 psi 30 min 1852 psi " Wellhead to Expro unit test: Pre -Test 0 psi Start 1850 psi 15 min 1835 psi 30 min 1832 psi Attachments: none - 2018-1217_WeII_Test_Unit_Hansen_H-16A bn.docx Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA)�{y (Z,j Sent: Thursday, December 6, 2018 10:58 AM (1 �'I l� To: Alecia Wood Cc: larry.burgess@bluecrestenergy.com; TracOps'; Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: SVS Test Within First 5 Days _ Waiver Request for H16A PTD 2 96 through 218-102 216-04/ v Thank you for providing the Expro test system P&ID (Drawing # WT-XAK-20107) and the procedure for the well test emergency shut down system (ESD System Check). A passing performance test of the Expro SSV (P&ID Tag 20-XAK- 004) must be completed before commencing flow through the well test system (LPS trip; closure of SSV, and ability to hold pressure differential). Also, the well's SSSV must be function tested. Performance testing the well's normal SVS (including SSSV) may be deferred up to 14 days after startup of flowback from well H -16A. The well SVS must be made operable and performance tested after flowback operations are completed and the well is placed in service. BlueCrest must provide notice to AOGCC for the opportunity to inspect the Expro well test system when rigged up on H -16A and to witness the Expro SSV performance test. Jim Regg Supervisor, Inspections AOGCC 333 W.7�h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.re¢zru@alaska.eov. From: Alecia Wood <alecia.wood@bluecrestenergy.com> Sent: Tuesday, December 4, 2018 3:48 PM To: Regg, James B (DOA) <jim.regg@alaska.gov> Cc: larry.burgess@bluecrestenergy.com; TracOps' <fracops@bluecrestenergy.com> Subject: RE: SVS Test Within First 5 Days _ Waiver Request for H16A PTD 218-096 through 218-102 Jim, Attached is the test procedure from Expro. We will pressure test the SSSV from below before the rig N/D the BOP and N/U the tree. They will test the self equalization of the valve, that it holds pressure from below and allow it to open. We can do a function test of the hydraulics after the rig releases it however without DP we will not be able to see if the valve is open/closed until we start the flowback and unload the kill weight fluid. Alecia From: Regg, James B (DOA) [mai Ito: jim.reggC:i)alaska.govj Sent: Wednesday, November 28, 2018 2:09 PM To: Alecia Wood Subject: RE: SVS Test Within First 5 Days _ Waiver Request for H16A PTD 218-096 through 218-102 Please provide the test procedure for the Expro well test unit's safety valve system (equivalent to well SSV). Will the SSSV be function tested as done with H-12? Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.reggOalaska.gov. From: Alecia Wood <alecia.wood@bluecrestenerl;v.com> Sent: Monday, November 26, 2018 2:30 PM To: Regg, James B (DOA) <iim.reee@alaska.aov> Cc: 'Joshua Hall' <ioshua.hall@bluecrestenergV.com>; 'FracOps' <fracops@bluecrestenerey.com>; 'Larry Burgess' <la rry.buraess@ bl uecrestenerry.com> Subject: SVS Test Within First 5 Days _ Waiver Request for H16A PTD 218-096 through 218-102 Hi Jim, We are approximately two weeks out from bringing our new drill H16A online and are requesting a waiver of the SVS test requirement within the first 5 days of production as we did with H12. We are planning to flow back through Expro (please see attached schematic of the equipment and ESD) to unload the brine and OBM to tanks while flowing the gas to the facility. The well will be completed with open hole laterals and a slotted liner in the main bore, we are requesting permission to continue flowing back the well while it is cleaning up which may take more than 5 days (Estimate 30-14 days?)to minimize water hammering. Once the fluids have cleaned up and the well stabilizes we will turn the well over to operations and submit our witness notification to test our SVS as soon as possible. Please let me know if you approve or have any questions or concerns. Thank you! Alecia Wood Alecia Wood Sr. Production Engineer BlueCrest Energy Inc 3301 C Street, Suite 202 Anchorage, AK 99503 Alecia.Wood@BlueCrestEnergy.com (w)907 -754 -9556(m)907 -394-2485(f)907-754-5997 Level: Fun, I Product Line: 0 Global well Test Document Type: Procedure Title: ESD System Check © July 2018 by Expro - ALL RIGHTS RESERVED This document may not be reproduced, either wholly or in part, nor may it be used by, or its contents divulged to, any other person whosoever without written permission of Expro. Furthermore the Master Copy of this document is held and formally controlled within Insight. Hard copies may be printed but will not be updated. Please refer to Insight for the latest revision. Document Number: INS -002021 Revision: 3 r=xPF10 Rev.3 Revision List Revision Reason for Change Issued Owner Reviewer Approver 01 01 -July -2012 E. Riddell D. Cleland 02 DCR-425, PIR 32332 23 -Dec -2014 H. Selim E. Riddell D. Cleland 1.0 Insight first Release 26/05/2015 H. Selim E. Riddell D. Cleland 2.0 Amendment to headers 01/06/2015 H. Selim E. Riddell D. Cleland 3.0 DCR4072 removed old 2-QMS references and added INS numbers 05/July/2018 D. Cleland H. Selim D. Cleland � yrx � VJ✓ J JlClll VIICt�f� -----� -- Rev. 3 CONTENT 1 Purpose.......................................................................................................................4 2 Responsibilities..........................................................................................................4 3 Safety...........................................................................................................................4 4 Remote Shut Down Buttons...................................................................................... 4 5 Hi/Low Pressure Activated Pilots..............................................................................5 Rev. 3 1 Purpose The purpose of the following procedure is to ensure the Well Test Emergency Shut Down system is fully functioned and tested prior to operations commencing. The ESD system including remote location shut down buttons and Hi/Low pressure activated pilots must be rigged up as per the submitted and approved P&ID. 2 Responsibilities The Well Test Operations' Manager is responsible for the implementation of this procedure assisted by the relevant Operations Supervisors. 3 Safety The safety of personnel is of paramount importance; operations will only commence once the following has been correctly completed: • All equipment correctly installed and pressure tested as per the P & ID. • A Work permit has been obtained, and all conditions therein met. • A Pre Flowing checklist has been reviewed and signed off. All personnel involved attend a pre -job safety meeting. The Expro Well Test Field Supervisor shall review this procedure in conjunction with the Well Test Operational Standards and all relevant risk assessments. 4 Remote Shut Down Buttons All remote location shut down buttons to be function tested individually and ESD valve closure time to be recorded on form INS -002050 - EMERGENCY SHUT DOWN SYSTEM CHECK SHEET. Maximum acceptable time shall not exceed 20 seconds V 6XPRO LJ✓ JyJlGlll Reev.v. -- 3 5 Hi/Low Pressure Activated Pilots For high sensing pressure activating pilot's pressure will be slowly increased in the process flowline until activation of the pilot is achieved. Once the pilot has been tripped timing of the closure of the ESD valve will commence. For low sensing pressure pilot's the ball valve on pilot's 'Normally Open' pneumatic exhaust is to be closed until pressure in process line is slowly increased above the pilot activation pressure. 1. Once process line pressure is above pilot activation pressure the ball valve on the pilots' 'Normally Open' pneumatic exhaust must be opened. 2. Process line pressure can now be bled off until activation of the pilot is achieved. Once the pilot has been tripped timing of the closure of the ESD valve will commence. • On completion of all function tests form INS -002050 - EMERGENCY SHUT DOWN SYSTEM CHECK SHEET must be completed and signed off by all required personnel before operations can commence. Maximum acceptable time shall not exceed 20 seconds During start up Low pressure pilots are isolated until the flow has stabilised. Once the flow has stabilised the isolation should be removed to activate the pilots. This should also be documented on the check sheet. N.B - If any Hi/Low pilots do not activate at their set pressure these can be recalibrated offshore by use of a Dead Weight Tester — This must also be witnessed and recorded on form INS -002050 - EMERGENCY SHUTDOWN SYSTEM CHECK SHEET. ■ I L SURFACE SAFETY VALVE DATA HEADER ARCTIC MOBILE HP SEPARATOR DATA HEADER 3 1/16' 10,000 PSIG 3- FIGURE 1502 10,000 PSIG 42" OD X 15' S—S LENGTH 3" FIGURE 206 2,000 PSIG API 6A DESIGN CODE ASME B31.3 DESIGN PRESSURE 1.400 PSIG O 100 DEG F DESIGN CODE ASME 1331.3 NACE MR0175 NACE MR.01.75 DESIGN CODE NACE MR.01.75 VESSEL:- ASME SECTION VIII DN 1 PIPEWORK: ASME 831.3 MACE MR0175 F-EXPRO T - A 4 6 / NOTES: DRAFT COPY 1. THIS DRAWING HAS BEEN CREATED IN AUTOCAD AND MUST NOT BE MODIFIED MANUALLY. 7. DAiA HEADER CONFIGURATION MAY VARY DEPENDENT ON DATA HEADER TYPE, PORT ORIENTATION, AND ACTUAL PHYSICAL RIG UP. FOR REVIEW ONLY 2. ANY CHANGES SHOULD BE REQUESTED ON ENGINEERING SUPPORT DOCUMENT CHANGE REQUEST FORM: 2-QMS-WT-FRM-001-09. 8- REFER TO WELL TEST DESIGN REPORT WT-XAK-50107 FOR SAFETY SYSTEM PHILOSOPHY. 3. REFER TO EXPRO DOCUMENT WELL TEST PROCESS P&ID / PFD SYMBOL LEGEND 115908 FOR A FULL UST OF DEVICE SYMBOLS 9, INDIRECT UNE HEATER CHOKE TO BE FULLY OPEN WHEN INDIRECT LINE HEATER IS BYPASSED. DRAFT REVISION 04,11/21/2018 AND ABBREVIATIONS USED WITHIN THIS DRAWING. 10.WHEN PRESSURE TESTING OR FLUSHING, THE FLASHING POINT SHALL BE UPSTREAM OF THE SSV WITH SAFETY SYSTEM IN USE TO 4. ALL LOW PRESSURE PILOTS TO BE INSTALLED AT END OF UNE SEGMENTS AND WILL BE ISOLATED ON START UP, UNTIL STABLE PROTECT EQUIPMENT. FLOW IS ACHIEVED, AND SHUTDOWN. 11. ANY "LOCKED" VALVES AS NOTED ON THE P&ID SHALL ONLY BE ON FUNCTIONED TO THE OPPOSITE POSITION BY THE SUPERVISOR 5. HIAO PRESSURE & TEMPERATURE ALARM SETTINS MAY BE MODIFIED OR ISOLATED IN THE FIELD AFTER STABLE FLOW IS UNCONTROLLED COPY D. AND SHALL BE RECORDED ON A TRAC WITH USE OF 'WALK THE LINES.' 6. ALLLL INTERCONNECTING A12.VALVE HP -25 (SEPARATOR SPARGE UNE OUTLET) ARE TO BE CLOSED WHEN THE SAND TRAP SPARGE UNE IS IN USE AND ST -05 ERCONNECTING PIPEWORK HAS A WORKING TEMPERATURE RANGE OF -20F TO 250E IS OPEN. THIS SHALL BE DONE TO PREVENT A BACK FLOW AND OVERPRESSURE SCENARIO IN THE SEPARATOR. A I a L.—_.. --.—J 2'+"1502 -- -- -- -- — L . _ . _ • — . — J BLUECRESf EXPRO A, POSITIVE DISP, CHEMICAL PUMP 01 DEMULSIFIER S7= I L J 2' 502 PBA -105 (3'-A2-cT-oo' I A70.41A7d.4, sssv A COIL TUBING PUMP FAO -001 I PI EXPRO BLUECREST LINE I � I EXPRO 3,/°" -131- CI - 01 1 01 EM LSIFIER EMU /r BLUECREST DCHEMICAL lO CHEMICAL NPT a los TANK LPSv 105 SET AT_1.800 PSIJ C I \ / l J FSyj P E IOZ SET AT 1,417 PSIG Y 4 Y p1S—.--.--.--. i S� L-- -- -- --•-1 I N �_ l' �1, I]�I—' F--- _ _ _ _ ---- ---- -- _ ► - GAS To VERnCAI _ _ I ® BP: w �Ha1 ene Irk SCRUBBER ID I --- - E P. C F.C. N.C. e Z1 J CL05F FHP 2' Y I E L.— — — — • — -- — —• —— — — - ———— -—— -—— - — —• —— — NOfE t2 I 1502 25 1502 z' -A4- r -ens SAND / DRAIN TO 400 BBL A—TANK O Design right PIPEWORK IDENTIFICATION DEVICE SYMBOLS ABBREVIATIONS REVISION HISTORY EXPRO NORTH SEA MAXIMUM FLOWING PARAMETERS LIMITED This REF MAWP REF DESCRIPTION SYM DESCRIPTION — SYM DESCRIPTION SYM DESCRIPTION SYM DESCRIPTION SYM DESCRIPTION AS PER CLIENT QUESTIONAIRE DATE REV # REASON FOR ISSUE BY CHK APRV document and all 1 15,000 PSIG FF FLUID FLOW IIII FLAME ARRESTOR - RUPTURE � BP BLEED PORT N.C. NORMALLY CLOSED 10/12/2017 _ A FIRST RELEASE SO GB AA the information it 2 10,000 PSIG OF OIL FLOW DISC VALVE BPV BACK PRESSURE VALVE N.O. NORMALLY OPENED PHASE RATE SG 30 -Nov -17 B SECOND RELEASE SO LT AA contains is 3 4 7,500 PSIG GF 5,000 PSIG WF GAS FLOW WATER FLOW -� STRAIGHTENING G � _ __ CONTROL VALVE FIXED CHOKE CI CHEMICAL INJECTION PI PRESSURE INDICATOR OIL 150 BOPD confidential and the property of 5 2,000 PSIG CH COMP. AIR VANES _ DP DPT DIFFERENTIAL PRESSURE DIFF. PRESS. TRANSDUCER PIC PIT PRESSURE CONTROLLER PRESSURE TRANSDUCER GAS 1.7 MMSCFD EXPRO NORTH SEA 6 1.440 PSIG SH STEAM FLOW &<1 REGULATOR AIR SUPPLY C� ADJ. CHOKE CC CORROSION COUPON PR PRESSURE RECORDER WATER 50 BPD LIMITED and is not 7 1,000 PSIG V VENT LINE `-�- F.C. FAIL SAFE CLOSED PSE RUPTURE DISC to be reproduced, communicated to a $ 250 PSIG RF RELIEF LINE STA STEAM TRAP � SAFETY VALVE � SWAGE FM FLOW METER PSH HIGH PRESSURE PILOT CITHP (PSIG) 325 PROPOSED P&ID FOR WELL TESTING 9 200 PSIG CI CHEM. INJECTION third party or used 10 100 PSIG _ A PIPE II/���"'VVV F.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOT FTHPREDUIRED(PSIG) 815 AUTHOR S. OYAO B LU EC R EST ALASKA OPERATING LLC in any manner 11 1,160 PSIG B HOSE ,M---- PNEUMATIC LINE � � VALVE SAFETY VALVE FRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVE FTHT (deg F) 20 — 75 DATE 10/06/2017 whatsoever TEMPORARY PIPEWORK TEMPERATURE Db OPEN CLOSED FSV FLOW CHECK VALVE SDT SAND DETECTION MAXIMUM TUBING TEST PRESSURE H-16 / H —1 A without the prior _ LC LEVEL CONTROLLER SDV SHUTDOWN VALVE (ESD) (PSIG) -- written consent of CONSTRAINTS I I � HYDRAULIC LINE �U� CLAMP CONNECTION I1 — HAMMER UNION LCV LEVEL CONTROL VALVE SP SAMPLE POINT - -- PAGE DRAWING NUMBER REV EXPRO NORTH SEA COFLEXIP HOSE -4F TO +266F LG LEVEL GAUGE TI TEMPERATURE INDICATOR — 0 — LIMITED. HAMMER UNION PIPEWORK -20F TO +250F �_ FLOW CHECK FLANGE CHOKE INLINE LSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCER CO2(%) EXPR 1 OF 2 WT—XAK — 20107 REV C RUBBED PIPEWORK -20F TO +350F VALVE CONNECTION LSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENT H2S (PPM) 5 — 15 2 /+ 5 6 7 R HP GAS SCRUBBER 400 MOSPHERIC TANK 36" OD X 10' S -S LENGTH MAWP ATMOSPHERIC DESIGN PRESSURE 1,400 PSIG O 100 DEC F CAPACITY: 400 BBL DESIGN CODE DESIGN CODE VESSEL- ASME SECTION VIII DIV 1 PIPEWORK: ASME 831.3 PIPEWORK: ASME 831.3 NACE MR0175 A --- 01 ■ QGAS TO vERnCAL SCRUBBER RELIEF TO 4D0 BBL OPEN TOP TANK FI OIL TO 400 BBL > Illp_ A -TANK (3' -A5 -0F-005' SAND / DRAIN TO 400 BBL A -TANK 4 6 / NOTES: 1. THIS DRAWING HAS BEEN CREATED IN AUTOCAD AND MUST NOT BE MODIFIED MANUALLY. 7. DATA HEADER CONFIGURATION MAY VARY DEPENDENT ON DATA HEADER TYPE, PORT ORIENTATION, AND ACTUAL PHYSICAL RIG UP. DRAFT COPY 2. ANY CHANGES SHOULD BE REQUESTED ON ENGINEERING SUPPORT DOCUMENT CHANGE REQUEST FORM: 2-OMS-WT-FRM-001-09. 8, REFcR TO WELL TEST DESIGN REPORT WT-XAK-50107 FOR SAFETY SYSTEM PHILOSOPHY. FOR REVIEW ONLY 3. REFER TO EXPRO DOCUMENT WELL TEST PROCESS P&ID / PFD SYMBOL LEGEND 115908 FOR A FULL LIST OF DEVICE SYMBOLS 9• INDIRECT LINE HEATER CHOKE TO BE FULLY OPEN WHEN INDIRECT LINE HEATER IS BYPASSED. AND ABBREVIATIONS USED WITHIN THIS DRAWING. 10.WHEN PRESSURE TESTING OR FLUSHING, THE FLASHING POINT SHALL BE UPSTREAM OF THE SSV WITH SAFETY SYSTEM IN USE TO DRAFT REVISION 04,11/21/2018 4. ALL LOW PRESSURE PILOTS TO BE INSTALLED AT END OF LINE SEGMENTS AND WILL BE ISOLATED ON START UP, UNTIL STABLE PROTECT EQUIPMENT. FLOW IS ACHIEVED, AND SHUTDOWN. 11. ANY "LOCKED" VALVES AS NOTED ON THE P&ID SHALL ONLY BE ON FUNCTIONED TO THE OPPOSITE POSITION BY THE SUPERVISOR 5. HI/LO PRESSURE & TEMPERATURE ALARM SETTINS MAY BE MODIFIED OR ISOLATED IN THE FIELD AFTER STABLE FLOW IS AND SHALL BE RECORDED ON A TRAC WITH USE OF 'WALK THE LINES." ACHEIVED. UN N LLIED COPY 12.VALVE HP -25 (SEPARATOR SPARGE UNE OUTLET) ARE TO BE CLOSED WHEN THE SAND TRAP SPARGE UNE IS IN USE AND ST -05 6. ALL INTERCONNECTING PIPEWORK HAS A WORKING TEMPERATURE RANGE OF -20f TO 250E IS OPEN. THIS SHALL BE DONE TO PREVENT A BACK FLOW AND OVERPRESSURE SCENARIO IN THE SEPARATOR. --- -- A rVENT STACK X36-XAK-006 I I I --- ------ --- --- --- --- - - ---•--•--•--•-----•----•--•-- rVERTICAL GAS SCRUBBER I 01 _ _ P9 Ps �I MBF -103004 740 1,440 IA4o6 A4►.4 A4.2 A.0.2,\/ I L.-- -- -- -- -- -- - ---•-- --- - -- --- I L.-- ------- --- ----- -- -- ------- --- -- - J I 1,356 PSI ATM BLUECR� EURO EXPRO BLUECREST 3--a5=GF-008 1,440 PSI AT1 400 BBL HORIZONTAL OPEN -TOP TANK I ABJ -105 I O I I I I I I I I O I I 1 I 1 680 PSS I+ATM I U3 I I 206 J 206 - 1 I I 2- 2- I 3• 1502 l oa l 15021 As ZT ( 208 1,350 PSI ATM - - - - - - - --BLUECREST EXPRO EXPRO BLUECREST TO VAC TRUCK EXPRO BLUECREST VENT TO SAFE AREA 3'-R9._IF 010 IB IE .. 2--A4-FF-006 Design right EXPRO NORTH SEA LIMITED. This document and all the information it contains is confidential and the property of EXPRO NORTH SEA LIMITED and is not to be reproduced, communicated to a third party or used in any manner whatsoever without the prior written consent of EXPRO NORTH SEA LIMITED. PIPEWORK IDENTIFICATION DEVICE SYMBOLS SYM BP BPV ClCI DP DPT CC F.C. FM F.O. FRT FSV LC LCV LG LSH LSL ABBREVIATIONS DESCRIPTION SYM DESCRIPTION BLEED PORT N.C. NORMALLY CLOSED BACK PRESSURE VALVE N.O. NORMALLY OPENED CHEMICAL INJECTION PI PRESSURE INDICATOR DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLER DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCER CORROSION COUPON PR PRESSURE RECORDER FAIL SAFE CLOSED PSE RUPTURE DISC FLOW METER PSH HIGH PRESSURE PILOT FAIL SAFE OPEN PSL LOW PRESSURE PILOT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVE FLOW CHECK VALVE SDT SAND DETECTION LEVEL CONTROLLER SDV SHUTDOWN VALVE (ESD) LEVEL CONTROL VALVE SP SAMPLE POINT LEVEL GAUGE TI TEMPERATURE INDICATOR LEVEL SAFETY HIGH TIT TEMP. TRANSDUCER LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENT MAXIMUM FLOWING PARAMETERS AS PER CLIENT QUESTIONAIRE PHASE RATE SG OIL 150 BOPD GAS 1.7 MMSCFD - -- WATER 50 BPD CITHP (PSIG) 325 FTHP REQUIRED (PSIG) 815 FTHT (deg F) 20-75 MAXIMUM TUBI PEST PRESSURE SIG ( CO2 (%) H2S (PPM) 5 - 15 — REVISION HISTORY DATE REV # REASON FOR ISSUE BY CHK 10/12/2017 A FIRST RELEASE _ SO GB 30 -Nov -17 B SECOND RELEASE SO LT -_ -PROPOSED P& I D FOR WELL TESTING AUTHOR S. OYAO DATE 10/06/2017 B L U EC R E ST ALASKA OPERATING LLC H-16 / H —1 A _ PAGE DRAWING NUMBER EXPR� 2 OF 2 WT— XAK — 20107 0 APRV AA AA - REV REV C REF MAWP REF DESCRIPTION SYM DESCRIPTION SYM DESCRIPTION SYM DESCRIPTION 1 15,000 PSIG FF FLUID FLOW IIII FLAME ARRESTOR RUPTURE DISC VALVE 2 10,000 PSIG OF OIL FLOW 3 7,500 PSIG GF GAS FLOW r -L- STRAIGHTENING VANES CONTROL VALVE � FIXED CHOKE 4 5,000 PSIG WF WATER FLOW 5 2,000 PSIG CH COMP. AIR 6 1,440 PSIG SH STEAM FLOW � REGULATOR � AIR SUPPLY ADJ. CHOKE Z 1,000 PSIG V VENT LINE 8 250 PSIG RELIEF LINE STA STEAM TRAP III���"'VVV SAFETY VALVE SWAGE 9 200 PSIG ClCI CHEM. INJECTION 10 100 PSIG A PIPE �- - - PNEUMATIC LINE A 17 VALVE SED OPEN CLOSED SAFETY VALVE 11 1,160 PSIG B HOSE TEMPORARY PIPEWORK TEMPERATURE CONSTRAINTS �--�-�- HYDRAULIC LINE -luf- CLAMP CONNECTION I� I HAMMER UNION COFLEXIP HOSE -4F TO +266F FLOW CHECK VALVE FLANGE CONNECTION CHOKE INLINE HAMMER UNION PIPEWORK -20F TO +250F_ HUBBED PIPEWORK -20F TO +350F 1 2 4 5 6 7 R 0410 041 &e7 0CP too jol k02 01111i- ivABORS / CAI�RIG i -dl 1 1 6TM un e '-'boxes ain, (Bundle 2- 7 Boxes) 1.01, 1.02, 1.03, L047 L057 L061 L07 API: 5023120051- 01-00 _ _ .. TD: 11 /18/2018 Set (10 & 11 trays /set) Type Frequency Interval (Feet MD) PL ILI Washed and Dried Operator: BlueCrest Alaska Operating Date: 11/20/2018 LLC Well Name: H16A Main, 1-01, 1.021 1-031 1.04,L05,1.06,1-07 Prepared BY: Alan Febus Location: Kenai Borough, Alaska Shipping: 333 W 7t" Ave, Suite 100 Anchorage, AK 99501 L03 (I BOX & 45 Envelopes) Hansen Field 30' 17940'-19268' TD L04 (I BOX & 45 Envelopes) Washed and Dried 301 Attn: Meredith Guhl (907)739-1235 i -dl 1 1 6TM un e '-'boxes ain, (Bundle 2- 7 Boxes) 1.01, 1.02, 1.03, L047 L057 L061 L07 API: 5023120051- 01-00 _ _ .. TD: 11 /18/2018 Set (10 & 11 trays /set) Type Frequency Interval (Feet MD) H16A Main (6 Boxes & 258 Envelopesl Washed and Dried 309 145803 - 22310' 1.01 (1 BOX & 38 Envelopes) Washed and Dried 30' 16320'-17440' TD L02 (I BOX 843 Envelopes) Washed and Dried 30' 17100'-18390' TD L03 (I BOX & 45 Envelopes) Washed and Dried 30' 17940'-19268' TD L04 (I BOX & 45 Envelopes) Washed and Dried 301 18660' — 20010' TD L05 (I BOX & 42 Envelopes) Washed and Dried 30' — 20743' TD L06 (I BOX & 36 Envelopes) Washed and Dried 30' 119500' 20280'— 21340' TD L07 (I BOX & 24 Envelopes) Washed and Dried 30' 21150'— 21860' TD Number of Boxes: 13 & Number of Envelot)es: 531 106� lj-062- oes'; 066 '(ee's '06P 'be* - Number of Boxes: 13 RECEIVED Packaged into 2 Shipping Bundles NOV 2 6 2018 Bundle 1: Main (6 Boxes) AOGCC Number of Envelopes: 258 Bundle 2: L01, 1.021 L031 L047 L057 L.06, L07 (7 Boxes) Number of Envelopes: 531 BLU ECREST RIG #1 / JOB #: A1712 / WELL: H 16A: L01, L02, 1-031 1.041 L05, 1-061 L07 THE STATE Alaska 01*1 and Gas Of Conservation Commission ALASKA GOVERNOR BILL WALKER Larry Burgess Alaska Manager BlueCrest Alaska Operating, LLC 3301 C Street Suite 202 Anchorage, AK 99503 Re: Hansen Field, Undefined Oil Pool,, H 16A BlueCrest Alaska Operating, LLC Permit to Drill Number: 218095 Surface Location: 2408' FSLI) 1509" FEL, SEC. 2,, T4S, R15W, SM Bottomhole Location: 1950'FSL, 2933' FEL,, SEC. 295 T3S,, R15W5 SM Dear Mr. Burgess: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs nm must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code., or an AOGCC. order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. Foerster Commissioner DATED this *day of September, 2018. STATE OF ALASKA RECEIVED ALA. A OIL AND GAS CONSERVATION COMMIS., N PERMIT TO DRILL JUL Z 6 X018 20 AAC 25.00.5 1 a. Type of Work: lb. Proposed Well Class:-,-Exploratory.-_,,Ga5, ❑ Service - WAG ❑ Service - Disp ❑ Drill ,ag Lat I tratigraphic Test Development - Oiler ❑ Service - Winj ❑ Single Zone Q Redrill e xploratory -Oil pment -Gas Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates Geothermal ❑Shale Gas 2. Operator Na 1 4W BlueCrest Alaska Operating LLC 5. Bond: Blanket ❑ Single Well ❑ Bond No. 5511251547 11. Well Name and Number: H16A - Mainbore 3. Address: 3301 "C" Street, Suite 202, Anchorage, AK 99503 6. Proposed Depth: MD: 22,829' TVD: 638801 F 12. Field/Pool(s): Hansen, Undefined Oil Pool 4a. Location of Well (Governmental Section): Surface: 2408' FSL, 1509' FEL, Sec. 2, T4S, R15W SM Top of Productive Horizon: 2572' FSL, 1182' FEL, Sec. 33, T3S, R15W SM Total Depth: 1950' FSL, 2933' FEL, Sec. 29, T3S, R15W SM 7. Property Designation: ADL 18790, ADL 384403, Fee -Hansen 8. DNR Approval Number: LOCI 14-007 13. Approximate Spud Date: 9/15%2018 9. Acres in Property: 14423 14. Distance to Nearest Property: 694' (Y01665) 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 168863 y- 2144856.073 Zone- 4 10. KB Elevation above MSL (ft): 180.4 GL / BF Elevation above MSL (ft): 145.81 15. Distance to Nearest Well Open to Same Pool: 342'- Hansen 1A -L1 16. Deviated wells: Kickoff depth:/'0-- 5 feet Maximum Hole Angle: 115 degrees 9 9 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3 549 psi p Surface. 2,842 psi (using 7,070 TVD) 18. Casing Program: Specifications r.r Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8.5 4.5 12.6 Pilo H563 8474 14355 7067 22829 6880 Slotted Liner - No Cement; 100' lap 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): Casing Length Size Cement Volume MD TVD Conductor/Structural 146 20" N/A - Driven 187 187 Surface 4136.5 13-3/8" 588 bbls Lead; 198 bbls Tail 4177 3175 Intermediate 14726 9-5/8" 178 bbls Tail 14767 7083 Production Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes ❑ No 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch a Drilling Program Seabed Report Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis 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: Thomas McKay Authorized Name: Larry Burgess Contact Email: tom.mckay(�bluecrestenerQycom Authorized Title: Alaska Manager Contact Phone: 907-754-9566 Authorized Signature: Date: 26 -Jul -18 4Z Commission Use Only Permit to Drill Number: ,..� O API Number: 50- ... �(� ,,... D .-► �� Permit ApprovalSee ?" Date: s I Z a I � J cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in slaal Other: .5-00 �y ��'"�,`T--�, (�„j it'Mel!5�&& 6 Samples req'd: Yes ❑ No Mud log req'd: Yes o 2S measures: Yes ❑ No Directional svy req'd: Yes o ❑ Spacing exception req'd: Yes yNo ❑ Inclination -only svy req'd: Yes E]No Post initial injection MIT req'd: Yes D',Io ❑ APPROVED BY Approved by:QUA/�COMMISSIONER THE COMMISSION Date: (?F9(13 Ity Submit Form and Form 10-401 Revised 5/2017 This permit is valid f' tr3lat&ft,'provall per 20 AAC 25.005(g) Attachment in Duplicate, M&RmowvV_R'1M JV'K, D Ilu est Energy 3301 C Street, Suite 202, Anchorage, AK 99503 Thomas W. McKay, P.E. Phone: (907) 754-9566 Email: tom.mckay@bluecrestenergy.com July 26, 2018 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Cosmopolitan Project RE: Application for Permit to Drill: Horizontal Production Well H16A — Fishbone Sidetrack Form 10-401; Fishbone Multilateral Well Design Dear Commissioners, BlueCrest Alaska Operating LLC hereby applies for a Permit to Drill for the onshore horizontal production well H16A — Fishbone Sidetrack. This well will be drilled and completed using BlueCrest Rig #1. The planned spud date could be as early as 15 Sept 2018. H16A will be a multilateral producer, employing seven (7) "fishbone" style ribs drilled off the mainbore up into the full section of reservoir present on this Lease. The H16A well will be sidetracked off a whipstock set in the 9-5/8" casing of the original H16 wellbore. The H16A Fishbone Sidetrack well will not be fracture stimulated but instead will rely on the seven (7) rib wellbores to drain the hydrocarbon fluids, etc. into the main bore which will be cased with a 4-1/2 slotted liner. The well will be completed with 3-1/2" tubing and lifted using gas lift. Please find attached for the review of the Commission form 10-401, and the information required by 20 ACC 25.005 for this well. Please note that the eight (8) Spacing Exceptions for this H16A well have already been submitted. Also note that seven (7) additional yet abbreviated APD packages will be submitted for each well "rib" numbered 1-7, which are proposed to be open hole sidetracks off the mainbore. As per AOGCC regulations, each rib requires its own unique name and APD. If you have any questions or require further information, please do not hesitate to contact Tom McKay at 907-754-9566 (office) or 907-350-9544 (cell). Sincerely, ez--, Larry Burges Alaska Manager BlueCrest Alaska Operating LLC Ilue est Energy Cosmopolitan Project H16 -A-1 0-401 Fishbone Sidetrack APD Application for Permit to Drill Document Horizontal Producer H16 -A — Fishbone Sidetrack Multilateral - Mainbore Table of Contents 1. Well Name..man .............. woman mammon mamma ................................................ mom son man .......................3 Requirementsof 20 AAC 25.005(f).............................................................................................................. 3 2. location Summary..... No ammommom MEMO MEN mammon am so son sommosommommomon mommummums 3 Requirements of 20 AAC 25.005(c)(2).......................................................................................................... 3 Requirementsof 20 AAC 25.050(b).............................................................................................................. 3 3. Blowout Prevention Equipment Information..................................................................4 Requirements of 20 AAC 25.005(c)(3).......................................................................................................... 4 4. Drilling Hazards Information.........................................................................................4 Requirements of 20 AAC 25.005 (c)(4)......................................................................................................... 4 DrillingHazards Summary: ..................................................................................................................... 6 5. Procedure for Conducting Formation Integrity Tests.......................................................7 Requirements of 20 AAC 25.005 (c)(5)......................................................................................................... 7 6. Casing and Cementing Program.....................................................................................7 Requirementsof 20 AAC 25.005(c)(6).......................................................................................................... 7 7. Diverter System Information.........................................................................................8 Requirementsof 20 AAC 25.005(c)(7).......................................................................................................... 8 8. Drilling Fluid Program...................................................................................................9 Requirements of 20 AAC 25.005(c)(8) ..........................................................................................................9 9. Abnormally Pressured Formation Information................................................................9 Requirements of 20 AAC 25.005 (c)(9)......................................................................................................... 9 10. Seismic Analysis...........................................................................................................9 Requirementsof 20 AAC 25.005 (c)(10)....................................................................................................... 9 11. Seabed Condition Analysis............................................................................................9 Requirements of 20 AAC 25.005 (c)(11)....................................................................................................... 9 12. Evidence of Bonding...................................................................................................10 Requirements of 20 AAC 25.005 (c)(12).....................................................................................................10 13. Proposed Drilling Program..........................................................................................10 Requirements of 20 AAC 25.005 (c)(13).....................................................................................................10 11Page H16 -A10-401 Fishbone Sidetrack APD Ilu est Energy Cosmopolitan Project H16 -A10-401 Fishbone Sidetrack APD 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.....................................10 Requirements of 20 AAC 25.005 (c)(14)..................................................................................................... 10 15. Attachments...................................................................................... ........................ 10 Attachment 1 Drilling Procedure...............................................................................................................10 Attachment2 Directional Plan..................................................................................................................10 Attachment 3 Casing Design Calculations (see H16 APD package)...............................................................10 Attachment 4 Formation Integrity And Leak Off Test Procedure................................................................... 10 Attachment 5 BOP & Choke Manifold Configuration...................................................................................10 Attachment 6 Wellhead & Tree Configuration............................................................................................10 Attachment 7 Diverter Schematics (N/A)..................................................................................................... 9 Attachment8 Lease Map....................................................................................................................................... 9 21Page H16 -A 10-401 Fishbone Sidetrack APD lust Energy 1. Well Name Cosmopolitan Project H 16-A-1 0-401 Fishbone Sidetrack APC 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. Well Name: H16 -A — Fishbone Sidetrack Multilateral - Mainbore To include the main bore and lower lateral drilling and completion only NOTE: This well will be proposed as a "fishbone" design with a mainbore named as H16 -A, and seven (7) open hole "barefoot" laterals drilled by open hole sidetrack from the mainbore to be named as: H16A-1-01, H16A-1-02, H16A-1-03, H16A-1-04, H16A-1-05, H16A-1-06, and H16A-1-07. The seven (7) laterals or "ribs" will be drilled upward into all the Hemlock and Starichkof reservoir layers at an inclination of 115 degrees, and each will have its own APD package to be submitted as per AOGCC Regulations. This particular package (H16A Fishbone Sidetrack) is for the mainbore H16A drilling and completion operations. 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, except for 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 formation, and at total depth, referenced to governmental section lines. (e) 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; (D) other information required by 20 AAC 25,050(b), Location at Top of Productive Interval ("Starichkof" Sand) Location at Surface - H16 Slot — same for H16A 2408' FSL, 1509' FEL, Sec. 02, T4S, R15W SM Measured Depth, RKB: 14,632' ASP Zone 4 NAD 27 Coordinates Northing: 2,144,856.073' Easting: 168,861.855' RKB Elevation 180.4' AMSL i Pad Elevation 145.811AMSL f Location at Top of Productive Interval ("Starichkof" Sand) 2572' FSL, 1182' FEL, Sec. 33, T3S, R15W SM ASP Zone 4 NAD 27 Coordinates Northing: 2,150,581.45' Easting: 158, 778.19' Measured Depth, RKB: 14,632' Total Vertical Depth, RKB: 71087' Total Vertical Depth, SS: 6,906' Location at Total Depth Requirements 1950' FSL, 2933' FEL, Sec. 29, T3S, R15W SM ASP Zone 4 NAD 27 Coordinates Northing: 2,155,437' Easting: 151,874' Measured Depth, RKB: 22,829' • Total Vertical Depth, RKB: 6,880' ,700' Total Vertical Depth, SS: 6,300-- Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a 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 see Attachment 2: Directional Plan Please see Attachment 8: Lease Map (2) for all wells within 200 feet of the proposed wellbore (A) list the names 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 furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 4, 31Page H16 -A10-401 Fishbone Sidetrack APD nluest Energy Cosmopolitan Project H16 -A-1 0-401 Fishbone Sidetrack APD 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 the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25,035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please see Attachment 5: BOP & Choke Manifold Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) 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: (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 expected reservoir pressure in the Starichkof / Hemlock Sands is —0.472 psi/ft, or 9.07 ppg EMW at 6,951' TVDss taken per MDT's on Cosmopolitan 1. The maximum known pressure in the upper Kenai sands is 9.66 ppg @ 3,841' TVDss per MDT's taken on Cosmopolitan 1. To be conservative, the highest pressure gradient of 9.66 ppg or 0.502 psi/ft will be used to determine MPSP at the production interval of 6,900' TVDss. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.10), and the planned vertical depth of the Starichkof / Hemlock formation is: MPSP=(6,900TVDss) (0.502 - 0.1 psi/ft) & =2,774 psi MPSP=(7,070TVD) (0.502 — 0.1 psi/ft) =2,842 psi (using TVD instead of TVDss for this calculation)` MAX BHP=(71070TVD) (0.502 psi/ft) =3,549 psi (using TVD instead of TVDss for this calculation) (B) data on potential gas zones; The Sterling, Beluga and Tyonek sands within the Kenai group have been known to contain gas. The intermediate section will be drilled with a minimum mud weight of 10.5 ppg, the maximum known pressure through these sections is 9.66 ppg @ 3,841' TVDss per MDT's taken on Cosmopolitan 1. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see the Drilling Hazards Overview below. 41Page H16 -A10-401 Fishborie Sidetrack APD Ilue est Energy O"Wft 4000 5000 101, I,# I Cosmopolitan Project H16 -Ps 1 0-401 Fishbone Sidetrack APID Pressure Model EMW) UpperTyonek, 3292.44 Lower Tyonek, 6059.01 Starichkof, 6874.84 Hemlock, 6902.77 8 9 10 11 12 13 14 15 16 17 18 19 20 EMW (PPG) r— Lithostatic Stress MDT Data Frac Gradient Moving Average Planned Mud Weight "'S. ?, /S 51 P a g e H16 -A10-401 FiSLbborye Sidetrack APD IOest Energy Cosmopolitan Project H16 -A-1 0-401 Fishbone; Sidetrack APD Drilling Hazards Summary (only the 8-1/2" Hole Section applies to this APD): 17-%" Hole Section / 13-%$" Casing Event Risk Level Mitigation Strategy ClayBallingMaintain planned mud parameters, Increase mud weight, use Lost Circulation Low weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in LCM pills, lost circulation material. Surface Formations Low Diverter drills, increased mud weight. Directional Control Low BHA design, on -sight geologic review, avoid "drilling the line". Lost Circulation low Reduced pump rates, mud rheology, lost circulation material, use Tight Hole � of low density cement slurries, control running speeds. 12-%" Hole Section / 9-%" Casing Event Risk Level Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent Lost Circulation Low circulating density (ECD) monitoring, mud rheology, Pre -planned LCM pills, lost circulation material. Hole swabbing on Reduced trip speeds, mud properties, proper hole filling, real time trips Low equivalent circulating density (ECD) monitoring, weighted sweeps. Sloughing Coals, Low Increased mud density and fluid composition according to plan, Tight Hole � controlled tri seeds ECD monitoring, optimized hydraulics for p p g' o p y Low hole cleaning. Abnormal Reservoir Low Well control drills, increased mud weight. Pressure Low H2S drills, detection systems, alarms, standard well control Hydrogen Sulfide Gas low H2S drills, detection systems, alarms, standard well control practices, mud scavengers. ers. g 8-%" Hole Section / 4-%" Slotted Liner Event Risk Level Mitigation Strategy Fluid density according to plan, reduced pump rates, reduced trip Lost Circulation Low speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material. Hole swabbing on Reduced trip speeds, mud properties, proper hole filling, real time trips Low equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Low BHA design, on -sight geologic review. Abnormal Reservoir v Low Well control drills, increased mud weight. Pressure Hydrogen Sulfide Gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers. ers. g 61Paga H16 -A10-401 Fishbone Sidetrack APD nluest Energy Cosmopolitan Project H16 -A-1 0-401 Fishbone Sidetrack APD 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) 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: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f), Please see Attachment 4: Formation Integrity and Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) 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: (6) a complete 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; Casing and Cementing Program — H16 Actual Depths & Cement Volumes for 20", 13-3/8" and 9-5/8" Cs /Tb Hole Size Weigh t Grade Conn Length g Top MD/TVD Btm MD/TVD Cement Program OD (in) ( ) (in) (Ib/1t) (f t) (ft) (ft) 20" N/A •500 A525 Weld 1469 41'/41' 187'/ 187' N/A (in place) Wall r, 13-3/8', � 41 17 7 / 786 TOTAL BBLS 17-1/2 „ R .., '4> � �. 0 _ - ,,- BTC 41136.5 , 40.5-'/40.5 3,175' LEAD: 588 bbls 12.00 ppg Kenai Lead (in place) TAIL. 198 bbls 15.8 ppg Class G 9-5/8" � 13,161'/ 12-1/4►, 47 P-110 Hydril 563 13,120 40.6 /40.6 6,688' (in place) 178 TOTAL BBLS TAIL: 178 bbls 15.8 ppg Class "G" 9-5/8" 13,161'/ ,w 14,767'/ 12-1/4" 53.5 P-110 Hydri1563 11606' 61688' 71083' (in place) 14,255'/ 22,8291/ No cement required „ 4-1/2 „ 8-1/2 1 � : � P-110 Hydri1563 , 8,574 618701 6 880' Slotted liner completion 100' liner lap Please see Attachment 3: Original H16 APD Package for Casing Design Calculations 40 NOTE: The H16A well is proposed to be sidetracked off a whipstock to be set in the 9-5/8" casing. The planned whipstock top -i -s 14,349' M.10and the planned whipstock bottom isf14,362' MD. The 9-5/8" casing will be pressure tested to 3500 ; psi 'prior -to setting the whipstock. The H16 9-5/8" 6--was-cemented (23Jan2017) with 178 bbls of 15.8 ppg Class G cement. Full returns and good lifting pressure were both observed during the primary job. A USIT log and a CBL/VDL log were both run on the 9-5/8" casing after the primary cement job, and an estimated Top of Cement (TOC) was concluded to be at 13,750' MD. Later, a 16.0 ppg FIT without leakoff was achieved upon drill out of the 9-5/8" shoe. As such, it is expected that adequate cement and isolation will be present in H16A for the proposed through -casing sidetrack at these depths. A formal report discussing the 9-5/8" primary cement job for H16 was submitted by BlueCrest, and is on file at the AOGCC for reference. 71Page H16 -A.10-401 Fishbone Sidetr-ack APD Ilue" est Energy Cosmopolitan Project H16 -A-1 0-401 Fishbone Sidetrack APD 7. Diverter System Information 0 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 on 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 is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 5: BOP and Choke Manifold Configuration. A diverter system will not be necessary since the well will be sidetracked out of 9-5/8" casing using the Rig # 1 BOP stack and choke manifold. 81Page H16 -A10-401 Fishbone Sidetrack APD Ilu es[ Energy Cosmopolitan Project H16 -A-1 0-401 Fishbone Sidetrack APD 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 already 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 fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Drilling will be done with a drilling fluid having the following properties over the listed Production interval in the following Table. It is planned to drill the H16A production section using a solids free oil based mud system with no barite and only a small amount of calcium carbonate used unless losses dictate the addition of bridging material, and coupled with an RCD and MPD (Rotating Circulating Device or Rotating Head and Managed Pressure Drilling) to minimize near wellbore formation damage in the reservoir section. Since the well design does not allow for any type of well stimulation or acid clean up after completion, it is vital for well productivity to drill the reservoir using MPD with as light a mud weight as possible, and with as few solids as possible. Parameter Surface Intermediate Production TypeA OBM — Low Solids Name ACTIMUL Reservoir Drill -In Density (ppg) 8.8-9.0_ • Oil:Water Ratio 70:30 6/3 RPM 8-12 PV (lbs/100ft) <28 API Fluid Loss (cc/30min) HTHP Fluid Loss (cc/30min) <5.0 Electric Stability (mlVolts) >300 pH Chlorides 75-80,000 ppm 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 stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test 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 on exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 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 an item already on file with the commission and identified in the application: (11) for a well drilled from 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); Not applicable: Application is not for an offshore well. 9 1 P a g e H16 -A10-401 Fishbone Sidetrack APD Ilue est Energy Cosmopolitan Project H16 -A-1 0-401 Fishbone Sidetrack APD 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 the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 (Bonding)have been met, Evidence of bonding for BlueCrest Alaska Operating LLC is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10- 403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; (13) a copy of the proposed drilling program; Please refer to Attachment 1— Drilling Procedure. Note: The H16A Fishbone Sidetrack well will NOT be hydraulically stimulated. 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 must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Solid and liquid wastes generated during the drilling process will be disposed of at Hilcorp Alaska, LLC's Kenai Gas Field (KFG) Grind & Injection (G&I) Facility or AIMM Technologies' (hydrokinetics) facility in Kenai. No annular disposal is planned for this well. 15. Attachments for H16A Attachment 1 Drilling Procedure with Wellbore Schematics Attachment 2 Directional Plan Attachment 3 Casing Design and Cement Volume Calculations — no cement to be used; see H16 APD for casing design Attachment 4 Formation Integrity And Leak Off Test Procedure Attachment 5 BOP & Choke Manifold Configuration Attachment 6 Wellhead & Tree Configuration Attachment 7 Diverter Schematics — N/A; well will be sidetracked out of 9-5/8" casing using BOP stack Attachment 8 Lease Map 101Page H16 -A10-401 Fisliborie Sidetrack APD I rNe�st lue Energy Attachment Cosmopolitan Project H16 -A10-401 Fishbone Sidetrack APD Attachments H16 -A10-401 Fishbone Sidetrack APD Attachments BlueCrest Energy H16A SIDETRACK MAINBORE FISHBONE LOWER LATERAL Drilling and Completion Well Plan for APD Package Tom McKay Tom.mckay@BlueCrestEnergy.com r��rr L71 C Err r General Procedure Pre -Rig Operations Cosmopolitan Project H16A APD Well Plan 1. Post Well Sign for H16A on rig in normal location. 2. Post approved APD for H16A as standard procedure. NOTE: H16A will have seven (7) laterals, each with its own APD and API Number, and all APD's must be available in Drilling Supervisor's office, and in the Rig Dog House. 3. Shut in H16 well prior to rig arrival to allow reservoir to re -charge after the flowback-production phase. This is necessary to minimize fluid losses to the reservoir during the de -completion phase. 4. Rig up on wing valve to pump 8.5 ppg (3% KCI) brine down annulus to reverse out lift gas and reservoir gas from the annulus and tubing. This may take numerous circulations. Use mud pumps and mud pits to build and circulate the brine. Monitor and record any losses observed. 5. Rig up slickline, and install dummy valves in top two (2) GLM's to force brine down through lowest GLM. Rig down slick line. 6. Continue to reverse out gas and prepare well for de -completion. 7. Set BPV. 8. Remove flow line. 9. Remove Xmas Tree. MIRU Operations 10. Skid BlueCrest Rig No. 1 over H16 well slot. 11. Flange looking up is 13-5/8" 5K standard API flange. 12. Lower BOP stack and make up BOP flange to wellhead. 13. Test this connection to 3500 psi, and record results. 14. Connect 10K choke and kill lines, and return line above BOP. 15. Install RCD with element for 5-1/2" drill pipe. 16. Rig up surface MPD equipment. 17. Notify AOGCC of BOP test 48 hours in advance. , `y 18. Set test plug. 19. Pressure test BOPE and choke manifold to 3500 psi, and record results. 20. Hold BOP closing and rig abandonment drill, and record same on IADC Drilling Report. 21. Remove test plug. O1Page H16A APD Wel! Plan Ilue test Energy De -Completion Operation 22. Remove BPV. Cosmopolitan Project 1-116A APD Well Plan 23. Reverse circulate well with 8.5 ppg (3% KCI) completion brine. Circulate until well is de -gassed. 24. Make up GE Vetco 4-1/2" tubing hanger running tool. 25. Remove 4-1/2" tubing hanger packoff. 26. Engage 4-1/2" tubing hanger and back out same. 27. Pull 3-1/2" production tubing seal stack out of seal bore. 28. Circulate well with 8.5 ppg completion brine to once again circulate out any gas left in the well. 29. POOH and lay down 3-1/2" tubing string and jewelry. 30. Send 3-1/2" tubing joint to shop for refurbishment and re -use. Isolate H16 Lower Lateral 31. Make up Halco EZSV Bridge Plug with mechanical setting tool for 9-5/8" 53.5# casing on 5-1/2" 21.9# X54 drill pipe. 32. RIH with EZSV Bridge Plug on 5-1/2" drill pipe. 33. Set EZSV Bridge Plug in shoe track at specified MD for accommodating whipstock and subsequent sidetrack, and to isolate existing lower lateral on H16 well. 34. Shear and release from Bridge Plug and set down 20,000 lbs to confirm EZSV is set. 35. Pull one stand above EZSV. 36. Pressure test casing to 3500 psi, chart record and report results. 37. POOH with drill string. 38. Report setting depth of EZSV so that whipstock and window to be milled can be planned accordingly. 1�Page Plan lue St Energy Install Whipstock and Mill Window Cosmopolitan Project 1116A APD Well Plan 39. Make up whipstock assembly with MWD and window milling equipment and anchor assembly. 40. RIH with whipstock assembly on 5-1/2" drill pipe. p 10� 41. Install RCD element and initiate MPD after BHA is below wellhead. 42. Once at setting depth, tag EZSV to correlate and confirm window depth. 43. Using MWD, orient whipstock 30 deg right if high side, drop ball, pump down same, and land fi ball. � 44. Pressure up to XXXX psi and hydraulically set whipstock at desired orientation. 45. Shear lug to free milling BHA from the slide on the whipstock. 46. Establish parameters and initiate milling of casing window. 47. Mill window to clear the 9-5/8" casing. 48. POOH to inside 9-5/8" casing, and circulate well clean with same mud weight all around. 49. Shut in around drill pipe and perform FIT to 13.0 ppg EMW. Record FIT results and lot on sam fraph with previous casing pressure test. Report results to office and to AOGCC. 50. Finish milling and dressing window as per service company procedures. 51. Confirm window is fully open and clear of any obstructions. 52. POOH with window milling BHA. 53. Remove RCD element to recover BHA. 54. Lay down window milling BHA and report wear condition on mills. k 'f'-V6 2 1 P a g e H16A APD Well Plan IlueCest Energy Cosmopolitan Project 1116A APD Well Plan Drilling Main Bore and Laterals (8 total laterals planned - 8-1/2" Production Section) P (NOTE: This one page of the Drilling Procedure is included in each of the APD Packages for Laterals L01 -L07, under Attachment 1, Drilling Procedure.) 55. Make up 8-1/2" PDC bit on RSS BHA and RIH. 56. Install RCD element for MPD after drilling BHA is below wellhead. 57. NOTE: The use of MPD on this operation is under evaluation internally at BlueCrest; but MPD is included in this APD Base Case Drilling Procedure. 58. RIH with drilling BHA on 5-1/2" drill pipe (combination of HT -55 and XT -54 drill pipe). 59. Enter window in 9-5/8" casing and correlate tally depths. 60. Exit window slowly with BHA and tag bottom. 61. Establish parameters and drill ahead using an 8.8-9.0 ppg low solids, barite free drilling fluid, as per directional plan to first sidetrack point for H 16A -L01. 62. Directionally drill well to 1-01 target and drill L01 lateral to L01 TD as called by Geologists. 63. Circulate and backream the 1-01 lateral back to the main bore. 64. Run back in to TD of the main bore. 65. Displace the 1-01 lateral with LVT. 66. Strip out using MPD without backreaming if possible to the main bore. 67. Initiate trenching and time drilling to execute an open hole sidetrack away from 1-01 and to the kickoff point for the L02 lateral. 68. Directionally drill the L02 lateral using the same procedure as L01. 69. Repeat these steps for drilling laterals 2 through 8 in H16A. 70. After drilling and displacing Lateral 8 with LVT, pull back to mainbore. 71. Backream and displace main bore to LVT is 1000' stages. 72. Continue backreaming and displacing to LVT until inside the 9-5/8" casing above the window. 73. Spot high viscosity pill and cap well to surface with a 9.7 ppg low solids mud without barite. 74. Backream / strip out to the BHA using MPD. 75. Remove the RCD element, and pull out with the BHA. 76. Lay down same and report wear patterns to office on all BHA components. 77. NOTE: BHA and drill pipe wear, along with the 14 -day AOGCC BOP test requirement, will determine how many laterals can be drilled on each bit run. 78. An RTTS packer for 9-5/8" casing is available on standby in the event a BOP test is conducted with the drill string hung off below the wellhead using the RTTS. 31Page H1.6A APD Well Plan lIueCest Cosmopolitan Project Energy N16A APD Well Plan Run 4-1/2" Slotted Liner Lower Completion 79. Test BOPE and choke manifold; notify AOGCC 48 hours in advance of test. 80. Rig up casing crew and run 4-1/2" slotted liner with Volant Hydroform rigid blade centralizers crimped on the liner joints. 81. Run the slotted liner with liner hanger and liner top packer, equipped with FIV (Schlumberger formation isolation valve) at the top of the liner. 82. Once liner top packer is below wellhead, install RCD element and run liner in on 5-1/2" drill pipe. 83. Exit window in 9-5/8" casing and run liner using rotation as needed, to the final TD of the well in Los. 84. With liner at setting depth, drop ball, and pump down same. 85. Land setting ball, pressure up, and set liner hanger per service company procedures. 86. Slack off to ensure liner hanger is set. 87. Release from hanger, and set down weight to set liner top packer. 88. Pressure test liner top packer and drill pipe annulus to 2500 psi; chart and report pressure test results. 89. Pull out of liner hanger which will close the FIV, isolating the liner and open hole from the 9-5/8" casing. 90. POOH with liner running tools. Clean Out Run & Brine Displacement 91. P/U clean out BHA and TIH on 5-1/2" DP to 30" above the top of 7.625" tie -back extension. 92. Obtain pick-up and slack -off weights before entering the tie -back extension. 93. Establish a circulation rate of +/- 1 BPM and slowly run in the hole while rotating at +/- 30 RPMs. 94. Observe pressure increase when the BHA enters the 5.75" ID, 23' seal bore located directly below the liner hanger. Mark the drill pipe. 95. Shut down the pumps and proceed to clean the seal bore and FIV area while rotating at +/-30 RPM until the BHA No Go is at the lower crossover. 96. Pull up out of the PBR to 5' above the tie -back extension and proceed to circulate the 9.7 ppg OBM in the casing with 9.0 ppg KCI/NaCl brine as per the fluid displacement procedure. 97. Flow check the well. 98. POOH managing drill pipe as required. 99. Lay down clean out assembly and prepare to run upper completion Run 3-1/2" Upper Completion / Remove BOP / Set Xmas Tree 100. Tally and Drift 3-1/2" 9.3# L80 IBT-MOD tubing string in pipe shed. Drift to 2.867". 101. Pull wear bushing and wash tubing hanger setting and sealing area as required. 102. Make dummy run with tubing hanger. 103. PU 15' 3-1/2" Seal Stack and FIV shifting tool and associated equipment. 4 1 P a g e H16A APD Well Plan /1u ts[ Energy Cosmopolitan Project H16A APD Well Pian 104. PU and RIH with production tubing string. 105. Keep hole full of 9.0 ppg kill weight brine. 106. Use Best of Life 2000 NM as per TSA recommendations. 107. Include three (3) gas lift mandrels, one (1) SSSV, one (1) set of real time readout downhole temperature and pressure gauges, and one (1) downhole chemical injection mandrel with control lines and clamps as per running tally. 108. RIH to 100' above packer setting depth as per tally and slow running speed. 109. Run cables and lines through penetrations in tubing hanger. 110. RIH to liner top packer. 111. Enter seal bore above liner top packer with seal stack. 112. Entering seal bore will re -open the FIV and re-establish communication between the tubing and the reservoir. 113. Slack off weight per tubing movement calculation to be provided. 114. Measure for space out and pick up as required to lay down top joint. 115. Pup up as required 1 joint below tubing hanger point. 116. MU tubing hanger. Land tubing hanger. 117. Test tubing hanger packoff to 5000 psi for 10 minutes. 118. Test tubing against PX plug and tubing by casing annulus. f" Z 3'a3 D 119. Install TWC (two way check valve) and observe well for flow. 14 a4r-k 120. Connect control line for SSSV to surface system. 121. Connect line for downhole chemical injection. 122. Connect 1 -wire for downhole pressure and temperature data transmission. 123. Drain BOP stack. Nipple down riser, RCD, and rig BOP Stack and place on stump. 124. Nipple up 4-1/2" 5K production tree and pressure test same to 5,000 psi. 125. Pull TWC. 126. Rig up slickline and pull PX plug in tubing. 127. Function test SSSV. 128. Close SSSV, pressure up and shear out downhole valve set in GLM, and pressure test SSSV from below as per AOGCC regulations. Report results to AOGCC and notify AOGCC to witness test 48 hours in advance. 129. Using slickline, replace dummy valves in GLM's with gas lift valves. 130. Function test SSV and SSSV with AOGCC witnessing. Place Well on Flowback and Production 131. Complete handover form and turn well operation over to the Production Operators. 132. Open wing valve and route production to plant. 133. Observe and record flow rate data using gas lift operation to observe assisted flow back. 134. Produce and flow back well as directed using gas lift. S1Page H16A APD Well Plan /1uee)erst Energy Well Plan Summary Rig BlueCrest Rig #1 Well Type Multilateral Fishbone Design Producer Well Design 13-3/8" Surface x 9-5/8" Intermediate x 4-1/2" Slotted Liner Lower 4-1/2" 12.6# H563 P110 Slotted Liner Lateral Completion Upper N/A Design Lateral Tubing 3-1/2" 9.3# L80 113T -MOD Production Tubing String String AFE H 16A -DC PTD Lower Lateral TBA by AOGCC API # TBA by AOGCC PTD Upper Lateral Will be issued later under a subsequent APD API # Will be issued later under a subsequent APD Proposed Whipstock Depths in 9-5/8" Casing for H16A: MD Inc Top 14349.00 82.40 Whipstock Base Ws 14362.00 84.35 Azimuth TVD -SS 299.43 6886.29 300.14 6887.79 Cosmopolitan Project 1116A LAPD Well Plan TVD 7066.72 7068.22 6 1 P a g e H16A APD Well Plan /lue erst Energy Cosmopolitan Project H16A_ APD Well Plan General Signage and Documentation 1. Ensure that all well signage is on location and displayed properly. R Well Sign 2. Ensure the following documents are stored TOGETHER in the company man's office: Application for Permit to Drill (APD 10-401) -> Display in Dog House as well; include H16A mainbore APD plus seven (7) rib lateral APD's Onshore ODPCP SPCC Plan Air Permit FAA obstruction determination Lease Operations Plan LO/CI 14-007 7 1 P a g e H16A APD Well Plan Last Updated: TWM, 11 July 2018 —187' MD/TVD Bit: N/A RSS: N/A MWD: N/A LWD: N/A 4,177' M D/3,175' TV D Bit: N/A RSS: N/A MWD: N/A LWD: N/A Base of window depth in 9-5/8" casing: 14,362' MD/ 7,068' TVD (Lower Lat) Bit: 8-1/2" PDC RSS: Xceed675 MWD: Telescope LWD: GeoSphere adnVISION 22,829' MD/ 6,880' TVD Total Depth Driven 17-1/2" Open Hole 12-1/4" Open Hole H 16-A Fishbone Production Well (Main Bore / Lower Lateral / Starichkof / Hemlock Primary Target) Well will be sidetracked through window in 9-5/8" casing 20" 0.500" Wall A252 ERW 13-3/8" 72# L80 BTC 3-1/2" Production Tubing to Surface GLM's / SSSV / DH Gauges / CIM 9-5/8" 47# P110 H563 (13,161') ------------------- Liner Hgr & Liner Top Packer 9-5/8" 53.5# P110 H563 (14,767') I I I 1 I 1 I I 8-1/2" Open Hole I 1 I I I I 4-1/2" 12.6# P110 H563 Slotted Liner Un -Cemented Slotted Liner Completion in Mainbore Cement ACTUAL PUMPED 12.0 ppg Lead 588 bbls 15.8 ppg Class G Tail 198 bbls ACTUAL PUMPED 15.8 ppg Class G 178 bbls Un -cemented Slotted Liner No Frac's Mud / Deviation I ncl 73 deg Azim 304 deg Incl 78 deg Azim 303 deg OBM 8.8-9.0 ppg VersaPro with MPD Max Incl 107 deg Azim 303 deg tPP (PP H16A Lower Lateral Completion with .Z°"Co^d°ct°r Slotted Liner in Main bore and Seven @ 187' BGL (7) Open Hole Fishbone Ribs 13-3/8" 72# 1.80 BTC a@ 4177' M D 3-%" 9.3# IBT-MOD Production Tubing 4 -Wil x 9-5/811 Liner Hanger & Liner Top Packer NOTE: WeH will be ' sidetracked off a whipstock set at approx 14,350' MD in the 9-518" casing Now 9-5/8" 47.0/53.5# P110 H563 @ T. McKay, Muly2018 14767' MD AllueClPest Ene%gy Fishbone ribs are 8-%" open holes spaced approx every 800' with 4-%" slotted liner run in the mainbore after the seven ribs are drilled; ribs are drilled in order from 1.01 to L07 using open hole sidetracks to initiate each rib; ribs penetrate all layers of Starichkof and Hemlock pay sands 1.01 L02 L03 Boa jos X06 L07 Of 4-%" 17# H521 Slotted Liner @ 1* 22829' MD s H16A Fishbone Design WLIU U ul L;fj %'j f -3430 qp u e est Energy Directional Plan Cosmopolitan Project H16 -A_10-401 Fishbone Sidetrack APD Atta&irri ents H16 -A10-401 Fishbone Sidetrack APD Attachments H16A -Table of Coordinates for Mainbore and Laterals L01 through L07 H16A I I Top of Productive Horizon Distance to Nearest Property Line MD x y Leg, I Main Wellbore 14632 158778.19 2150581.45 2572"FSLp 1182' FEL, Sec. 33., T3S, R15W SM L01 16382 157163-69 2151793-49 1950" FSL, 2933' FEL, Sec- 29, T3S, R15W SM L02 17180 156506.56 2152245-94 4173' FSI-, 3498' EEL., Sec. 33,, T3S, R15W SM L03 17980 155847-77 2152699-77 4608' ESL, 41681 FEL,, Sec. 33, T3S., RIS W SM L04 18780 155189.00 2153153.63 5044' FSL, 4839' FEL,, Sec, 33, T3S., R15W SM L05 19580 154530.21 2153607-47 196' ESL, 228' FEL., Sec. 29, T3S, R15W SM L06 20382 -F—'153272-06 153869-79 2154062-46 633' ESL: 9011 FEL,. Sec. 29,, T3S,, R15W SM L07 21107 2154473.31 1026' FSL, 1509' FEL., Sec. 29, T3S, R15W SM H16A I I Total Depth Distance to Nearest Property Line MD x y Legal Main Wellbore 22829 151874.00 2155437.00 1950' FSL, 2333' FEL, Sec. 29,, T3S, R15W SM L01 17722 156120.00 2152512.00 44284 FSL. 3891' FEL, Sec. 33, T3S, R15W Sm 102 L03 18730 19590 155305-00 154601.00 2153074.00 2153558-00 4967' FSL, 4721' FEL,, Sec. 33, T3S,, R15W SM 149' FSL, 156' FEL, Sec. 29, T3S, R15W SM 104 L05 106 20374 21105 21745 153954-00 153347.00 152808-00 2154004.00 2154422.00 2154794-00 576'FSL, 815' FEL, Sec. 29, T3S,, R15W SM 977' FSL, 1433' FEL, Sec. 29, T3S, R15W SM 1334' FSL, 1982'FEL, Sec. 29, T3S,, R15W SM L07 22315 152320.00 2155129.00 16551 FSL, 2479' FEL, Sec. 29,, T3S, R15W SM H16A I I Distance to Nearest Property Line Main Wellbore 694 Y01665 L01 5502 Y01665 L02 4.595 Y01665 L03 3800 Y01665 L04 3066 Y01665 L05 2372 Y01665 L06 1751 Y01665 L07 1.202 Y01665 IrNep�st Energy H 16A (P2) Proposal Geodetic Report (Def Plan) 7E; Report Date: July 10, 2018 - 01:15 PM Survey / DLS Computation: Minimum Curvature / Lubinski Client: BlueCrest Vertical Section Azimuth: 300.000 ° (True North) Field: Structure / Slot: Cosmopolitan Unit Cosmopolitan Pad / H-16S���� Vertical Section Origin: 0.000 ft, 0.000 ft Well: • H16 • •I ty TVD Reference Datum: TVD Reference Elevation: Rotary Table 180.430 ft above MSL Borehole: H16A ' s� Ground Elevation: 14 5.810 ft above MSL API#: 502312005101 Magnetic Declination: 14.561 ° Survey Name: H16A (P2) Total Gravity Field Strength: 1001.2613mgn (9.80665 Based) Survey Date: July 10, 2018 Gravity Model: DOX Tort / AHD / DDI / ERD Ratio: 209.503 ° / 20048.113 ft / 7.131 / 2.827 Total Magnetic Field Strength: 55102.359 nT Coordinate Reference System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Dip Angle: 72.8800 Location Lat / Long: N 590 51'32.04341", W 1510 48' 5.01216" a Declination Date: September 30, 2018 Location Grid N/E Y/X: N 2144855.980 ftUS, E 168862.230 ftUS a Magnetic Declination Model: HDGM 2018 CRS Grid Convergence Angle: -1.5580 ° North Reference: True North Grid Scale Factor: 1.0000248 Grid Convergence Used: 0.0000 ° Version / Patch: 2.10.544.0 Total Corr Mag North ->True North: 14.56120 200.00 1.02 Local Coord Referenced To: Well Head Comments D Incl Azim True TVDSS TVD VSEC NS EW TF DLS Directional Exclusion Zone Exclusion Zone GeoMag Th Northing Easting (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (0) (0/100ft) Difficulty Index Alert Angle 0 (nT) (ftUS) (ftUS) RTE 0.00 34.62 0.00 0.00 0.00 0.00 -180.43 -145.81 0.00 34.62 0.00 0.00 0.00 0.00 0M N/A 0.00 17.12 16221.09 2144855.98 168862.23 100.00 0.43 249.54 -80.43 100.00 0.16 0.00 -0.09 0.00 -0.23 249.54M 252.78M 0.00 0.66 0.00 0.00 17.12 16221.16 2144855.98 168862.23 200.00 1.02 252.78 19.56 199.99 1.00 -0.48 -1.43 320.54M 0.59 0.19 17.37 17.68 16451.11 16733.41 2144855.90 2144855.54 168862.00 168860.79 300.00 400.00 2.42 5.40 320.54 333.89 119.52 299.95 3.58 0.89 -3.62 333.89M 2.24 1.14 15.82 15019.20 2144856.96 168858.63 500.00 7.61 323.52 219.28 318.63 399.71 499.06 9.47 19.44 6.74 16.29 -7.04 33.21 L 64.09L 3.10 1.85 13.48 12843.18 2144862.91 168855.38 600.00 9.91 303.00 417.48 597.91 34.11 26.31 -13.05 -24.20 70.58L 2.49 3.85 2.30 2.68 13.64 12997.58 2144872.62 168849.63 700.00 11.34 287.80 515.79 696.22 52.32 34.00 -40.79 104.78L 3.13 2.95 16.77 19.90 15902.54 18754.88 2144882.94 2144891.08 168838.75 168822.38 800.00 900.00 10.96 9.37 272.57 613.92 794.35 70.37 37.43 -59.65 175.14R 2.96 3.15 22.08 20719.03 2144895.02 168803.62 1000.00 10.13 273.40 294.04 712.35 810.93 892.78 991.36 86.09 102.12 38.34 42.41 -77.27 88.04R 1.60 3.28 20.98 19737.33 2144896.41 168786.03 1100.00 13.66 301.29 908.77 1089.20 122.68 52.13 -93.43 -111.56 26.52R 13.85R 3.56 3.83 3.42 3.56 18.32 17321.17 2144900.92 168769.98 1200.00 16.58 303.80 1005.30 1185.73 148.73 66.20 -133.51 40.66R 2.99 3.69 18.43 19.33 17429.13 2144911.12 168752.12 1245.17 17.30 305.85 1048.51 1228.94 161.84 73.72 -144.31 2.42L 2.07 3.74 19.22 18240.62 18145.40 2144925.79 2144933.60 168730.56 168719.97 1344.29 1435.95 19.34 21.29 305.59 301.72 1142.60 1323.03 192.84 91.91 -169.61 36.39L 2.06 3.84 20.49 19289.66 2144952.47 168695.18 1529.04 23.68 301.02 1228.56 1314.57 1408.99 1495.00 224.58 260.17 109.49 128.01 -196.11 6.72L 2.58 3.93 22.78 21338.66 2144970.77 168669.16 1623.23 25.95 300.17 1400.06 1580.49 299.70 148.12 -226.51 -260.54 9.32L 4.52L 2.58 2.44 4.02 4.11 24.67 23004.71 2144990.11 168639.28 1717.53 26.63 300.05 1484.60 1665.03 341.46 169.07 -296.67 4.41 R 0.72 4.17 26.62 27.18 24696.08 25179.63 2145011.13 2145033.06 168605.81 168570.26 1811.41 1905.43 27.53 28.66 300.20 299.14 1568.19 1651.13 1748.62 1831.56 384.20 190.52 -333.64 24.3L 0.96 4.24 27.85 25750.54 2145055.51 168533.89 1999.47 30.32 298.11 1732.99 1913.42 428.47 474.75 212.43 234.60 -372.11 -412.75 17.43L 2.37L 1.31 1.85 4.30 29.05 26769.95 2145078.46 168496.02 2093.53 32.53 297.94 1813.24 1993.67 523.76 257.64 -456.04 13.08L 2.35 4.36 4.42 30.70 32.60 28147.42 2145101.72 168456.00 2188.05 35.54 296.74 1891.56 2071.99 576.59 281.91 -503.03 5.71 L 3.26 4.49 35.53 29704.21 32038.34 2145125.93 2145151.47 168413.36 168367.04 2295.97 2376.65 37.49 39.21 296.42 297.75 1978.30 2041.57 2158.73 2222.00 640.69 310.64 -560.46 26.15R 1.82 4.56 37.33 33430.65 2145181.75 168310.41 2473.36 42.17 299.40 2114.89 2295.32 690.68 753.70 333.44 363.62 -605.02 -660.37 20.6R 2.03R 2.36 3.26 4.61 38.46 34292.42 2145205.75 168266.49 2563.47 44.14 299.50 2180.62 2361.05 815.33 393.92 -714.03 54.06L 2.19 4.68 4.73 40.63 42.38 35897.91 2145237.42 168211.98 2657.42 45.62 296.71 2247.20 2427.63 881.57 425.12 -772.51 28.6L 2.62 4.78 44.54 37159.53 38672.01 2145269.18 2145301.96 168159.15 168101.55 2751.41 2845.12 47.92 50.92 295.03 294.28 2311.57 2492.00 949.87 454.98 -834.13 11L 2.77 4.84 47.14 40414.11 2145333.48 168040.76 2938.93 53.66 293.61 2372.53 2429.90 2552.96 2610.33 1020.72 1094.51 484.66 514.77 -898.81 11.15L 27.35R 3.26 4.89 50.13 42314.25 2145364.91 167976.91 3032.97 56.06 295.10 2484.03 2664.46 1171.03 546.49 -966.63 -1036.67 16.64R 2.97 2.86 4.94 4.99 52.87 43956.83 2145396.85 167909.93 3126.72 59.20 296.19 2534.21 2714.64 1249.97 580.77 -1108.04 29.04R 3.49 5.05 54.67 57.29 44982.15 46394.61 2145430.47 2145466.67 167840.77 167770.37 3220.63 3315.21 61.70 63.38 297.76 298.93 2580.53 2624.14 2760.96 2804.57 1331.55 1415.43 617.83 -1180.83 31.99R 3.03 5.09 59.18 47353.29 2145505.70 167698.61 3408.14 64.84 299.90 2664.72 2845.15 1499.02 657.68 698.74 -1254.68 -1327.50 31.08R 155.28L 2.09 1.83 5.14 5.18 60.43 47955.21 2145547.55 167625.86 3502.96 64.04 299.49 2705.63 2886.06 1584.56 741.12 -1401.81 34.81 L 0.93 5.21 61.52 60.89 48467.96 48173.35 2145590.57 2145634.96 167554.18 167481.06 3596.88 3690.73 64.56 64.59 299.09 298.04 2746.36 2786.65 2926.79 2967.08 1669.19 782.52 -1475.62 88.41 L 0.67 5.24 61.50 48456.34 2145678.35 167408.40 3784.52 65.08 296.94 2826.53 3006.96 1753.92 1838.72 823.05 862.23 -1550.06 -1625.36 64.03L 106.87L 1.01 1.18 5.27 61.83 48610.42 2145720.89 167335.08 3878.56 64.70 295.53 2866.44 3046.87 1923.69 899.87 -1701.74 132.96R 1.42 5.30 5.34 62.62 62.67 48963.64 48988.45 2145762.10 2145801.81 167260.87 3972.32 64.14 296.20 2906.93 3087.36 2008.04 936.77 -1777.84 69.72R 0.88 5.36 61.95 48664.25 2145840.76 167185.55 167110.48 4066.25 4126.07 64.20 64.99 296.38 295.88 2947.85 2973.51 3128.28 3153.94 2092.40 974.21 -1853.64 29.86L 0.18 5.39 61.95 48666.61 2145880.25 167035.72 13-3/8" 4175.00 65.51 296.63 2994.00 3174.43 2146.32 2190.66 998.01 1017.67 -1902.15 -1942.00 52.97R 52.65R 1.52 1.76 5.40 62.85 49065.63 2145905.36 166987.87 4215.19 65.94 297.25 3010.52 3190.95 2227.24 1034.27 -1974.66 68.98L 1.76 5.42 5.43 63.12 49184.22 2145926.09 166948.57 4261.46 66.12 296.74 3029.32 3209.75 2269.46 1053.46 -2012.33 80.2R 1.08 5.44 63.34 49282.70 2145943.58 166916.37 4355.34 66.26 297.61 3067.22 3247.65 2355.25 1092.68 -2088.74 42.5L 0.86 5.47 63.66 63.54 49420.44 49368.64 2145963.79 2146005.08 166879.24 166803.92 4448.62 4542.43 66.36 66.07 297.51 296.67 3104.70 3142.53 3285.13 3322.96 2440.59 2526.32 1132.21 -2164.47 110.84L 0.15 5.49 63.66 49422.32 2146046.64 166729.30 4636.41 65.95 296.88 3180.74 3361.17 2612.04 1171.30 1209.98 -2240.89 -2317.55 122.07R 39.07R 0.88 0.24 5.51 63.64 49410.80 2146087.80 166653.96 5.53 63.46 49336.28 2146128.55 166578.38 Drilling Office 2.10.302.0 Cosmopolitan Unit\Cosmoplitan Pad\H14\H14\H14 (P5) 7/17/2018 1:51 PM Page 1 of 4 IVI Comments D Incl Azim True TVDSS TVD VSEC N EW TF DLS Directional Exclusion Zone Exclusion ZoneS GeoMag Th Northing Easting (ft) (0) (0) (ft) (ft) (ftj (ft) (ft) (0) (°/100ft) Difficulty Index Alert Angle (nT) (ftUS) (ftUS) 4730.27 66.30 297.19 3218.73 3399.16 2697.76 1248.99 -2394.00 114.71R 0.48 5.55 63.70 49439.92 2146169.63 166503.02 4824.24 65.97 297.98 3256.75 3437.18 2783.62 1288.78 -2470.16 73.59R 0.85 5.57 63.16 49206.29 2146211.48 166427.96 4918.12 5012.21 66.24 66.06 298.97 3294.78 3475.21 2869.42 1329.71 -2545.61 153.08L 1.01 5.59 63.12 49192.17 2146254.44 166353.65 5106.29 66.64 298.87 299.19 3332.82 3370.56 3513.25 2955.46 1371.32 -2620.94 26.88R 0.21 5.61 62.98 49131.14 2146298.09 166279.49 5200.16 65.82 299.27 3408.40 3550.99 3588.83 3041.62 3127.52 1413.14 1455.09 -2696.29 174.91 R 0.69 5.63 63.44 49329.65 2146341.94 166205.30 5294.78 66.18 299.72 3446.89 3627.32 3213.96 1497.65 -2771.25 -2846.49 48.88R 178.66R 0.88 0.58 5.65 5.67 62.64 48980.94 2146385.91 166131.50 5388.11 65.79 299.73 3484.87 3665.30 3299.21 1539.92 -2920.52 62.94R 0.42 5.68 62.85 49074.00 2146430.50 166057.45 5481.22 65.86 299.88 3523.00 3703.43 3384.15 1582.14 -2994.23 62.14L 0.17 5.70 62.48 48909.97 2146474.77 165984.59 5575.27 66.01 299.57 3561.35 3741.78 3470.03 1624.72 -3068.81 8AL 0.34 5.71 62.50 48920.60 2146518.98 165912.05 5669.31 66.32 299.52 3599.35 3779.78 3556.04 1667.14 -3143.64 22.84L 0.33 5.73 62.73 49024.21 2146563.57 165838.66 5763.64 66.91 299.25 3636.79 3817.22 3642.62 1709.62 -3219.08 176.78R 0.68 5.74 63.04 49160.11 2146608.01 165765.01 5857.68 66.26 299.29 3674.16 3854.59 3728.91 1751.81 -3294.36 84.56R 0.69 5.76 63.68 49436.17 2146652.53 165690.75 5951.68 66.29 299.63 3711.98 3892.41 3814.96 1794.14 -3369.29 81.81 L 0.33 5.77 63.05 49165.82 2146696.75 165616.64 6045.71 66.35 299.18 3749.75 3930.18 3901.07 1836.42 -3444.31 10.43R 0.44 5.79 62.98 49135.49 2146741.10 165542.89 6139.68 66.95 299.30 3786.99 3967.42 3987.33 1878.56 -3519.59 2.78L 0.65 5.80 63.17 49218.17 2146785.41 165469.05 6233.54 67.33 299.28 3823.46 4003.89 4073.81 1920.87 -3595.02 121.31 R 0.41 5.81 63.70 49448.56 2146829.58 165394.94 6327.35 67.19 299.53 3859.72 4040.15 4160.33 1963.35 -3670.39 5.15L 0.29 5.83 64.07 63.87 49604.35 2146873.93 165320.68 6421.36 67.60 299.49 3895.85 4076.28 4247.11 2006.10 -3745.92 3.62L 0.44 5.84 64.27 49518.02 2146918.44 165246.49 6515.36 68.04 299.46 3931.34 4111.77 4334.15 2048.93 -3821.70 80.48L 0.47 5.85 64.69 49687.31 49864.74 2146963.23 2147008.10 165172.15 165097.56 6609.25 68.21 298.39 3966.32 4146.75 4421.26 2091.07 -3897.96 169.93L 1.07 5.87 65.17 50058.55 2147052.30 165022.48 6703.22 67.43 298.24 4001.80 4182.23 4508.24 2132.34 -3974.56 141.13R 0.84 5.88 64.47 49773.93 2147095.65 164947.02 6796.49 67.19 298.45 4037.78 4218.21 4594.26 2173.20 -4050.30 13.84L 0.33 5.89 64.18 49653.96 2147138.55 164872.42 6890.96 67.49 298.37 4074.17 4254.60 4681.40 2214.67 -4126.98 30.03L 0.33 5.91 64.49 49782.96 2147182.09 164796.90 6985.37 67.65 298.27 4110.19 4290.62 4768.63 2256.07 -4203.80 165.57R 0.20 5.92 64.67 49858.36 2147225.57 164721.23 7077.92 67.22 298.39 4145.71 4326.14 4854.06 2296.63 -4279.03 32.2R 0.48 5.93 64.23 49675.01 2147268.15 164647.13 7171.15 7265.15 67.44 67.94 298.54 4181.64 4362.07 4940.06 2337.63 -4354.65 31.47L 0.28 5.94 64.39 49744.39 2147311.20 164572.64 7359.12 67.57 298.21 297.73 4217.33 4252.90 4397.76 4433.33 5026.98 5113.91 2378.96 -4431.17 129.88L 0.62 5.95 64.96 49980.03 2147354.59 164497.28 7452.91 67.45 297.57 4288.78 4469.21 5200.49 2419.75 2459.97 -4507.98 -4584.75 129.1 L 147.75L 0.62 0.20 5.96 64.75 49894.45 2147397.46 164421.60 7546.90 67.26 297.44 4324.96 4505.39 5287.15 2500.03 -4661.68 58.16R 0.24 5.97 5.98 64.69 49867.49 2147439.75 164345.96 7640.93 67.49 297.84 4361.14 4541.57 5373.87 2540.29 -4738.57 103.98R 0.46 5.99 64.55 49809.42 2147481.89 164270.14 7734.97 67.36 298.41 4397.24 4577.67 5460.66 2581.23 -4815.15 83.87L 0.58 6.01 64.65 49851.76 2147524.23 164194.37 7828.89 67.39 298.11 4433.37 4613.80 5547.31 2622.27 -4891.51 100.28R 0.30 6.02 64.36 49732.16 2147567.23 164118.93 7923.05 67.35 298.35 4469.60 4650.03 5634.18 2663.38 -4968.09 28.05L 0.24 6.02 64.47 49781.05 2147610.34 164043.71 8016.82 67.68 298.16 4505.46 4685.89 5720.78 2704.40 -5044.40 136.62R 0.40 6.03 64.37 64.73 49736.71 2147653.52 163968.28 8110.77 67.29 298.56 4541.44 4721.87 5807.53 2745.62 -5120.78 80.21 R 0.57 6.04 49889.80 2147696.59 163893.11 8204.72 67.33 298.81 4577.68 4758.11 5894.19 2787.23 -5196.82 160.92R 0.25 6.05 64.25 49688.51 2147739.88 163817.88 8298.81 67.25 298.84 4614.00 4794.43 5980.97 2829.08 -5272.86 55.89R 0.09 6.06 64.21 49674.42 2147783.54 163743.00 8392.75 67.30 298.92 4650.29 4830.72 6067.60 2870.92 -5348.73 97.79L 0.09 6.07 64.13 49639.50 2147827.44 163668.12 8485.73 67.25 298.52 4686.21 4866.64 6153.34 2912.14 -5423.94 21.04R 0.40 6.08 64.15 49650.21 2147871.33 163593.41 8579.73 67.37 298.57 4722.47 4902.90 6240.04 2953.58 -5500.12 121.13L 0.14 6.09 64.22 49679.89 2147914.58 163519.35 8673.65 67.17 298.21 4758.76 4939.19 6326.63 2994.77 -5576.33 78.59L 0.41 6.10 64.32 49721.96 2147958.07 163444.32 8767.68 67.30 297.52 4795.15 4975.58 6413.27 3035.29 -5652.98 143.62L 0.69 6.11 64.24 49687.24 2148001.32 163369.26 8861.49 67.10 297.36 4831.50 5011.93 6499.66 3075.14 -5729.73 42.65L 0.26 6.11 64.56 49823.10 2148043.91 163293.73 8955.37 67.11 297.35 4868.03 5048.46 6586.06 3114.88 -5806.55 28.3R 0.01 6.12 64.42 49764.47 2148085.84 163218.09 9049.33 67.35 297.49 4904.39 5084.82 6672.61 3154.78 -5883.45 5.03L 0.29 6.13 64.43 49770.22 2148127.65 163142.39 9143.34 67.56 297.47 4940.43 5120.86 6759.35 3194.84 -5960.48 138.32R 0.22 6.14 64.62 49848.10 2148169.63 163066.60 9237.33 66.90 298.11 4976.81 5157.24 6845.95 3235.25 -6037.15 53.22L 0.94 6.15 64.83 49932.99 2148211.77 162990.68 9331.31 67.10 297.82 5013.53 5193.96 6932.40 3275.81 -6113.55 8.58L 0.35 6.16 64.01 49595.49 2148254.25 162915.14 9425.28 67.59 297.74 5049.73 5230.16 7019.05 3316.23 -6190.28 137.26R 0.53 6.16 64.29 49711.32 2148296.88 162839.86 9519.11 67.55 297.78 5085.53 5265.96 7105.72 3356.63 -6267.03 159.99R 0.06 6.17 64.78 64.73 49914.05 2148339.37 162764.26 9612.97 67.12 297.95 5121.70 5302.13 7192.27 3397.11 -6343.60 105.19R 0.49 6.18 49894.24 2148381.84 162688.64 9706.86 67.11 297.99 5158.21 5338.64 7278.72 3437.68 -6419.99 96.46R 0.04 6.19 64.27 49705.12 2148424.39 162613.20 9800.82 67.08 298.28 5194.78 5375.21 7365.22 3478.49 -6496.32 52.22R 0.29 6.19 64.25 49696.85 2148467.02 162537.93 9894.71 67.13 298.35 5231.31 5411.74 7451.68 3519.52 -6572.46 56.36R 0.09 6.20 64.13 49649.97 2148509.89 162462.74 9988.47 67.37 298.74 5267.57 5448.00 7538.12 3560.84 -6648.42 171.27R 0.46 6.21 64.16 49661.88 2148552.97 162387.74 10082.41 67.13 298.78 5303.89 5484.32 7624.73 3602.52 -6724.36 25.39L 0.26 6.22 64.28 49710.11 2148596.34 162312.93 10176.37 67.50 298.59 5340.13 5520.56 7711.39 3644.13 -6800.41 176.32L 0.44 6.22 64.04 49610.23 2148640.07 162238.15 10270.36 67.07 298.56 5376.42 5556.85 7798.07 3685.60 -6876.55 53.49L 0.46 6.23 64.44 49780.94 2148683.74 162163.26 10364.43 67.33 298.18 5412.88 5593.31 7884.75 3726.80 -6952.86 101.09L 0.46 6.24 64.04 49614.50 2148727.26 162088.27 10458.36 67.26 297.79 5449.13 5629.56 7971.35 3767.46 -7029.37 39.72R 0.39 6.25 64.40 49764.87 2148770.53 162013.11 10552.44 67.36 297.88 5485.42 5665.85 8058.09 3807.99 -7106.13 125.38R 0.14 6.25 64.45 49785.25 2148813.26 161937.73 10646.46 67.19 298.14 5521.75 5702.18 8144.75 3848.72 -7182.69 HS 0.31 6.26 64.52 49814.27 2148855.86 161862.10 10740.38 67.43 298.14 5557.97 5738.40 8231.36 3889.59 -7259.10 90.89L 0.26 6.26 64.28 49716.13 2148898.65 161786.67 10834.41 67.42 297.28 5594.07 5774.50 8318.11 3929.96 -7335.97 150.1 R 0.84 6.27 64.51 49811.46 2148941.58 161711.40 10928.39 67.02 297.53 5630.46 5810.89 8404.67 3969.84 -7412.89 21.31 L 0.49 6.28 64.75 49911.92 2148984.03 161635.66 11022.43 67.47 297.34 5666.83 5847.26 8491.31 4009.80 -7489.86 145.61R 0.51 6.29 64.30 49725.07 2149025.99 161559.84 11116.30 67.04 297.66 5703.13 5883.56 8577.80 4049.77 -7566.65 32.86R 0.56 6.29 64.78 49925.35 2149068.03 161483.99 11210.29 67.57 298.03 5739.39 5919.82 8664.45 4090.27 -7643.32 164.65L 0.67 6.30 64.28 49718.27 2149110.07 161408.31 11304.20 67.00 297.86 5775.65 5956.08 8751.02 4130.87 -7719.85 91.5R 0.63 6.31 64.68 49882.57 2149152.64 161332.77 11398.15 66.99 298.30 5812.37 5992.80 8837.45 4171.57 -7796.15 3.89R 0.43 6.32 64.19 49679.07 2149195.31 161257.37 11492.14 67.67 298.35 5848.60 6029.03 8924.14 4212.72 -7872.49 159.75L 0.73 6.32 64.05 49621.60 2149238.07 161182.21 11585.95 67.32 298.21 5884.50 6064.93 9010.76 4253.78 -7948.81 148.46L 0.40 6.33 64.68 49884.90 2149281.28 161107.01 11679.75 67.05 298.03 5920.88 6101.31 9097.18 4294.53 -8025.07 15.47L 0.34 6.34 64.39 49764.90 2149324.41 161031.83 11773.78 67.25 297.97 5957.39 6137.82 9183.78 4335.21 -8101.57 98.64L 0.22 6.34 64.18 49680.45 2149367.22 160956.71 11867.66 67.20 297.61 5993.73 6174.16 9270.27 4375.57 -8178.15 71.17R 0.36 6.35 64.39 64.45 49767.63 49792.27 2149409.96 2149452.39 160881.34 11961.53 67.32 297.99 6030.02 6210.45 9356.78 4415.95 -8254.73 71.59R 0.39 6.35 64.45 49793.98 2149494.83 160805.88 160730.43 12055.21 67.36 298.12 6066.11 6246.54 9443.18 4456.61 -8331.02 61.6R 0.13 6.36 64.45 49794.54 2149537.55 160655.27 12149.20 12243.19 67.45 67.40 298.30 298.67 6102.22 6138.30 6282.65 9529.91 4497.63 -8407.49 98AR 0.20 6.37 64.49 49808.74 2149580.63 160579.94 12337.04 67.00 298.26 6174.67 6318.73 6355.10 9616.67 9703.16 4539.02 4580.25 -8483.77 136.71- 0.37 6.37 64.33 49744.63 2149624.09 160504.81 12431.00 67.24 298.80 6211.20 6391.63 9789.69 4621.60 -8559.83 -8635.88 64.35R 111.02R 0.59 0.59 6.38 64.07 49636.36 2149667.38 160429.90 6.38 64.14 49666.37 2149710.78 160355.00 Drilling Office 2.10.302.0 Cosmopolitan Unit\Cosmoplitan Pad\H14\H14\H14 (P5) 7/17/2018 1:51 PM Page 2 of 4 Comments MD Incl Azim True TVDSS TVD VSEC NS EW TF DLS Directional Exclusion Zone Exclusion Zone GeoMag Th Northing Easting (°) (ft) (ft) (ft) (ft) (ft) (°) (0/100ft) Difficulty Index Alert Angle (nT) (ftUS) (ftUS) 12524.87 67.12 299.14 6247.61 6428.04 9876.20 4663.51 -8711.58 165.8R 0.36 6.39 63.93 49577.11 2149754.73 160280.47 12618.68 66.54 299.30 6284.52 6464.95 9962.44 4705.61 -8786.85 168.5L 0.64 6.40 63.33 49322.41 2149798.86 160206.37 12712.72 66.27 299.24 6322.16 6502.59 10048.61 4747.74 -8862.02 25.061- 0.29 6.40 63.09 49219.48 2149843.02 160132.36 12806.45 66.88 298.93 6359.42 6539.85 10134.60 4789.55 -8937.18 140.36L 0.72 6.41 63.76 49508.25 2149886.86 160058.37 12900.53 66.35 298.45 6396.76 6577.19 10220.93 4831.00 -9012.93 48.67L 0.73 6.42 63.40 49353.56 2149930.36 159983.77 12994.82 66.82 297.87 6434.23 6614.66 10307.41 4871.84 -9089.22 119.621- 0.75 6.42 64.02 49616.58 2149973.25 159908.63 13088.71 66.40 297.06 6471.51 6651.94 10393.50 4911.58 -9165.68 17.36L 0.91 6.43 63.86 49548.98 2150015.06 159833.27 13182.28 66.93 296.88 6508.57 6689.00 10479.30 4950.55 -9242.25 67.73R 0.59 6.44 64.41 49782.84 2150056.09 159757.79 13276.03 67.07 297.25 6545.20 6725.63 10565.48 4989.81 -9319.10 59.59R 0.39 6.44 64.44 49793.59 2150097.44 159682.03 13370.05 67.44 297.93 6581.55 6761.98 10652.11 5029.97 -9395.94 100.31- 0.77 6.45 64.59 49857.21 2150139.67 159606.30 13464.09 67.29 297.02 6617.75 6798.18 10738.82 5070.01 -9472.95 90.72L 0.91 6.45 64.71 49908.87 2150181.79 159530.41 13556.80 67.28 295.68 6653.55 6833.98 10824.17 5107.97 -9549.58 47.94R 1.33 6.46 65.10 50065.93 2150221.82 159454.84 13650.66 67.38 295.80 6689.72 6870.15 10910.53 5145.58 -9627.60 99.87L 0.16 6.47 65.16 50090.67 2150261.54 159377.88 13744.66 67.31 295.36 6725.93 6906.36 10997.02 5183.04 -9705.84 159.44L 0.44 6.47 65.22 50116.56 2150301.11 159300.68 13838.74 67.04 295.25 6762.43 6942.86 11083.45 5220.10 -9784.23 0.14R 0.31 6.48 65.00 50026.41 2150340.29 159223.32 13932.68 70.95 295.26 6796.09 6976.52 11170.83 5257.51 -9863.53 9.51 R 4.16 6.49 68.70 51431.67 2150379.85 159145.06 14026.48 75.05 295.97 6823.51 7003.94 11260.24 5296.29 -9944.40 24.85R 4.43 6.51 72.40 52617.49 2150420.81 159065.28 Jj'� 14120.47 14214.46 77.03 79.71 296.91 297.59 6846.19 6865.13 7026.62 7045.56 11351.28 11443.22 5336.90 5379.05 -10026.06 -10107.90 14.03R 40.9R 2.32 2.94 6.52 74.02 53067.32 2150463.63 158984.75 Top Whipstock Base WS 14349.00 14362.00 82.40 84.35 299.43 6886.29 7066.72 ,ate 11576.03 4 54 2.65 -10224.54 20R 2.67 6.54 6.55 76.38 78.42 53649.09 54077.89 2150507.99 2150574.73 158904.09 158789.22 300.14 6887.79 7068.22 11588.94 5449.06 -10235.74 HS 16.00 6.56 80.08 54377.49 2150581.45 1587'8.19 Cry 3/100 14382.00 84.35 300.14 6889.76 7070.19 11608.85 5459.06 -10252.95 60R 0.00 6.56 80.08 54377.54 2150591.91 158761.26 14400.00 84.62 300.61 6891.49 7071.92 11626.76 5468.12 -10268.41 59.95R 3.00 6.56 80.21 54398.14 2150601.39 158746.05 14500.00 86.13 303.22 6899.55 7079.98 11726.37 5520.81 -10353.00 59.74R 3.00 6.58 80.92 54510.14 2150656.36 158662.9: 14600.00 87.64 305.81 6904.99 7085.42 11825.90 5577.38 -10435.27 59.6R 3.00 6.59 81.65 54617.10 2150715.15 158582.22 End Cry 14632.00 88.13 306.64 6906.17 7086.60 11857.69 5596.28 -10461.07 HS 3.00 6.60 81.89 54650.07 2150734.74 158556.95 14700.00 88.13 306.64 6908.39 7088.82 11925.20 5636.84 -10515.60 HS 0.00 6.60 81.89 54650.17 2150776.77 158503.53 Cry 3/100 14732.00 88.13 306.64 6909.43 7089.86 11956.97 5655.92 -10541.27 24.11 L 0.00 6.60 81.89 54650.21 2150796.54 158478.40 14800.00 89.99 305.81 6910.55 7090.98 12024.55 5696.10 -10596.11 24.1 L 3.00 6.61 83.91 54890.81 2150838.20 158424.66 End Cry 14817.40 90.47 305.59 6910.48 7090.91 12041.86 5706.25 -10610.24 HS 3.00 6.62 84.43 54941.42 2150848.73 158410.81 14900.00 90.47 305.59 6909.80 7090.23 12124.07 5754.32 -10677.41 HS 0.00 6.62 84.43 54941.47 2150898.61 158344.98 15000.00 90.47 305.59 6908.99 7089.42 12223.59 5812.52 -10758.73 HS 0.00 6.63 84.43 54941.54 2150959.00 158265.27 15100.00 90.47 305.59 6908.17 7088.60 12323.11 5870.72 -10840.04 HS 0.00 6.64 84.43 54941.60 2151019.39 158185.57 15200.00 90.47 305.59 6907.35 7087.78 12422.63 5928.92 -10921.36 HS 0.00 6.64 84.43 54941.66 2151079.78 158105.86 15300.00 90.47 305.59 6906.54 7086.97 12522.15 5987.12 -11002.67 HS 0.00 6.65 84.43 54941.72 2151140.17 158026.16 15400.00 90.47 305.59 6905.72 7086.15 12621.67 6045.32 -11083.99 HS 0.00 6.65 84.43 54941.78 2151200.56 157946.45 15500.00 90.47 305.59 6904.90 7085.33 12721.20 6103.52 -11165.30 HS 0.00 6.66 84.43 54941.84 2151260.95 157866.75 15600.00 90.47 305.59 6904.09 7084.52 12820.72 6161.72 -11246.62 HS 0.00 6.67 84.43 54941.90 2151321.34 157787.04 15700.00 90.47 305.59 6903.27 7083.70 12920.24 6219.92 -11327.93 HS 0.00 6.67 84.43 54941.96 2151381.73 157707.34 15800.00 90.47 305.59 6902.45 7082.88 13019.76 6278.12 -11409.25 HS 0.00 6.68 84.43 54942.01 2151442.12 157627.63 15900.00 90.47 305.59 6901.64 7082.07 13119.28 6336.32 -11490.56 HS 0.00 6.69 84.43 54942.07 2151502.51 157547.93 16000.00 90.47 305.59 6900.82 7081.25 13218.80 6394.52 -11571.88 HS 0.00 6.69 84.43 54942.12 2151562.90 157468.23 16100.00 90.47 305.59 6900.00 7080.43 13318.32 6452.72 -11653.19 HS 0.00 6.70 84.43 54942.18 2151623.29 157388.52 16200.00 90.47 305.59 6899.19 7079.62 13417.84 6510.92 -11734.51 HS 0.00 6.70 84.43 54942.23 2151683.68 157308.82 16300.00 90.47 305.59 6898.37 7078.80 13517.36 6569.12 -11815.82 HS 0.00 6.71 84.43 54942.28 2151744.08 157229.11 Cry 3/100 16330.86 90.47 305.59 6898.12 7078.55 13548.08 6587.08 -11840.92 10.8L 0.00 6.71 84.43 54942.30 2151762.71 157204.51 KOP Cry 2/100 16382.00 91.97 305.30 6897.03 7077.46 13598.97 6616.73 -11882.57 LS 3.00 6.72 85.96 55065.59 2151793.49 157163.69 16400.00 91.61 305.30 6896.47 7076.90 13616.88 6627.13 -11897.25 LS 2.00 6.72 85.61 55041.10 2151804.28 157149.29 Cry 2/100 16482.00 89.97 305.30 6895.33 7075.76 13698.52 6674.51 -11964.16 83.09L 2.00 6.73 84.04 54904.16 2151853.47 157083.69 16500.00 90.02 304.95 6895.33 7075.76 13716.45 6684.87 -11978.88 83.09L 2.00 6.73 84.18 54918.06 2151864.22 157069.26 16600.00 90.26 302.96 6895.09 7075.52 13816.21 6740.72 -12061.83 83.09L 2.00 6.74 84.96 54989.57 2151922.31 156987.86 End Cry 16631.55 90.33 302.34 6894.92 7075.35 13847.72 6757.74 -12088.39 HS 2.00 6.75 85.21 55010.08 2151940.04 156961.77 16700.00 90.33 302.34 6894.53 7074.96 13916.11 6794.35 -12146.22 HS 0.00 6.75 85.21 55010.11 2151978.21 156904.95 16800.00 90.33 302.34 6893.94 7074.37 14016.03 6847.84 -12230.72 HS 0.00 6.75 85.21 55010.16 2152033.98 156821.94 16900.00 90.33 302.34 6893.36 7073.79 14115.94 6901.32 -12315.21 HS 0.00 6.76 85.21 55010.21 2152089.74 156738.93 17000.00 90.33 302.34 6892.77 7073.20 14215.86 6954.81 -12399.70 HS 0.00 6.77 85.21 55010.26 2152145.51 156655.9 17100.00 90.33 302.34 6892.19 7072.62 14315.77 7008.30 -12484.19 HS 0.00 6.77 85.21 55010.30 2152201.28 156572.92 Cry 3/100 17126.11 90.33 302.34 6892.04 7072.47 14341.86 7022.26 -12506.25 5.63R 0.00 6.77 85.21 55010.32 2152215.83 156551.25 KOP Cry 2/100 17180.00 91.94 302.49 6890.96 7071.39 14395.69 7051.14 -12551.73 LS 3.00 6.78 86.71 55112.08 2152245.94 156506.56 17200.00 91.54 302.49 6890.36 7070.79 14415.66 7061.88 -12568.59 LS 2.00 6.78 86.33 55089.63 2152257.14 156490.00 Cry 2/100 17280.00 89.94 302.49 6889.32 7069.75 14495.58 7104.86 -12636.06 63.93R 2.00 6.79 84.79 54975.13 2152301.93 156423.72 17300.00 90.12 302.85 6889.31 7069.74 14515.56 7115.65 -12652.90 63.93R 2.00 6.79 84.86 54981.05 2152313.18 156407.19 End Cry 17313.31 90.24 303.09 6889.27 7069.70 14528.85 7122.90 -12664.07 HS 2.00 6.79 84.91 54984.97 2152320.73 156396.22 17400.00 90.24 303.09 6888.91 7069.34 14615.41 7170.23 -12736.69 HS 0.00 6.80 84.91 54985.01 2152370.02 156324.91 17500.00 90.24 303.09 6888.50 7068.93 14715.27 7224.83 -12820.47 HS 0.00 6.80 84.91 54985.05 2152426.87 156242.64 17600.00 90.24 303.09 6888.08 7068.51 14815.12 7279.43 -12904.25 HS 0.00 6.81 84.91 54985.10 2152483.73 156160.38 17700.00 90.24 303.09 6887.67 7068.10 14914.97 7334.03 -12988.02 HS 0.00 6.82 84.91 54985.14 2152540.59 156078.11 17800.00 90.24 303.09 6887.26 7067.69 15014.83 7388.63 -13071.80 HS 0.00 6.82 84.91 54985.18 2152597.45 155995.85 17900.00 90.24 303.09 6886.84 7067.27 15114.68 7443.23 -13155.58 HS 0.00 6.83 84.91 54985.23 2152654.31 155913.59 Cry 3/100 17923.37 90.24 303.09 6886.75 7067.18 15138.01 7455.98 -13175.15 1.07L 0.00 6.83 84.91 54985.24 2152667.59 155894.36 KOP Cry 2/100 17980.00 91.94 303.06 6885.67 7066.10 15194.55 7486.89 -13222.60 LS 3.00 6.83 86.55 55102.90 2152699.77 155847.77 18000.00 91.54 303.06 6885.07 7065.50 15214.51 7497.79 -13239.35 LS 2.00 6.84 86.17 55079.39 2152711.13 155831.32 Cry 2/100 18080.00 89.94 303.06 6884.04 7064.47 15294.39 7541.43 -13306.39 160.73L 2.00 6.84 84.63 54960.65 2152756.58 155765.49 End Cry 18089.72 89.75 303.00 6884.07 7064.50 15304.10 7546.73 -13314.55 HS 2.00 6.85 84.47 54946.17 2152762.10 155757.49 18100.00 89.75 303.00 6884.11 7064.54 15314.36 7552.33 -13323.17 HS 0.00 6.85 84.47 54946.18 2152767.93 155749.02 18200.00 89.75 303.00 6884.55 7064.98 15414.22 7606.78 -13407.03 HS 0.00 6.85 84.47 54946.23 2152824.65 155666.67 18300.00 89.75 303.00 6884.98 7065.41 15514.09 7661.24 -13490.90 HS 0.00 6.86 84.47 54946.29 2152881.37 155584.31 18400.00 89.75 303.00 6885.41 7065.84 15613.95 7715.70 -13574.77 HS 0.00 6.86 84.47 54946.34 2152938.09 155501.95 18500.00 89.75 303.00 6885.85 7066.28 15713.81 7770.16 -13658.64 HS 0.00 6.87 84.47 54946.39 2152994.81 155419.59 18600.00 89.75 303.00 6886.28 7066.71 15813.67 7824.62 -13742.51 HS 0.00 6.87 84.47 54946.44 2153051.53 155337.23 18700.00 89.75 303.00 6886.71 7067.14 15913.54 7879.08 -13826.38 HS 0.00 6.88 84.47 54946.48 2153108.25 155254.87 Cry 3/100 18707.48 89.75 303.00 6886.75 7067.18 15921.01 7883.15 -13832.65 0.33R 0.00 6.88 84.47 54946.49 2153112.49 155248.71 Drilling Office 2.10.302.0 Cosmopolitan Unit\Cosmoplitan Pad\H1 4\H1 4\H1 4 (P5) 7/17/2018 1:51 PM Page 3 of 4 Comments MD Incl Azim True TVDSS TVD VSEC NS EW TF DLS Directional Exclusion Zone Exclusion ZoneGeoMag Th Northing Easting (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (0) (°/100ft) Difficulty Index Alert Angle (nT) (ftUS) (ftUS) KOP Cry 2/100 18780.00 91.93 303.01 6885.68 7066.11 15993.41 7922.65 -13893.46 LS 3.00 6.89 86.56 55103.54 2153153.63 155189.00 18800.00 91.53 303.01 6885.08 7065.51 16013.38 7933.54 -13910.22 LS 2.00 6.89 86.18 55080.10 2153164.97 155172.53 Cry 2/100 18880.00 89.93 303.01 6884.06 7064.49 16093.26 7977.12 -13977.30 178.62L 2.00 6.90 84.64 54961.61 2153210.35 155106.66 End Cry 18888.66 89.75 303.01 6884.09 7064.52 16101.90 7981.83 -13984.57 HS 2.00 6.90 84.47 54946.53 2153215.27 155099.53 18900.00 89.75 303.01 6884.14 7064.57 16113.23 7988.01 -13994.08 HS 0.00 6.90 84.47 54946.53 2153221.70 155090.19 19000.00 89.75 303.01 6884.57 7065.00 16213.09 8042.48 -14077.94 HS 0.00 6.90 84.48 54946.58 2153278.43 155007.84 19100.00 89.75 303.01 6885.00 7065.43 16312.95 8096.95 -14161.80 HS 0.00 6.91 84.48 54946.63 2153335.17 154925.49 19200.00 89.75 303.01 6885.42 7065.85 16412.81 8151.42 -14245.66 HS 0.00 6.91 84.48 54946.67 2153391.90 154843.14 19300.00 89.75 303.01 6885.85 7066.28 16512.68 8205.89 -14329.52 HS 0.00 6.92 84.48 54946.71 2153448.63 154760.79 19400.00 89.75 303.01 6886.28 7066.71 16612.54 8260.37 -14413.38 HS 0.00 6.92 84.48 54946.75 2153505.36 154678.44 19500.00 89.75 303.01 6886.71 7067.14 16712.40 8314.84 -14497.24 HS 0.00 6.93 84.48 54946.80 2153562.10 154596.09 Cry 3/100 19507.83 89.75 303.01 6886.75 7067.18 16720.22 8319.10 -14503.81 0.04L 0.00 6.93 84.48 54946.80 2153566.54 154589.64 KOP Cry 2/100 19580.00 91.92 303.00 6885.69 7066.12 16792.28 8358.41 -14564.32 LS 3.00 6.94 86.56 55103.38 2153607.47 154530.21 19600.00 91.52 303.00 6885.09 7065.52 16812.24 8369.30 -14581.09 LS 2.00 6.94 86.17 55079.92 2153618.82 154513.75 Cry 2/100 19680.00 89.92 303.00 6884.09 7064.52 16892.12 8412.87 -14648.17 178.55R 2.00 6.94 84.64 54961.35 2153664.20 154447.88 End Cry 19688.14 89.76 303.01 6884.11 7064.54 16900.26 8417.30 -14655.00 HS 2.00 6.95 84.48 54946.96 2153668.82 154441.17 19700.00 89.76 303.01 6884.16 7064.59 16912.09 8423.76 -14664.94 HS 0.00 6.95 84.48 54946.97 2153675.54 154431.41 19800.00 89.76 303.01 6884.59 7065.02 17011.96 8478.24 -14748.80 HS 0.00 6.95 84.48 54947.00 2153732.28 154349.06 19900.00 89.76 303.01 6885.01 7065.44 17111.82 8532.71 -14832.66 HS 0.00 6.96 84.48 54947.04 2153789.02 154266.71 20000.00 89.76 303.01 6885.44 7065.87 17211.68 8587.19 -14916.52 HS 0.00 6.96 84.48 54947.08 2153845.75 154184.36 20100.00 89.76 303.01 6885.86 7066.29 17311.54 8641.66 -15000.38 HS 0.00 6.97 84.48 54947.11 2153902.49 154102.01 20200.00 89.76 303.01 6886.29 7066.72 17411.40 8696.14 -15084.24 HS 0.00 6.97 84.48 54947.15 2153959.23 154019.66 20300.00 89.76 303.01 6886.71 7067.14 17511.26 8750.62 -15168.09 HS 0.00 6.97 84.48 54947.18 2154015.96 153937.3 Cry 3/100 20308.16 89.76 303.01 6886.75 7067.18 17519.41 8755.06 -15174.94 0.97L 0.00 6.97 84.48 54947.19 2154020.59 153930.60 KOP Cry 2/100 20382.00 91.97 302.97 6885.63 7066.06 17593.14 8795.26 -15236.86 LS 3.00 6.98 86.62 55106.92 2154062.46 153869.79 20400.00 91.61 302.97 6885.07 7065.50 17611.10 8805.05 -15251.95 LS 2.00 6.98 86.27 55086.27 2154072.66 153854.96 20482.00 89.97 302.97 6883.94 7064.37 17692.98 8849.67 -15320.74 176.12R 2.00 6.99 84.70 54966.89 2154119.13 153787.42 End Cry 20486.23 89.89 302.98 6883.94 7064.37 17697.21 8851.97 -15324.29 HS 2.00 6.99 84.62 54959.47 2154121.53 153783.93 20500.00 89.89 302.98 6883.97 7064.40 17710.96 8859.46 -15335.84 HS 0.00 6.99 84.62 54959.48 2154129.33 153772.59 20600.00 89.89 302.98 6884.17 7064.60 17810.82 8913.89 -15419.73 HS 0.00 7.00 84.62 54959.51 2154186.03 153690.21 20700.00 89.89 302.98 6884.37 7064.80 17910.69 8968.32 -15503.62 HS 0.00 7.00 84.62 54959.53 2154242.72 153607.83 20800.00 89.89 302.98 6884.56 7064.99 18010.55 9022.75 -15587.51 HS 0.00 7.01 84.62 54959.56 2154299.41 153525.45 20900.00 89.89 302.98 6884.76 7065.19 18110.42 9077.18 -15671.40 HS 0.00 7.01 84.62 54959.58 2154356.10 153443.07 21000.00 89.89 302.98 6884.96 7065.39 18210.28 9131.61 -15755.29 HS 0.00 7.02 84.62 54959.61 2154412.79 153360.69 21100.00 89.89 302.98 6885.16 7065.59 18310.15 9186.04 -15839.18 HS 0.00 7.02 84.62 54959.63 2154469.48 153278.30 21200.00 89.89 302.98 6885.35 7065.78 18410.01 9240.47 -15923.07 HS 0.00 7.02 84.62 54959.65 2154526.17 153195.92 21300.00 89.89 302.98 6885.55 7065.98 18509.88 9294.90 -16006.96 HS 0.00 7.03 84.62 54959.67 2154582.86 153113.54 21400.00 89.89 302.98 6885.75 7066.18 18609.74 9349.33 -16090.84 HS 0.00 7.03 84.62 54959.69 2154639.55 153031.16 21500.00 89.89 302.98 6885.95 7066.38 18709.61 9403.75 -16174.73 HS 0.00 7.04 84.62 54959.71 2154696.24 152948.78 21600.00 89.89 302.98 6886.14 7066.57 18809.47 9458.18 -16258.62 HS 0.00 7.04 84.62 54959.73 2154752.94 152866.40 21700.00 89.89 302.98 6886.34 7066.77 18909.34 9512.61 -16342.51 HS 0.00 7.05 84.62 54959.75 2154809.63 152784.02 21800.00 89.89 302.98 6886.54 7066.97 19009.20 9567.04 -16426.40 HS 0.00 7.05 84.62 54959.77 2154866.32 152701.64 21900.00 89.89 302.98 6886.74 7067.17 19109.07 9621.47 -16510.29 HS 0.00 7.06 84.62 54959.78 2154923.01 152619.26 Cry 3/100 21912.44 89.89 302.98 6886.76 7067.19 19121.49 9628.24 -16520.73 0.64R 0.00 7.06 84.62 54959.78 2154930.06 152609.01 21982.88 92.00 303.00 6885.60 7066.03 19191.83 9666.59 -16579.80 0.21 R 3.00 7.06 86.65 55108.11 2154970.00 152551.00 22000.00 92.51 303.00 6884.93 7065.36 19208.91 9675.90 -16594.15 0.21 R 3.00 7.07 87.14 55133.84 2154979.70 152536.91 22100.00 95.51 303.01 6877.93 7058.36 19308.51 9730.24 -16677.79 0.21 R 3.00 7.08 89.98 55202.59 2155036.29 152454.78 22200.00 98.51 303.02 6865.72 7046.15 19407.61 9784.32 -16761.00 0.21 R 3.00 7.09 87.11 55131.97 2155092.61 152373.06 22300.00 101.51 303.04 6848.33 7028.76 19505.94 9837.99 -16843.56 0.21 R 3.00 7.10 84.23 54922.24 2155148.51 152292.00 22400.00 104.51 303.05 6825.82 7006.25 19603.23 9891.10 -16925.22 0.22R 3.00 7.11 81.35 54574.09 2155203.83 152211.81 End Cry 22496.38 107.40 303.06 6799.32 6979.75 19695.74 9941.64 -17002.88 HS 3.00 7.12 78.58 54108.71 2155256.46 152135.5 22500.00 107.40 303.06 6798.24 6978.67 19699.20 9943.52 -17005.78 HS 0.00 7.12 78.58 54108.69 2155258.42 152132.70 22600.00 107.40 303.06 6768.33 6948.76 19794.48 9995.58 -17085.75 HS 0.00 7.12 78.58 54108.23 2155312.63 152054.17 22700.00 107.40 303.06 6738.41 6918.84 19889.77 10047.63 -17165.73 HS 0.00 7.13 78.58 54107.77 2155366.84 151975.64 22800.00 107.40 303.06 6708.50 6888.93 19985.06 10099.68 -17245.70 HS 0.00 7.13 78.58 54107.31 2155421.05 151897.11 TD 22829.43 � 107.40 303.06 6699.70 6880.13 20013.10 10115.00 -17269.23 0.00 7.13 78.58 54107.18 2155437.00 151874.00 Survey Error Model: ISCWSA Rev 0 "` 3-D 95.000% Confidence 2.7955 sigma Survey Program: Description Part MD From MD To EOU Freq Hole Size Casing Diameter Expected Max (ft) (ft) (ft) (in) (in) Inclination Ideal Survey Tool Type Borehole / Survey 1 0.000 1200.000 Act Stns 17.500 13.375 SLB_CNSG+CASING H16PB1 / H16PB1 1 1200.000 4126.070 Act Stns 17.500 13.375 SLB_MWD+GMAG H16P61 / H16PB1 1 4126.070 14308.350 Act Stns 12.250 9.625 SLB_MWD+GMAG H16PB1 / H16PB1 1 14308.350 14349.000 1/100.000 12.250 9.625 SLB_MWD+GMAG H16A-L01 / H16A-L01 (P2) 1 14349.000 14800.000 1/100.000 8.500 0.000 SLB -MWD -INC -ONLY -FILLER H16A-L01 / H16A-L01 (P2) 1 14800.000 16300.000 1/100.000 8.500 0.000 SLB _MWD+SAG H16A-L01 / H16A-L01 (P2) 2 14800.000 16382.000 1/100.000 8.500 0.000 SLB_MWD+GMAG H16A-L01 / H16A-L01 (P2) 2 16382.000 17180.000 1/100.000 8.500 0.000 SLB _MWD+GMAG H16A-L02 / H16A-1-02 (P2) 2 17180.000 17980.000 1/100.000 8.500 0.000 SLB _MWD+GMAG H16A-L03 / H16A-L03 (P2) 2 17980.000 18780.000 1/100.000 8.500 0.000 SLB _MWD+GMAG H16A-L04 / H16A-L04 (P2) 2 18780.000 19580.000 1/100.000 8.500 0.000 SLB _MWD+GMAG H16A-L05 / H16A-L05 (P2) 2 19580.000 20382.000 1/100.000 8.500 0.000 SLB _MWD+GMAG H16A-L06 / H16A-L06 (P2) 2 20382.000 22829.427 1/100.000 8.500 0.000 SLB_MWD+GMAG H16A / H16A (P2) Drilling Office 2.10.302.0 Cosmopolitan Unit\Cosmoplitan Pad\H14\1-114\1-114 (P5) 7/17/2018 1:51 PM Page 4 of 4 Vertical Section Plane ('0-00 ft N. OXG ft E) f 300,000 Vertical Section (h) Vertical Section Mane (0.00 ft N, 0.00 ft E) 0 300.001, mmmmuv.*A" IIIIIIIIIIIIIINUM Vertical Section (ft) 140M 150DO 1&400 17000 1KW 19000 20X�O ---- ----- ------- WEST (ft) EAST WEST (ft) EAST H16A (P2) Anti -Collision Summary Report Analysis Date-24hr Time: July 10, 2018 - 13:23 Analysis Method: 3D Least Distance Client: BlueCrest Reference Trajectory: H16A (P2) (Def Plan) Field: Cosmopolitan Unit Depth Interval: Every 10.00 Measured Depth (ft) Structure: Cosmopolitan Pad Rule Set: D&M AntiCollision Standard S002 v5.1/5.2 Slot: H-16 Min Pts: All local minima indicated. Well: H16 Version / Patch: 2.10.544.0 Borehole: H 16A Database 1 Project: localhost\drilling-Cook Inlet Scan MD Range: 20382.00ft -r 22829.43ft ISCWSAO 3-D 95.000% Confidence 2.7955 sigma, for subject well. For Traiectory Error Model: offset wells, error model version is specified with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans - All Non -Def Surveys when no Def -Survey is set in a borehole - All Non -Def Plans when no Def -Plan is set in a borehole Alert Status I Offset Trajectory Separation I Allow I Sep. Controlling I Reference Trajectory Risk Level Ct-Ct ft MAS ftEOU ft Dev. ft Fact. I Rule MD ft TVD ftAlert Minor major Major Major H16A-L07 (P2) (Def Plan) 0.00 347.98 -232.32 -347.98 0.00 OSF1.50 20382.00 7066.06 OSF<5.00 OSF<1.50 OSF<1.00 Fail Major 0.00 348.6 -232.7 -348.6 0.00 OSF1.50 20482.00 7064.37 Enter Major 0.05 170.07 -113.65 -170.01 -0.01 0.40 354.77 -236.44 OSF1.50 20510.00 7064.42 MinPts MinPt-O-SF -354.3 0.00 OSF1.50 21190.00 7065.76 MinPts 90.74 135.79 -0.11 -45.05 1.00 OSF1.50 21740.00 7066.85 OSF>1.00 Exit Major 130.14 132.62 41.40 -2.47 1.47 OSF1.50 21880.00 7067.13 OSF>1.50 Exit Minor 314.20 96.37 249.62 217.83 4.93 OSF1.50 22496.38 6979.75 OSF>5.00 Exit Alert 555.24 65.30 511.38 489.94 12.93 OSF1.50 22829.43 6880.13 TD H16A-L06 (P2) (Def Plan) Fail Major 0.00 347.98 -232.32 -347.98 0.00 OSF1.50 203$2.00 7066.06 OSF<5.00 OSF<1.50 OSF<1.00 Enter Major 0.03 135.17 -90.41 -135.14 -0.01 OSF1.50 20390.00 7065.80 MinPt-O-SF 84.37 128.53 -1.64 -44.16 0.98 OSF1.50 20920.00 7065.23 OSF>1.00 Exit Major 122.53 125.30 38.67 -2.77 1.47 OSF1.50 21060.00 7065.51 OSF>1.50 Exit Minor 403.76 121.97 322.13 281.80 4.99 OSF1.50 21760.00 7066.89 OSF>5.00 Exit Alert 1154.62 65.31 1110.75 1089.31 26.90 OSF1.50 22829.43 6880.13 TD H16 (Def Survey) 115.38 318.31 -97.16 -202.9 0.5 JO5F1.50 OSF1.50 20382.00 7066.06 OSF<5.00 OSF<1.50 OSF<1.00 Enter Major Fail Major 116.47 321.79 -98.39 -205.32 0.5 20540.00 7064.48 106.82 356.08 -130.90 -249.26 0.45 OSF1.50 21700.00 7066.77 MinPt-O-SF 107.05 357.68 -131.73 -250.62 0.4 OSF1.50 21740.00 7066.85 MinPt-CtCt 108.02 359.5 -132.02 -251.55 0.45 OSF1.50 21790.00 7066.95 MinPt-O-SF 110.81 362.88 -131. -252.01 0.46 OSF1.50 21880.00 7067.13 MI N PT -O -EO U 164.14 354.90 -72.79 -190.76 0.69 OSF1.50 22470.00 6987.47 MinPt-O-ADP 251.10 884.26 -338.73 -633.15 0.42 OSF1.50 22829.43 6880.13 MINPT-O-EOU MinPts Hansen #1 AL1 (Def Survey) 561.89 419.36 281.99 142.53 2.01 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert Fail Major 555.73 433.40 266.47 122.33 1.92 OSF1.50 20680.00 7064.76 MinPt-CtCt 544.2 464.00 234.59 80.25 1.76 OSF1.50 21110.00 7065.61 MinPt-CtCt 545.17 467.02 233-5011 78.1 gl 1.7]1O5F1.50 21240.00 7065.86 545.0 467.0111 233.37]1 78.03 1.75 OSF1.50 21300.00 7065.98 MinPts 545.04 467.01 233.3 1 78.0 1.7 OSF1.50 21310.00 7066.00 MinPts 544.30 465.80 233.41F-78,5011 1.75 OSF1.50 21430.00 7066.24 MinPts 488.34 490.03 161.32 -1.70 1.49 OSF1.50 22070.00 7061.01 OSF<1.50 MinPt-O-ADP Enter Minor 378.92 574.64 -4.50 -195.72 0.99 OSF1.50 22520.00 6972.69 OSF<1.00 Enter Major 341.95 632.06 -79.75 -290.11 0.81 OSF1.50 22700.00 6918.84 MinPt-CtCt 342.10 632.42 -79.84 -290.321 0.81 OSF1.50 22710.00 6915.85 MinPts 365.65 601.56 -35.72 -235.91 0.91 OSF1.50 22829.43 6880.13 TD H16A-L05 (P2) (Def Plan) Warning Alert 163.04 115.261 85.871 47.781 2.13 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 376.64 113.93 300.36 262.71 4.99 OSF1.50 20900.00 7065.19 OSF>5.00 Exit Alert 1811.44 65.71 1767.31 1745.73 41.96 OSF1.50 22829.43 6880.13 TD H12 (P7) (Def Plan) Warning Alert 817.22 320.33 603.34 496.89 3.83 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 815.78 321.20 601.31 494.57 3.82 OSF1.50 20530.00 7064.46 MinPt-CtCt 815.94 321.5611 601.23 494.38 3.81 OSF1.50 20580.00 7064.56 MINPT-O-EOU 816.32 322.03 601.3111 494.29 3.81 OSF1.50 20640.00 7064.68 MinPt-O-ADP 801.99 341.00 574.33 460.99 3.53 OSF1.50 22540.00 6966.70 MinPt-CtCt 802.12 341.421 574.18 460.70 3.53 OSF1.50 22600.00 6948.76 MINPT-O-EOU 802.22 341.55 574.20 460.67 3.53 OSF1.50 22620.00 6942.77 MinPt-O-ADP 802.69 341.92 574.42 460.78 3.53 OSF1.50 22680.00 6924.83 MinPt-O-SF 817.01 334.55 593.65 482.46 3.67 OSF1.50 22829.43 6880.13 TD H12 (Non-Def Survey) Warning Alert 817.22 320.33 603.34 496.89 3.83 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 815.78 321.20 601.31 494.57 3.82 OSF1.50 20530.00 7064.46 MinPt-CtCt 815.94 321.56 601.2 494.38 3.81 OSF1.50 20580.00 7064.56 MINPT-O-EO U 816.32 322.03 601.3111 494.29 3.81 OSF1.50 20640.00 7064.68 MinPt-O-ADP 816.78 323.78 600.60 493.00 3.79 OSF1.50 20840.00 7065.07 MinPt-CtCt 816.83 323.90 600.5 492.93 3.79 OSF1.50 20860.00 7065.11 816.89 323.96 600.5911 492.93 3.79 OSF1.50 20870.00 7065.13 MINPT-O-EO U MinPt-O-ADP 817.32 324.20 600.86 493.121 3.79 OSF1.50 20910.00 7065.21 MinPt-O-SF 818.52 324.61 601.79 493.91 3.79 OSF1.50 20970.00 7065.33 MinPt-O-SF 820.63 327.74 601.82 492.90 3.76 OSF1.50 21280.00 7065.94 MinPt-CtCt 815.78 334.38 592.53 481.40 3.67 OSF1.50 21910.00 7067.18 MinPt-CtCt 816.21 335.551 592.18 480.66 3.66 OSF1.50 22020.00 7064.37 817.28 337.141 592.19 480.13 3.64 OSF1.50 22170.00 7050.36 MINPT-O-EOU MINPT-O-EOU 817.58 337.51 592.291 480.07]1 3.64 OSF1.50 22210.00 7044.64 MinPt-O-ADP 819.00 338.42 593.06 480.58 3.64 OSF1.50 22320.00 7024.67 MinPt-O-SF 832.34 379.69 578.89 452.65J 3.29 OSF1.50 22670.00 6927.82 MinPts 856.22 369.15 609.80 487.08 3.48 OSF1.50 22829.43 6880.13 TD H12-L06 (Non-Def Survey) Warning Alert 817.22 320.33 603.33 496.88 3.83 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 815.78 321.21 601.31 494.57 3.82 OSF1.50 20530.00 7064.46 MinPt-CtCt 815.94 321.5�L 601.2311 494.37 3.81 OSF1.50 20580.00 7064.56 816.32 322.04 601.30 494.28 3.81 OSF1.50 20640.00 MINPT-O-EOU 7064.68 MinPt-O-ADP 816.97 323.44 601.02 493.53 3.80 OSF1.50 20800.00 7064.99 MINPT-O-EOU 817.24 323.76 601.07 493.48 3.79 OSF1.50 20840.00 7065.07 MinPt-O-ADP 818.21 324.30 601.68 493.91 3.79 OSF1.50 20910.00 7065.21 MinPt-O-SF 821.19 325.45 603.89 495.74 3.79 OSF1.50 21030.00 7065.45 MinPt-O-SF 826.23 328.46 606.93 497.77 3.78 OSF1.50 21300.00 7065.98 MinPt-O-SF 827.62 329.35 607.73 498.27 3.78 OSF1.50 21400.00 7066.18 MinPt-O-SF 891.54 342.3�1 662.97 549.17 3.91 OSF1.50 22080.00 7060.18 MINPT-O-EOU 893.00 344.35 663.11 548.63.9011 OSF1.50 22090.00 7059.29 MinPts 1004.01 303.18 801.56 700.83 4.98 OSF1.50 22460.00 6990.30 OSF>5.00 Exit Alert 1208.54 251.86 1040.31 956.68 7.22 OSF1.50 22829.43 6880.13 TD H12-1-05 (Non-Def Survey) Warning Alert 832.60 319.25 619.44 513.35 3.92 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 958.94 290.01 765.27 668.93 4.97 OSF1.50 21620.00 7066.61 OSF>5.00 Exit Alert 1699.70 166.69 1588.25 1533.01 15.38 OSF1.50 22829.43 6880.13 TD H12-1-04 (Non-Def Survey) Warning Alert 882.55 305.93 678.27 576.63 4.34 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 956.52 288.43 763.90 668.09 4.99 OSF1.50 20800.00 7064.99 OSF>5.00 Exit Alert 980.79 295.59 783.40 685.20 4.99 OSF1.50 20900.00 7065.19 OSF<5.00 Enter Alert 993.47 - 312.20 785.0111 681.2 14.78 OSF1.50 20950.00 7065.29 MinPts Cosmopolitan State 1 (Def Survey) 1013.62 306.29 809.10 707.33 4.98 OSF1.50 21020.00 7065.43 OSF>5.00 1372.07 250.36 1204.63 1121.71 2283.60 144.15 2187.18 2139.46 23.92 OSF1.50 22829.43 6880.13 Exit Alert 8.26 OSF1.50 20940.00 7065.27 MinPt-CtCt 2319.44 158.15 2213.47 2161.29 22.21 TD 22829.43 Hansen #1A (Def Survey) MinPts TD H14PB1 (Def Survey) Warning Alert 1453.38 1681.281 751,241 1180.121 930.041 3.36 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 312.24 1251.11 1147.36 7.03 OSF1.50 2342.13 704.20 1872.33 1637.92 4.99 OSF1.50 21940.00 7067.05 OSF>5.00 OSF1.50 22220.00 7043.08 2941.69 595.29 2544.50 2346.40 7.42 OSF1.50 22829.43 6880.13 Exit Alert MinPt-CtCt 1444.84 329.60 1224.78 1115.24 6.59 OSF1.50 22330.00 7022.54 MINPT-O-EOU TD H16A-1-04 (P2) (Def Plan) 330.03 1225.52 1115.83 6.591 OSF1.50 22420.00 7001.13 MinPt-O-ADP 1458.52 330.59 1237.79 1127.92 6.63 OSF1.50 22829.43 6880.13 MinPt-O-SF Pass 496.98 109.591 423.601 387.39 6.85 OSF1.50 20382.00 7066.06 2545.34 66.49 2500.69 2478.85 58.26 OSF1.50 22829.43 6880.13 MinPts Pass 1527.14 193.75 1397.64 1333.39 11.88 OSF1.50 20382.00 7066.06 TD 3699.67 H16PB1 (Def Survey) 57.85 OSF1.50 22829.43 6880.13 MinPts TD H14PB3 (Def Survey) Pass 927.59 85.33[_870.371 842.26 8 OSF1.50 20382.00 7066.06 7066.06 Pass 3351.58 79.59 3298.19 3271.98 63.93 OSF1.50 22829.43 6880.13 MinPts 1556.96 318.83 1344.08 1238.14 7.34 OSF1.50 21240.00 7065.86 MinPt-CtCt TD 319.06 1344.02 1237.99 H16A-1-03 (P2) (Def Plan) OSF1.50 21270.00 7065.92 MinPt-CtCt 1557.12 319.14 1344.0311 1237.98 7.34 OSF1.50 21280.00 7065.94 MINPT-O-EOU 1565.32 365.82 1321.11 1199.50 6.43 OSF1.50 21650.00 Pass MinPt-O-ADP 1022.89 60.141 982.471 962.75 1 OSF1.50 20382.00 7066.06 MinPts 3327.14 67.28 3281.96 3259.86 75.26 OSF1.50 22829.43 6880.13 MinPts 1662.87 TD 8.02 H12-1-03 (Non -Def Survey) 20382.00 7066.06 Pass 1662.701 313.50 1453.37 1349.20 7.98 OSF1.50 20590.00 7064.58 MinPt-CtCt 1663.08 315.1211 1452.67 1347.96 7.94 OSF1.50 20770.00 7064.93 Pass 1061.86 292.39 866.60 769.47 5.46 OSF1.50 20382.00 7066.06 1664.731 2941.48 118.72 2862.01 2822.76 37.46 OSF1.50 22829.43 6880.13 MinPts TD 371.43 1397.46 1273.98 Cosmopolitan State 1 (Def Survey) Pass 1372.07 250.36 1204.63 1121.71 8.26 OSF1.50 20930.00 7065.25 1372.07 250.38[___1204.62 1121.691 8.26 OSF1.50 20940.00 7065.27 MinPt-CtCt 2319.44 158.15 2213.47 2161.29 22.21 OSF1.50 22829.43 6880.13 MinPts TD H14PB1 (Def Survey) 1453.38 309.88 1246.46 1143.50 7.05 OSF1.50 20382.00 7066.06 Pass 1459.60 312.24 1251.11 1147.36 7.03 OSF1.50 20680.00 7064.76 MinPts 1444.53 328.82 1224.99 1115.71 6.60 OSF1.50 22220.00 7043.08 MinPt-O-SF 1444.73 329.481 1224.76 1115.26 6.59 OSF1.50 22310.00 7026.74 MinPt-CtCt 1444.84 329.60 1224.78 1115.24 6.59 OSF1.50 22330.00 7022.54 MINPT-O-EOU 1445.86 330.03 1225.52 1115.83 6.591 OSF1.50 22420.00 7001.13 MinPt-O-ADP 1458.52 330.59 1237.79 1127.92 6.63 OSF1.50 22829.43 6880.13 MinPt-O-SF TD H12-1-02 (Non -Def Survey) Pass 1527.14 193.75 1397.64 1333.39 11.88 OSF1.50 20382.00 7066.06 3699.67 96.89 3634.76 3602.79 57.85 OSF1.50 22829.43 6880.13 MinPts TD H14PB3 (Def Survey) 1560.13 310.26 1352.96 1249.87 7.56 OSF1.50 20382.00 7066.06 Pass 1560.80 311.46 1352.84 1249.35 7.54 OSF1.50 20460.00 7064.44 MinPts 1556.96 318.83 1344.08 1238.14 7.34 OSF1.50 21240.00 7065.86 MinPt-CtCt 1557.05 319.06 1344.02 1237.99 7.34 OSF1.50 21270.00 7065.92 MinPt-CtCt 1557.12 319.14 1344.0311 1237.98 7.34 OSF1.50 21280.00 7065.94 MINPT-O-EOU 1565.32 365.82 1321.11 1199.50 6.43 OSF1.50 21650.00 7066.67 MinPt-O-ADP 1981.76 297.15 1783.33 1684.61 10.03 OSF1.50 22829.43 6880.13 MinPts TD H14 (Def Survey) 1662.87 311.70 1454.74 1351.17 8.02 OSF1.50 20382.00 7066.06 Pass 1662.701 313.50 1453.37 1349.20 7.98 OSF1.50 20590.00 7064.58 MinPt-CtCt 1663.08 315.1211 1452.67 1347.96 7.94 OSF1.50 20770.00 7064.93 MinPt-CtCt 1663.28 315.36 1452.7111 1347.92 7.93 OSF1.50 20800.00 7064.99 MINPT-O-EOU 1664.731 319.56 1451.36 1345.17 7.83 OSF1.50 21230.00 7065.84 MinPt-O-ADP 1645.41 371.43 1397.46 1273.98 6.66 OSF1.50 22190.00 7047.60 MinPt-CtCt 1645.42 371.441 1397.461 1273.981 6.66 OSF1.50 22200.00 7046.15 MinPt-CtCt 1763.84 348.55 1531.14 1415.29 7.61 OSF1.50 22829.43 6880.13 MinPts TD H16A-LQ2 (P2) (Def Plan) Pass 1806.61 56.071 1768.90 1750.54 49.17 OSF1.50 20382.00 7066.06 MinPts Hansen #1 (Def Survey) H14P62 (Def Survey) 4176.03 68.25 4130.20 4107.78 93.11 1984.44 336.221...1759.961 1648.21 8.87 4351.65 217.60 4206.26 4134.05 30.13 2157.97 262.54[_1982.621 1895.43 12.37 4319.49 148.90 4219.89 4170.58 43.79 H12 -L01 (Non -Def Survey) 22829.43 6880.13 TD 2382.90 124.131 2299.821 2258.77 29.01 4697.14 84.31 4640.60 4612.82 84.54 H16A-L01 (P2) (Def Plan) Pass 2760.161 60.831 2719.28 2699.33 69.16 5159.87 69.59 5113.14 5090.27 112.79 OSF1.50 22829.43 6880.13 TD Pass OSF1.50 20382.00 7066.06 MinPts OSF1.50 22829.43 6880.13 TD Pass OSF1.50 20382.00 7066.06 MinPts OSF1.50 22829.43 6880.13 TD Pass OSF1.50 20382.00 7066.06 MinPts OSF1.50 22829.43 6880.13 TD Pass OSF1.50 20382.00 7066.06 MinPts OSF1.50 22829.43 6880.13 TD Starichkof State 1 (Def Survey) 4588.25 89.521 4528.241 4498.731 77.72 OSF1.50 20382.00 7066.06 MinPts Pass 6963.86 82.15 6908.77 6881.71 128.68 OSF1.50 22829.43 6880.13 TD H16A (P2) Anti -Collision Summary Report Analysis Date-24hr Time: July 10, 2018 - 13:24 Analysis Method: Normal Plane Client: BlueCrest Reference Trajectory: H16A (P2) (Def Plan) Field: Cosmopolitan Unit Depth Interval: Every 10.00 Measured Depth (ft) Structure: Cosmopolitan Pad Rule Set: D&M AntiCollision Standard S002 v5.1/5.2 Slot: H-16 Min Pts: All local minima indicated. Well: H16 Version / Patch: 2.10.544.0 Borehole: H 16A Database \ Project: localhost\drilling-Cook Inlet Scan MD Range: 20382.00ft - 22829.43ft ISCWSAO 3-D 95.000% Confidence 2.7955 sigma, for subject well. For Traiectory Error Model: offset wells, error model version is specified with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans - All Non -Def Surveys when no Def -Survey is set in a borehole - All Non -Def Plans when no Def -Plan is set in a borehole Offset Trajectory Separation Allow JDev. Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct ft MAS ftEOU ft ft Fact. Rule MD ft TVD ft Alert Minor Major Major Major H16A-L07 (PZ) (Def Plan) Fail Major 0.00 347.98 -232.32 -347.98 0.00 OSF1.50 20382.00 7066.06 OSF<5.00 OSF<1.50 OSF<1.00 Enter Major 0.00 348.6 -232.7 -348.6 0.00 OSF1.50 20482.00 7064.37 0.00 258.31 -172.54 -258.31 -0.01 OSF1.50 20490.00 7064.38 MinPts MinPt-CtCt 0.05 169.97 -113.59 -169.92 -0.01 OSF1.50 20510.00 7064.42 MinPt-O-SF 0.40 354.81 -236.47 -354.41 0.091 OSF1.50 21189.98 7065.76 MinPts 99.41 149.16 -0.36 -49.75 1.00 OSF1.50 21760.14 7066.89 OSF>1.00 Exit Major 149.26 150.67 48.49 -1.41 1.49 OSF1.50 21912.13 7067.19 OSF>1.50 Exit Minor 270.40 144.06 174.03 126.34 2.82 OSF1.50 22323.62 7023.90 TD H16A-L06 (P2) (Def Plan) Fail Major 0.00 347.98 -232.32 -347.98 0.00 OSF1.50 20382.00 7066.06 OSF<5.00 OSF<1.50 OSF<1.00 Enter Major 0.00 135.16 -90.44 -135.16 -0.01 OSF1.50 20382.96 7066.03 MinPts 0.14 135.7 1 -90.68 -135.60 -0.01 OSF1.50 20400.00 7065.50 MINPT-O-EOU 0.34 135.96 -90.6 -135.62 -0.01 OSF1.50 20410.00 7065.24 MinPt-O-ADP 92.57 141.54 -2.12 -48.98 0.98 OSF1.50 20940.88 7065.27 OSF>1.00 Exit Major 140.85 142.97 45.20 -2.13 1.48 OSF1.50 21093.37 7065.57 OSF>1.50 Exit Minor 404.28 148.51 304.94 255.78 4.10 OSF1.50 21670.59 7066.71 TD H16 (Def Survey) 115.38 318.16 -97.05 -202.781 0.54 OSF1.50 20382.00 7066.06 OSF<5.00 OSF<1.50 OSF<1.00 Enter Major Fail Major 116.31 321.20 -98.15 -204.881 0.54 OSF1.50 20524.77 7064.45 MinPt-O-SF 117.67 324.64 -99.09 -206.9 0.54 OSF1.50 20644.72 7064.69 MinPt-O-SF 106.82 356.25 -131.01 -249.43 0.45 OSF1.50 21704.45 7066.78 MinPt-CtCt 107.00 357.34 -131.56 -250.340.4 OSF1.50 21734.45 7066.84 MinPt-O-SF 107.91 359.1 -131.84 -251.23 0.45 OSF1.50 21784.44 7066.94 MINPT-O-EOU 111.05 362.80 -131.1 -251.71 0.46 OSF1.50 21884.39 7067.13 MinPt-O-ADP 157.19 346.13 -73.90 -188.94 0.68 OSF1.50 22417.64 7001.75 MinPt-O-SF 167.81 365.2 6.01 -197.42 0.69 7-369.431 OSF1.50 22472.57 6986.73 MINPT-O-EOU 242.82 917.87 -675.061 0.401 OSF1.50 22765.21 6899.34 MinPts Hansen #1 AL1 (Def Survey) Fait Major 562.72 418.64 283.31 144.09 2.02 OSF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 1555.71 433.51 266.40 122.23 1.92 OSF1.50 20682.42 7064.76 MinPt-CtCt 544.2 464.06 234.55 80.19 1.76 OSF1.50 21111.29 7065.61 MinPt-CtCt 545.04 467.0211 233.3J1 78.0J1 1.7 OSF1.50 21291.24 7065.96 E5:031 467.01 233.37 78.03 1.75 OSF1.50 21301.24 7065.98 MinPts MinPt-CtCt 491.85 491.98 163.53 -0.13 1.50 OSF1.50 22085.54 7059.69 OSF<1.50 Enter Minor 384.59 579.68 -2.19 -195.08 0.99 OSF1.50 22561.38 6960.31 OSF<1.00 Enter Major 341.95 632.06 -79.75 -290.101 0.81 OSF1.50 22699.94 6918.86 MinPts H16A-1-05 (P2) (Def Plan) 173.87 135.681 83.091 38.19 1.93 OSF1.50 20383.40 7066.02 OSF<5.00 Warning Alert Enter Alert 470.79 142.47 375.47 328.31 4.98 OSF1.50 21015.57 7065.42 TD H12 {P7} (Def Plan) Warning Alert 817.28 320.22 603.47 497.06 3.84 OSF1.50 20385.40 7065.95 OSF<5.00 Enter Alert 815.78 321.17 601.34 494.61 3.82 OSF1.50 20525.67 7064.45 MinPt-CtCt 815.98 321.66 601.21]1494.32 3.81 OSF1.50 20585.66 7064.57 MINPT-O-EOU 801.99 340.95 574.36 461.03 3.53 OSF1.50 22534.31 6968.41 MinPt-CtCt 802.15 341.531 574.13 460.62 3.53 OSF1.50 22603.67 6947.66 MINPT-O-EOU 802.33 341.75 574.17 460.58 3.53 OSF1.50 22633.28 6938.80 MinPt-O-ADP 802.70 342.06 574.33 460.64 3.53 OSF1.50 22677.18 6925.67 MinPt-O-SF H12 (Non -Def Survey) Warning Alert 817.28 320.22 603.47 497.06 3.84 OSF1.50 20385.40 7065.95 OSF<5.00 Enter Alert 815.78 321.17 601.34 494.61 3.82 OSF1.50 20525.67 7064.45 MinPt-CtCt 815.98 321.661[_601.21 494.32 3.81 OSF1.50 20585.66 7064.57 MINPT-O-EOU 11 816.78 323.75 600.62 493.03 3.79 OSF1.50 20835.65 7065.06 MinPt-CtCt 816.82 323.91 600.55 492.91 3.79 OSF1.50 20855.65 7065.10 MINPT-O-EOU 816.96 324.08 600.5811 492.88 3.79 OSF1.50 20875.65 7065.14 MinPt-O-ADP $20.6 327.79 601.78 492.85 3.76 OSF1.50 21285.57 7065.95 815.78 334.44 592.49 481.34 3.67 OSF1.50 21914.87 7067.19 MinPt-CtCt MinPt-CtCt 816.27 335.711 592.1 480.56 3.65 OSF1.50 22025.91 7064.04 817.28 337.221 592.14 480.06 3.64 OSF1.50 22168.06 7050.61 MINPT-O-EOU 817.80 337.85 592.2 479.96 3.64 OSF1.50 22229.22 7041.60 MINPT-O-EOU 819.84 339.07 593.47 480.7 3.63 OSF1.50 22351.65 7017.77 MinPt-O-ADP MinPt-O-SF 831.03 380.48 577.05 450.55 3.28 OSF1.50 22623.24 6941.80 MinPts H12 -L06 (Non -Def Survey) Warning Alert 817.28 320.23 603.47 497.05 3.84 OSF1.50 20385.40 7065.95 OSF<5.00 Enter Alert 815.78 321.18 601.33 494.60 3.82 OSF1.50 20525.67 7064.45 MinPt-CtCt 815.98 321.6 601.20 494.31 3.81 OSF1.50 20585.66 7064.57 MINPT-O-EOU 817.01 323.55 600.99 493.47 3.79 OSF1.50 20805.66 7065.00 MINPT-O-EOU 817.24 323.83 601.02 493.41 3.79 OSF1.50 20835.65 7065.06 MinPt-O-ADP 827.73 329.47 607.75 498.26 3.78 OSF1.50 21405.80 7066.19 MinPt-O-SF 881.06 350.76 646.89 530.30 3.77 OSF1.50 21930.14 7067.14 MinPts H12-1-05 (Non -Def Survey) Warning Alert 834.74 320.82 620.54 513.92 3.91 •SF1.50 20382.00 7066.06 OSF<5.00 Enter Alert 913.50 306.84 708.61 606.66 4.48 OSF1.50 21328.30 7066.04 TD H12-1-04 (Non -Def Survey) Warning Alert 890.79 306.17 686.35 584.62 4.37 OSF1.50 20384.42 7065.98 OSF<5.00 Enter Alert 960.52 325.5 743.14 634.95 4.43 OSF1.50 20696.24 7064.79 MinPts Hansen #1A (Def Survey) Warning Alert 1825.05 787.451 1299.751 1037.60 3.48 OSF1.50 20388.91 7065.83 OSF<5.00 Enter Alert 1901.87 794.67 1371.77 1107.20 3.59 OSF1.50 20573.09 7064.54 TD Cosmopolitan State 1 (Def Survey) 4487.98 128.921 4401.5011 4359.0611 52.86 OSF1.50 20915.45 7065.22 Pass 5370.26 122.311 5288.18 5247.9 66.711 OSF1.50 22496.22 6979.80 MinPts 5370.26 122.31 5288.18 5247.94 66.71 OSF1.50 22496.64 6979.67 MinPts 1372.07 250.39L_1204.61 1121.68 8.26 OSF1.50 20934.73 7065.26 MinPt-CtCt MinPts 1372.11 250.45 1204.61 1121.67 8.26 OSF1.50 20934.74 7065.26 MinPt-O-ADP 1372.43 250.54 1204.87 1121.89 8.26 OSF1.50 20934.75 7065.26 MinPt-O-SF 6324.21 119.3 6244.12 6204.8 80.55 OSF1.50 22802.19 6888.28 MinPts 6408.94 119.22 6328.93 6289.72 81.71 OSF1.50 22829.43 6880.13 TD H14PB1 (Def Survey) 1453.65 310.1011 1246.5911 1143.5 7.05 OSF1.50 20382.60 7066.04 Pass MinPts 1444.53 328.86 1224.96 1115.67 6.60 OSF1.50 22224.76 7042.33 1444.71 329.441 1224.75 1115.26 6.59 OSF1.50 22300.40 7028.68 MinPt-CtCt MINPT-O-EOU 1444.86 329.63 1224.77 1115.22 6.59 OSF1.50 22328.45 7022.88 MinPt-O-ADP 1445.94 330.10 1225.54 1115.84 6.59 OSF1.50 22411.47 7003.34 MinPt-O-SF 1459.60 330.57 1238.89 1129.03 6.64 OSF1.50 22829.43 6880.13 TD H14PB3 (Def Survey) 1560.56 310.82 1353.02 1249.7 7.55 OSF1.50 20382.00 7066.06 Pass 1560.80 311.45 1352.84 1249.35 7.54 OSF1.50 20459.86 7064.44 MinPts 1556.97 318.78 1344.12 1238.18 7.34 OSF1.50 21235.26 7065.85 MinPt-CtCt MinPt-CtCt 1557.05 319.0�1 1344.01 1237.98 7.34 OSF1.50 21265.08 7065.91 1557.13 319.16 1344.021237.96 7.34 OSF1.50 21275.02 7065.93 MINPT-O-EOU 1564.64 365.73 1320.491F_1198.91 6.43 OSF1.50 21604.06 7066.58 MinPt-O-ADP MinPts H14 (Def Survey) 1662.87 311.72 1454.73 1351.15 8.02 OSF1.50 20382.00 7066.06 Pass 1662.701 313.55 1453.34 1349.15 7.97 OSF1.50 20595.84 7064.59 MinPt-CtCt 1663.07 315.1 1452.66 1347.95 7.94 OSF1.50 20765.21 7064.92 MinPt- MinPt- tc CtC t 1663.30 315.40 1452.71 1347.90 7.93 OSF1.50 20795.06 7064.98 MINOU 1664.73 319.50 1451.40 1345.23 7.84 OSF1.50 21223.66 7065.83 MinPt-O -ADP DP 1645.40 371.43 1397.45 1273.97 6.66 OSF1.50 22193.65 7047.08 Mit-O- MiCtC nPtst H16A-1-03 (P2) (Def Plan) Pass H16A-1-04 (P2) (Def Plan) Pass H12-1-01 (Non-Def Survey) Pass H16PB1 (Def Survey) Pass H16A-1-01 (P2) (Def Plan) Pass Hansen #1 (Def Survey) Pass H12-1-03 (Non-Def Survey) Pass H14PB2 (Def Survey) Pass H16A-1-02 (P2) (Def Plan) Pass H12-1-02 (Non-Def Survey) Pass Starichkof State 1 (Def Survey) Pass Traveling Cylinder Plot NoGo Rogiom ECU's based on! Onionted EOU Dimension - Minor Risk TRAVELING CYLINDER PLOT Anti-CoNision rule, used: D&M AntiCollmion Standard 5002 v5. V5 2 Choni S!u*Cr*st Field Cosmopolitan Unit Structure Cosmopolitan Pad Well H18 North Sor*h*lo WeA 350 0 10 Date 340 20 330 40 30 320 0 40 310 50 300 (P2) 60 290 70 Je 280 - so 270 90 260 100 250 110 240 120 230 130 140 210 200 160 190 1"1 111-80 170 Well Ticks, Type MO on WaA (P2) t� Calcu�aon Method Normal Pune Rtnq Interval 20 00 ft Azimuth Interval: 10.00 deg Start Depth: 20382.00 ft End Depth, 22829.43 ft Offsot Well Coumt: 2f! Before exemption After exemption NoGo R - TRAVELING CYLINDER PLOT « Chem 8!U*cT*S1 FieA Structure Cosmopolitan Unit Well Cosmopolitan Pad H16 Borehole H 18 # Date G -Jul -2018 w�� I PAP A MUM * M"VNIO& 4% ATMM MUMMUM j uwgr� OW-rVIE a wlerntemn Traveling Cylinder Plot NoGo Rogiom ECU's based on! Onionted EOU Dimension - Minor Risk TRAVELING CYLINDER PLOT Anti-CoNision rule, used: D&M AntiCollmion Standard 5002 v5. V5 2 Choni S!u*Cr*st Field Cosmopolitan Unit Structure Cosmopolitan Pad Well H18 North Sor*h*lo WeA 350 0 10 Date 340 20 330 40 30 320 0 40 310 50 300 (P2) 60 290 70 Je 280 - so 270 90 260 100 250 110 240 120 230 130 140 210 200 160 190 1"1 111-80 170 Well Ticks, Type MO on WaA (P2) t� Calcu�aon Method Normal Pune Rtnq Interval 20 00 ft Azimuth Interval: 10.00 deg Start Depth: 20382.00 ft End Depth, 22829.43 ft Offsot Well Coumt: 2f! Before exemption After exemption ^luest Energy Attachment Cosmopolitan Project H 16-A-1 0-401 Fishbone Sidetrack AP® Attachments H16-A�10-401 Fishbone Sidetrack APD Attachments NOTE: The Maginbore H16A is to be drilled from a window cut in the 9m5/8&"' casing, with the H16A a6inbore to be completed with a 4- 1/2" slotted liner, and as such,, no cementing operations are required in this proposed well, and further there are no casing design or cement volume calculations to present in this section of the H16A ainbore APD. The original casing design calculations for H16 can be found in the approved APD (216-076) for that well on file at the AOGCC, I Iluest e e Energy Attachment Cosmopolitan Project H 16-A 1 0-4-01 Fishbone Sidetrack AP® Attachments H16 -A10-401 Fishbone Sidetrack APD Attachments Ilue tt Energy AlueCrest LOT/FIT Procedure Cosmopolitan Project LOT/FIT Procedure I. Drill out the shoe track and clean out any rat hole from the previous hole section below the shoe. From this depth, drill an additional 20 ft (minimum) to 50 ft (maximum) of new hole. 2. Circulate the wellbore clean and ensure MW in = MW out. Record this value. Line up one mud pump on the kill line. Isolate the other pump(s). 3. Turn on the pump to flood the kill line and to ensure the hole is full and that no air is present in the circulating system. 4. While pumping, ensure that the pump pressure gauge and the gauge on the chart recorder are reading the same pressure. 5. Shut down the pump, position a tool joint at the rig floor and close the upper pipe rams. 6. Bring the mud pump on line slowly at % - %2 bbl per minute and watch for pressure to start increasing. 7. Verify no fluid is leaking past the closed pipe rams. Record the pressure from the chart recorder vs strokes pumped every 2 or 3 strokes pumped. The pressure should increase in a linear fashion vs strokes (Volume) pumped. 8. To perform a LOT (Leak -off Test), continue pumping and recording pressure vs strokes until the pressure deviates from a straight line trend. Obtain two additional readings to confirm this deviation from linearity. 9. Shut down the pump and continue to record pressure vs time, initially every 30 seconds for 2 minutes and then every minute for an additional 8 minutes. 10. Plot the points for the pressure build up vs volume pumped on one chart and the pressure drop vs time on a second chart. 11. By looking at the chart of pressure vs volume pumped, the leak -off pressure is the point at which the curve deviates from a straight line trend. 12. Use the formula: MW + PressureLeak Off MW MW _ 7'VDsnoe x 0.052 13. Report using the format below: • XX.XX ppg EMW FIT/LOT w/ XXX psi and XX.XX ppg MW @ X,XXX' TVD 14. The FIT follows the same operational steps as previously described, except that the pressure is increased to a pre -determined value previously calculated, where the plot of pressure vs volume pumped does not deviate from a straight line. Using the same formula, the FIT value is obtained. If, however, deviation from a straight line does occur, do not keep pumping. The leak off pressure has been reached and additional pumping may cause the formation to break down. 15. The final step is to bleed off the pressure from the test and measure the volume of fluid returned to a small pit such as the trip tank or small pill pit. Depending on well design and depth, this volume bled back could be small — maybe no more than 1 bbl. 10-401 APD Attachments LOT/FIT Procedure lust Energy Attachment Cosmopolitan Project H16 -A-1 0-4-01 Fishbone Sidetrack AP® Attachments H16 -A_10-401 Fishbone Sidetrack APD Attachments I Ilue est Energy Cosmopolitan Project BOP & Choke Manifold Configuration 2 11 5/81, 27 3/4' 13 5/8"X10K� CAMERON BOP STACK DAIT - I 14t 0i x(y) Ln CL CL < Lr) T --- 4 VLUECREST ENERGY 13 5/87MOK CAMERON BOP STACK - RU 6/22/15 FULLBSBC70 "Umm 02 10-401 APD Attachments BOP & Choke Manifold Configuration Ilu e)eps t Energy Cosmopolitan Project BOP & Choke Manifold Configuration 10-401 APD Attachments BOP & Choke Manifold Configuration ^luest Energy Diverter Cosmopolitan Project BOP & Choke Manifold Configuration i M AS CA$7 N 10-401 APD Attachments BOP & Choke Manifold Configuration �_F G 9f4 IN 111 101 _11-1 H -- K Vis 27% 1 45% L 5134 M, N 5" 1 52% K I "I I CLAMP L AS CAST HUB Nominal Dimensians--Inches--with 2000 psi Bottom Connections A . ... ....... 8 C 0 E F G H J K L M ------- -- N 0 Hub 181 Hubt 52% 51 12yz 23% Th OV 274t 46% 5134 58% 52% 50 1% ttk Hub 1. 10-401 APD Attachments BOP & Choke Manifold Configuration A C F Hob 17 Hkqbb I 54% 12% 23% 51" U$0 F G 9f4 IN 111 101 _11-1 H -- K Vis 27% 1 45% L 5134 M, N 5" 1 52% 0 P 50 1% 1 10-401 APD Attachments BOP & Choke Manifold Configuration Ilue epst Energy Attachment 6 Cosmopolitan Project H 1 6-A-1 0-4-01 Fishbone Sidetrack APD Attachments H16 -A10-401 Fishbone Sidetrack APD Attachments nlue. st Energy !-0 —,T, 11, 4 1116 LOW Wo wit VG 4z St& p1do 1 u -sAr s.ow m, 2 Vlt* SAXI 4*:Al K4)�, .1 wr 5.ow pit S/0' PAiL 4r , 4 13, W SPW PSI 13 Pt f u I t 0 4-6 K MOO Me . ozo lit *OOLMM MAN"M Ova."* wrz, 4ww_OM.$qM 2 .wwv"w, kiv. Out 0. 00 aw ft"MOR *86" 46 133 Cosmopolitan Project Wellhead/Tree 10-401 APD Attachments Wellhead/Tree 'Nepst 1u e Energy Attachment t V r * f, � p Cosmopolitan Project H16 -A10-4-01 FisMone Sidetrack APL Attachments H16 -A10-401 Fishbone Sidetrack APD Attachments NOTE: The Rib Laterals ion H16A are to be drilled from a window cut'In the 9-5/8" casing using the BlueCrest Rig 1 BOP stack and choke manifold for well control (no D*iverter system applicable), and as such, there are no Di*verter Schematics to present in this section of the respective L01 through L07 Lateral APD&1s, Ilue est Energy Attachment 8: Lease Map Cosmopolitan Project H16 -A_10-4.01 Fishbone Sidetrack APD Attachments HI6-A_10-401 Fishbone Sidetrack APD Attachments H 1 6A With 1000' Radius Around Production Sect -ion 500' From Lease Boundary C 29 T3S. W, St,H14 ADL3844 331 H12 R SEC 28, T3S. R15W. SM � H 12-LO6 H � H 12-LO5 Ha,isen 1 H_1 2-L H -12-L H-1 2-L H -12 -LO Hansen 1 A ,� Stan f St 1 SEC: 32, TTS, R15W. SM KOP SEC 33, T31, f? 5 h1 H 16A Surface Location (NAD 27) i Northing: 2,145,914.431, Easting 166,970.57' 2,408' FSL, 1509' FEL, Sec. 2, T4S, R15W SM Surface Casing Point Northing: 2145773.805' Easting: 167211.107' 3,414' FSL, 3,429' FEL, Sec. 2, T4S, R15W SM Bottom of Window Northing: 2,150,581.45', Easting: 158,778.19' 2,572' FSL, 1,182' FEL, Sec. 33, T3S, R15W SM SEC 4 T4S. R 15W, SM Total Depth i Northing: 2,155,347.001, Easting: 151,874.00' 1,950' FSL, 2,933' FEL, Sec. 29, T3S, R15W SM Cosmopolitan Unit Development Date Company 10/07/2018 BlueCrest Energy SEC 27. T3S, R15W. SM SEC 34, T3S. R15W, SM ADL18 990 SEC 3. T4S. R15W, SAA 0 1000 2000 3000 4000 50 MUS 1:30000 SEC 26. T3S, R15W. SM SEC 35. T3S. R1 5UJ, `M SEC 2. T4`3, SEC 36: T3. SEC 1, T4S, I New Well Rig Elevation Form FIELD WELL RIG Cellar Box Elevation (CBE) (from 'As Built' Survey Plat dated 12-30-1980) Actual Rig Height (RT -GL) (from rig measure) Actual Rig Elevation (Actual RTE) (CBE+RT-GL=Actual RTE) Rotary Table - Base Flange Height (RT -BF) (from rig measur) Base Flange - Mean Sea Level (BF -MSL) (actual RTE - RT -BF = BF -MSL) Cosmopolitan Unit H16 BlueCrest#1 145.81 ft 34.62 ft 180.43 ft 40.56 ft 139.87 ft November 23, 2016 DIRECTIONAL DRILLER (please print) Marty Rinke TRANSMITTAL LETTER CHECKLIST WELL NAME: H (6A PTD: t,, t 8 - O 95 /Development _Service _Exploratory _ Stratigraphic Test _Non -Conventional FIELD: Ha h -5'e PO) POOL: HavNseh u�f � Check Box for Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing well Permit MULTI 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 25.0050, 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 sam les are first cau ht 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 ro ram. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, //,Per 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 HANSEN, HANSEN UNDEF OIL - 290100 PTD#:2180950 Company BLUECREST ALASKA OPERATING LLC Initial Class/Type DEV Well Name: HANSEN H -16A Program DEV Well bore seg V / 1 -OIL GeoArea 820 Unit 10370 On/Off Shore Off Annular Disposal ❑ Administration 17 Nonoonven. gas conforms to AS31.05.030Q.1.A),lj.2.A-D) NA. Commissioner: Date Commissioner Date 0/13I 1 Permit fee attached NA I$ 2 Lease number appropriate. _ _ Yes .... . . ....... 3 Unique well name and number _ _ _ _ _ .. _ .. _ . - . _ Yes 4 Well located in. a. defined pool _ ......... ........... Yes 5 Well located proper distance from drilling unit boundary_ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 Well located proper distance from other wells.. _ _ _ _ _ _ _ _ _ _ _ _ _ No. _ Spacing exception required. Hearing vacated; spacing exception order in progress. SFD9/121'2018 7 Sufficient acreage available in drilling unit.. ..... .. Yes As planned, this well does NOT conform with statewide spacing requirements. 8 If deviated, is wellbore plat included _ _ _ _ .. . ........ ......... Yes H2S not observed in nearby Hansen wells. Rig has sensors and alamis. 9 Operator only affected party - - - - - - - - - - - - - _ _ ... _ _ _ _ Yes 10 Operator hasappropriate bond in force _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ Appr Date 11 Permit can be issued without conservation order _ _ _ _ _ _ _ No _ 12 Permit can be issued without administrative. approval _ ... Yes SFD 9/12/2018 13 Can permit be approved before 15 -day wait _ _ ........... . . . No. 14 Well located within area and strata authorized by Injection Order# (put 10# in comments) (For! NA 15 All wells.within 114 mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA. 16 Pre -produced injector; duration of pre-produgtion less than 3 months (For service welt only) .. NA _ .... _ 18 Conductor string provided . . . . . . . . . . . . . . . .......... . . ............ NA........ Sidetrack from whipstock placed in existing intermediate_ casing string Engineering 19 Surface casing. protects all known USDWs ............................. NA. Sidetrack from whipstock placed in existing intermediate. casing string.. . 20 CMT. vol. adequate to circulate on conductor & surf csg . . . . ........ . . . . . . . . .NA Sidetrack from whipstock placed in existing intermediate. casing string.. _ 21 CMT vot adequate to tie-in long string to surf csg _ _ _ _ _ _ _ _ NA _ Sidetrack from whipstock placed in existing intermediate. casing string 22 CMT will cover all knownproductive horizons _ _ _ _ _ _ _ _ NA _ _ Cemented above the reservoir, slotted liner completion 23 Casing designs adequate for C, T, B &.permafrost _ _ _ _ Yes 24 Adequate. tankage. or reserve pit _ _ _ _ _ ..... Yes 25 If a_re-drill, has_a 10-403 for abandonment been approved _ _ ... Yes 26 Adequate wellbore separation proposed _ _ _ _ _ _ Yes _ Close approaches within the reservoir 27 If diverter required, does it meet regulations. _ _ _ _ _ NA -------------------- Appr Date 28 Drilling fluid. program schematic & equip list adequate _ _ _ Yes MGR 8/21/2018 29 SOPEs, do they meet regulation _ _ _ _ _ _ Yes 30 BORE press rating appropriate; test to (put prig in comments).. ..... Yes .. _ ...... . 31 Choke manifold complies w/API_RP-53 (May 84).... _ Yes 32 Work will occur without operation shutdown... _ _ _ _ Yes 33 Is presence of H2$ gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No 34 .Mechanical condition of wells within AOR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ NA..... 35 Permit can be issued w/o hydrogen. sulfide measures _ _ _ _ _ _ _ _ _ _ _ Yes Geology 36 Data presented on potential overpressure zones... _ _ _ _ _ _ _ _ _ .. Yes Appr Date 37 Seismic analysis of shallow gas zones_ _ .... ...... .............. NA...... DLB 8/8/2018 38 Seabed condition survey (if off -shore) . . ...... . ..... . . . . . . . . . ...... . . . .NA .. _ . - 39 Contact name/phone for weekly progress reports [exploratory only] ........... . ......NA..... . Geologic Engineering Public Commissioner: Date: 4113 I�� Commissioner: Date Commissioner Date 0/13I J S Sx � CFS I$
