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219-054
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Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Li Pull Tubing Li Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert to WINJ ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name ConocoPhillips Alaska, Inc. Develo ment Ex lorato P ❑ P ry ❑ Stratigraphic ❑ Service ❑ 219-054-0 3. Address: P. O. BOX 100360 6. API Number: Anchorage, Alaska 99510 50-029-22419-60-00 7. Property Designation (Lease Number): 8. Well Name and Numeec KRU 2E-1711 ADL 25658, ADL 25665, ADL 25664 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9,206 feet Plugs measured None feet true vertical 6,388 feet Junk measured None feet Effective Depth measured 9,206 feet Packer measured 8735 feet true vertical 6,388 feet true vertical 6014 feet Casing Length Size MD TVD Buret Collapse Structural Conductor 80 16 121 121 Surface 4,439 95/8 4,481 3,473 Intermediate Production 9,165 7 9,206 6,380 Liner 3,661 23/8 12,258 6,081 Perforation depth Measured depth -- feet True Vertical depth -- feet MD TVD Tubing (size, grade, measured and true vertical depth) 3.5 L-80 8860 6114 NO SSSV Packers and SSSV (type, measured and true vertical depth) BAKER T' x 3-1/2" FHL PACKER 8735 6014 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: — -- -- — Subsequenitooperation:— -- 1126 1534 12639 14. Attachments (required per 20 AAO 25.090,25.071,825283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ] WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct t0 the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-355 Contact Name: Alex Trower Authorized Name: Lynn Aleshire Contact Email: alexj.eower@oonocophillips.com Authorized Title: Staff Petroleum Engineer Contact Phone: (907) 263-3733 (D Authorized Signature: Date: 9 v7-1 /0//5// 9 A "ilk BDMS W'`' OCT 112019 Form 10-004 Revised 4/2017 Submit Original Only 2E-171.1 DAILY REPORT OF WELL OPERATIONS 9: 2E-17 was brought on water injection after completion of workover, CTD sidetrack and permanent Dn to waterflood facility KUP INJ WELLNAME 2E-17 WELLBORE 2E -17L1 cmmoPhillips Kaska. Imc. .-In1. I.. Em Last Tag Vx mM .I.) Annatal O pth B) End Date Milkore la:l mad ey UST TAG: 2E-i]Li i1jennit Last Rev Reason AnnolaUan End am. S1 mad ay REV REASON; CTD Lateral A10/2019 2E-1ILt jennall Casing Strings C—n,a.-nolbn I.. pp ID(m) TDR(RHa) soo."tIM.e) Bet D¢o1N IrvD1... wuL¢n 11._Grade Tov Tl LILATERAL(CTD) 12258.0 6081.0 HANGIR;$80 CONDVCTOfl: 015121.0 G48 UFT: 2,8B0 SURFACE: 41.•al G<S UFT: 4.M2 GPS LIFT', 6, 13 GAS LIFT:],51B3 GAS LIFT; &ZA3 GPS UFT; B,B828 LOCATOR: B,7198 SEAL ASSY a.Ia, PACHER B,.a 1!WOING NIPPLE; area0 Fi CTD COILTRACK all iROOUCTION, 41 ll D LI UTEl (CTD); 12,255.0 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Alex Trower Sr. Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2E -17L1 Permit to Drill Number: 219-054 Sundry Number: 319-355 Dear Mr. Trower: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaslka.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this �sday of August, 2019. RBDMS�` AUG 16 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS REVISION 20 AAC 25.280 1. Type of Re[JUBS : W Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program(:) Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Convert to WINJ El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: CionooOPhllll s Alaska Inc. Exploratory ❑ Development El • Stratigraphic ❑ Service ❑ 219-054-0 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22419-60-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2E -17L1 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Fieltl/Pool(s): ADL 25658, ADL 25665 Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 12,258• 6,081' - 12258 6081 3000psi NONE 8797 Casing Length Size MD ND Burst Collapse Conductor 80' 16" 121' 121' Surface 4,439' 95/8 4,481' 3,473' Production 9,165' T' 9,196' 6,380' Liner 3,455' 23/8 12,258' 6,081' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3.500" L-80 8,862' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): PACKER = BAKER FHL PACKER 8735 MD and 6014 ND SSSV = NONE N/A 12. Attachments: Proposal Summary Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service p ' 14. Estimated Date for 8/15/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ El ' WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Alex Trower Contact Name: Alex Trower Authorized Title: Sr. Petroleu Engineer Contact Email: Alex.J.Trower@cop.com 7 Contact Phone: (907) 263.3733 /31 Authorized Signature: (.`rte Date' I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I 3 SS Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test v❑ Location Clearance ❑ Other: �C/ Post Initial Injection MIT Rei Yes CJ RBDMSL AUG t 6 2019 No El��// Spacing Exception Required? Yes ❑ Subsequent Form Required: �— 4O No d O T APPROVED BY ApprovedW,9� COMMISSIONER THE COMMISSION Date: �Il�ll lINAL F 10-403 Remed 4/2017 Approved li a o is valid for 12 months from the date of approval. Anachments in Duplicate ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 July 31, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 2E-17 (and associated sidetrack laterals Ll and L2) from Oil Production to Water Injection Service. The subject well was drilled as a producer but it has never produced; instead i remained suspended without completion until workover and sidetrack operations this year (see attached Proposal Summary for detailed well history). Enclosed you will find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. KRU 2E-17 (PTD 193-174), 2E -17L1 (PTD 219-054), and 2E -17L2 (PTD 219- 055). If you have any questions regarding this matter, or need further documentation to support this conversion, please contact me directly at (907) 263-3733. Sincerely, Alex Trower Senior Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry applications Proposal Summary AOR Detail AOR Area Map Well Schematic Multi -Lateral Schematic 2E-17 DESCRIPTION SUMMARY OF PROPOSAL Area of Review 2E-17 (Subject Well) Kuparuk River Unit 2E-17, originally drilled as a producer, was left uncompleted and in Suspended status due to oil quality concerns identified in initial core analysis. It is the view of our development team that this poor -quality C -sand pay exists in localized patches, and in offset wells we've had success using CTD to extend the wellbore into areas with mobile resource. This was the intent of the recent sidetrack performed on this well (the addition of L1 and L2 this year) —to exit the tarry C -sand in the immediate area surrounding the 2E-17 parent bore and provide much-needed injection support to two Kuparuk producers to the northeast and southwest. The top of C -sand was encountered at 8808' MD (6072' TVD). The top of cement was determined by CBL to be 7950' MD (5474' TVD). As work has been done on 2E-17 over the past year we've confirmed integrity of the inner and outer annuli, and a state -witnessed MIT -IA will be performed once the well is converted to water injection. i The attachment "2E-17 Final CTD Schematic" helps to illustrate the lateral arrangement of 2E -17L1 & L2. There is a fish just outside the casing window, and because of this fish one of the laterals (1-1) remains unlined. We are able to flow through and around this BHA and as such we do not expect it to impede injection at this time. 2E-06 The only other well within the % mile radius area of review is producer KRU 2E-06 (and specifically its northern lateral 2E -06L1). This well shares a similar history to 2E-17, in that after initial drilling, oil mobility concerns prevented immediate completion & production. After CTD in 2014 it has produced via primary decline. We hope to deliver support as soon as possible with water injection from 2E-17. Top of C -sand in this well was encountered at 10216' MD (6071' TVD). A CBL run during initial completion determined the top of cement to be 9310' (5413' TVD). It has exhibited no integrity problems since completion and is currently producing. Please see the following table for additional detail about cement operations and mechanical integrity for the two wells in review. Each has two sidetrack laterals which are included on the subsequent lines below each parent bore with additional detail where possible. ■ -J t 2 - ! (E ! � t £ § \ \ \ } 9 ; ' \ 6 \ \ \ \ ADL025658 T11NR9E T10NR9E N 0 0.1 0.2 0.3 oMiles ConocoPhillips Alaska 2E-17 Injection Analysis 7/24/2019 17 WEV14 Well Paths — Well Trajectory 2E-17 Open Interval 2E-171-1 Open Interval 2E-171-2 Open Interval �E-17LVB1 Open Interval 2E-17L1P82 Open Interval �2E-17LYB1 Open Interval W 11--17AL1 W G ry Z r- 111NR1UL T'IONR10F ADL025664 z Well Open Interval 1/4 Mi Buffers Q 2E-17 01 114 Mi Buffer Q 2E -17L1 01114 Mi Buffer Q2E-17L1PB1 01 114 Mi Buffer 2E -17L1 PB2 011/4 Mi Buffer O 2E-171-2 011/4 Mi Buffer Q 2E-17L2PB1 011/4 Mi Buffer I Other Wells Active P&A'd Gravel Footprint CPAI Lease \ H !,(2 _ 2 2; |mm z!a \ 2 ! \ H Loepp, Victoria T (CED) From: Trower, Alex J <Alex.J.Trower@conocophillips.com> Sent: Monday, June 24, 2019 4:58 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 2E-17, 2E-171_1, 2E-17L2(PTDs 193-174, 219-054, 219-055) Conversion to WI AOR Required Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria, Wanted to let you know we're working on it — Our drilling group hadn't completed their QC of the final surveys so we're waiting on that, and now our mapping expert is on vacation! Please bear with us..... Thanks, Alex Trower Drillsite Petroleum Engineer ConocoPhillips Alaska 0:(907)263-3733 C:(785)691-6746 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, June 19, 2019 3:06 PM To: Trower, Alex J <Alex.J.Trower@conocophillips.com> Subject: [EXTERNAL]KRU 2E-17, 2E-171-1, 2E-17L2(PTDs 193-174, 219-054, 219-055) Conversion to WI AOR Required Alex, The two laterals were recently drilled as development wells. To convert these three wells to water injection will require a separate sundry for each well. Included in the sundry must be an AOR. We can use the current sundry 317-301 for the motherbore 2E-17 conversion to WI but you will need to submit two more sundries for each of the laterals plus the required AOR analysis for each. If you need guidance on the AOR analysis, let me know. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoePP(&alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Monday, July 29, 2019 11:41 AM To: 'Alex.J.Trower@conocophillips.com' Cc: Loepp, Victoria T (CED); Schwartz, Guy L (CED); Boyer, David L (CED) Subject: KRU 2E-171_1 (PTD 219-054; Sundry 319-355) and KRU 2E -17L2 (PTD 219-055; Sundry 319-354) - Additional Information Needed Attachments: 187-026 Sundry_Application_Convert_Producer to_WINJ 20170614.pdf; AOR Guidance Doc.pdf; MPU K-09 Well Summary.pdf Alex, I'm following up on a June 19, 2019 email sent to you by Victoria Loepp that requested additional information regarding conversion of KRU 2E-17, and associated lateral well branches 2E-171_1 and 2E-171-2, from production to water injection. The three Sundry Applications provided by CPAI are deficient, and they cannot be processed without additional information. Please review Regulation 20 AAC 25.402 with specific emphasis on subparagraphs 20 AAC 25.402(c)(15) and 20 AAC 25.402(e). Attached are three documents that will also aid you as you compile the required information: an Area of Review guidance document, a similar application submitted by CPAI in 2017 for conversion of KRU 310-06 from production to water injection, and an excellent well summary provided by BP for conversion of a well at Milne Point. Please present the information for the wells that lie within the Area of Review using the spreadsheet format shown in CPAI's 2017 application. Please let us know if we can help further. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. Area of Review Guidance The Alaska Oil and Gas Conservation Commission (AOGCC) is issuing guidance to all Alaskan oil and gas operators regarding permit requirements for all injection wells, including those involved in disposal, storage and enhanced recovery service. Please ensure copies are distributed to all persons with responsibility to prepare applications for permits to drill in your organization. All injection wells, including disposal, storage and enhanced recovery injectors, must be constructed and operated in a manner that prevents the movement of injected fluids into sources of freshwater'. An important aspect of evaluating the risk associated with a proposed injector is the identification of all potential conduits within an affected area of the receiving zone that may allow fluid migration. AOGCC regulations at 20 AAC 25.252 UNDERGROUND DISPOSAL OF OIL FIELD WASTES AND UNDERGROUND STORAGE OF HYDROCARBONS, and 20 AAC 25.402, ENHANCED RECOVERY OPERATIONS, define the specific area of review (AOR) for a proposed injector as a'/4 mile radius surrounding the subject well bore. Both regulations are designed to, within the AOR: a) compile a comprehensive inventory of all wells and borings , b) assess the mechanical condition of each well that has penetrated into the receiving zone , and c) prove that all wells, regardless of operator, are that are a possible means of injected fluid migration have been properly repaired, plugged or otherwise modified to prevent such movement. [***Note — UIC regulations at 40 CFR 146.6, "Area of Review", require not less than %4 mile fixed radius around a well, and not less than the project area PLUS '/4 mile lateral distance from the perimeter beyond the perimeter of the project; our regulations do not specifically speak to the AOR for an area injection order.] The'/4-mile AOR is measured from the point at which the injection well penetrates the base of the confining layer (top of the injection zone). An application for a disposal injection order, area injection order, permit to drill for a new injection well, or a sundry application for the conversion of any well to injection service must include the following information within the AOR: (1) a plat showing the location of each proposed injection well, abandoned or other unused well, production well, dry hole, and other well within; (2) a list of all operators and surface owners; (3) an affidavit showing that the operators and surface owners; Freshwater is defined as having total dissolved solids concentration less than 10,000 mg/l and occurs in an non -exempted stratum, or occurs in a stratum that serves as a source of drinking water for human consumption; 20 AAC 25.990(27). (4) an analysis of the mechanical condition of each well. This analysis will, at minimum, consist of a review of the planned and actual casing and cementing programs. These data will be used to infer if the subject wellbores are adequately cemented through the proposed injection zone. All additional information relevant to either the pressure integrity or zonal isolation of the subject wellbore, such as cement quality logs or casing pressure tests must also be included; (5) an analysis of all existing wells and borings, including water wells, , assessing the probability that they may serve as fluid migration conduits. This analysis will require the integration of seismic, drilling, local stratigraphy and reservoir surveillance data as described above. The mechanical integrity of those portions of wellbores that have some probability of experiencing injection related pressures must be demonstrated as in item (4) above; (6) the delineation of faults within the injection zone from seismic data, and an assessment of the faults ability to serve as migration conduits; (7) a search of drilling records from wells in adjacent injection patters for anomalous subsurface pressures or kicks that may be injection related; and (8) an assessment of the injection conformance (performance?) of other injectors in adjacent patterns or areas of the same field. You are cautioned that the Commission will not act upon an application unless there is sufficient information included to demonstrate an AOR as described above has been performed. . W STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 &IVED JU0 S017 AbG C 1. Type of Request: Abandon Plug Perforations ❑ Fracture Stimulate Repalr Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Reddll ❑ Perforate New Pool E]Re-enter Susp Well ❑ Alter Casing ❑ Other O)to IN ❑� 2. Operator Name: 4. Current Well Class: S. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 01 Stretigraphic ❑ Service c 187-026 3. Address: 8. API Number. lop 50-029-21707-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NIA KRU 3M-06 i Will planned perforations require a spacing exception? Yes 0 No 21 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25521 I(upamk River Field/ Ku aruk River Oil Pool . PRESENT WELL CONDITION SUMMARY Total Depth MD (ft)'. Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): B,16By 7%0 ' 0?1 r 7-a6M;331 r 6.469" (�3W r. 3000 None None Casing Length Sim MD TVD Burst Collapse Structural Conductor 77" - 16" 115' 115' 1640 670 Surface 3,490' 9-718" 3,527' 3,714' 3520 2020 Intermediate Production 7,394' 7" 7,429' 6,567' 14980 4320 Liner Perforation Depth MD (8): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (it): 7132-7142, 7155-7180, 6204-6212, 6223-6243, 6248-12.875" 1 J-55 7041' 7186-7190 6251 Packers and SSSV Type: Packer- Carrico HRP -1 -SP Packer Packers and SSSV MD (ft) and TVD (ft): MD = 7011 , TVD = 6106 and Campo TRDP-IA-SSA safety VLV MD = 1800 TVD = 1800, 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigri phic ❑ Development ( Service 14. Estimated Dale for 6/15/2017 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑+ GSTOR ❑ SPLUG ❑ 16. Verbal Approval Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Hilaire Yemeli-Gozon Contac Name. Hilaire Yemeli-Gozon eli-gozonCCOP.co Authorized Title: Petroleum Engineer Contact Email: hilaire.yemm / Q O6 0p V/9 Contact Phone: (907)285-1478 Authorized Signature: p/�• Date: COMMISSION USE ONLY Conditions of approval'. Notify Commission so that a representative may witness Sundry Number. 3 t-7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑jf.. b Il�1 It� Other. Post Initial Injection MIT Req'd? Yes No ❑ RBDMSL, JUN 16 2017 Spacing Exception Required? Yes ❑ No Q' Subsequent Form Required: 7 APPROVED BY COMMISSIONER THE COMMISSION Date: Approved by. / Submit Form antl form 10-403 Revised V2017 Approved application Is valid for 12 months from the date of approval. Attachments m pupllcale ORIGINAL ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 May 26, 2017 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, RECEIVED JUN 0 S 7.017 ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3M-06 from Oil Production to Water Alternating Gas Injection service. 3M-06 was drilled as an injector and had been injecting from May 51h, 1988 to January 14, 2016 when it was shut-i�n_a�low back operations started 7/14/2016 for reservoir pressure management ahead of Enclosed you will find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3M-06 (PTD# 187-026) If you have any questions regarding this matter, please contact me at 907-265-1478. Sincerely, Hilaire Yemeli-Gozon Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary AOR Detail Area Map Well Schematic 1 M 3M-06 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 31VI-06 (PTD# 187-026) from oil production service to water injection service. Area of Review KRU Well 3M-06 is waiting to be converted to dedicated water injection to provide injection into the reservoir to increase the ultimate recovery of oil. 3M-06 is anticipated to support 3M- 05 and 3M-14 ifi The top of the A sand was found at 7,126' MD / 6,199' TVD Area map with % mile radius around target injection zone (see attached) The map attached shows that except for the offset producers 3M-16, 31VI-13 and 3M-05, there are no additional production/injection wells located within a''/e mile radius of the 31VI-06 penetration of the Kuparuk interval Mechanical Condition of the Well to be Converted The mechanical condition of Kuparuk well 3M-06 is good and is classified as a "single casing" well. The injection tubing/casing annulus is isolated via Camco HRP -1 -SP Packer located at 7,011' MD (6,106' TVD) A State -witnessed MIT -IA will be performed once well 31VI-06 is converted to water injection, online, and stabilized CBL and interpretation of the cement quality The intermediate casing CBL indicates sufficient formation bond (5,300'-7,312' MD / 4,825' — 6,341' TVD) The CBL interpretation was completed on the PTD's. • The 16" conductor was cemented with 198 sx CS 11. • The 9-5/8" surface casing was cemented with 1100 sx AS 111 & 350 sx Class G. • The 7" production casing was cemented with 300 sx Class G & 175 sx AS I. • n LJ Top ofA PTD API WELL Top of A-sand Sand 011 Top o1 Top of Top of Cement Resemir rs Zonal Cement Mechanical NAME STATUS Oil Pool IN Pool Cement Cement Determined By Status isolation Operations Integrity (NDSS) (MD) (TVDSS) Summary CAMCO 2 16" Casing 198 sx 10/18/2016: 7/8" HRP- C511, 9-5/8" (WC): MITOA Peds open 1-SP Retr. Casing 1200 Sx CS to 1800 psi 187-025 50-029.21706 310-05 Producing 8664' 6165' 6200' 4604' CBL for Pkr48K III & 325 Sx Class (Passed). TIFL production Pull or Ret G, 1005x CS 11, 7" (Passed). release Casing 400 Sx Initial T/i/O= 5.98]" OD, Class G and 175 150/1275/122 2.347° ID Sx CS I S. 12/21/2015: (Pre RWO) FT CBLTOC 16" Casing 200 sx LOST POT 7900'& 0511,9-5/8" (PASS)T Perfs open Packer@ Casing 1700 Sx CS PPPOT(PASS) 187-040 50-029-21720 3M-13 Producing 9283' 6212' 7900' 5200' CBL for 9181. (less fit &4005. Class IC POT (PASS) production than 200' G, 7" Casing 3SO T from top Sx Class G and (PASS) 5) M ITOA Part) 175 Sx ASI 1800 PSI (PASS) Initial T/I/O =si 16" Casing 200 sx 7/14/2016: C511, 9-5/8" Non- Part$open CAMCO Casing1450Sx A5 witnessed MIT 187-053 50-029-21728 3M-16 Shut-in ]601' 6222' 4,900 3,]62 [8L HRP-1-SP III &4005. Class IA Passed to for injection PACKER G,7"Casing 300 1810 psi. Sx Class G and Initial T/l/0= 175 Sx CS I 25/35/0 • n LJ ADL025522 TI"3NR8E ADLO26523 Well Trajectory Well Open Interval OQuarter Mile Open Interval Radius Wells within Open Interval Radius uCPAI Leases n ADLO25512 T13NR9 ADLO25521 N A 0 0.2 0.4 f Miles 311-15 ConocoPhillips Alaska, Inc. 3M -O6 Injection Swap Analysis SY1812017 KUP PROD ` 3M-06 - -- e 41ea � Max Angle 8 MD TD Alaska. km. w.rE,p,.Apvewl n.awm. .n6pu saN lnxel AA Bun XI7A 5002921)0]00 KUPARUK M'ER UNIT PROD 4L12 5,60000 ],4650 LcmmY�l x$S 1ppml Dale SSSV: TROP 2,900 110712016 AnnMlan Ene ptlp Last WO x6GN IN xl MMut aY 39]1 v4nWIBB7 314W.aiVMVlsaax PM MnMBlian "'s"sK8) EM OaIa LIM Tag: SLM ],2230 1'Y142016 Cptl Moe By EnJ DBY Rev geamn: H23 yymven b1N201' CONDw.nbron OG Pn lorynl Top InN81 SpI CBpu 1XNN IOppu ... wuun I_ G Top Tn.w CONDUCTOR 16 15.062 78.0 115.0 115.0 6250 Hd0 WELDED SUR, D^tnlpllvn Op 1101 ID pnj Top InK31 SlOpin 3510.pu ., WVwn I... Gny Lop Tnnatl SURFACE B 96 8.921 31 0 3,5285 3,799.5 36.00 Y55 BTC Wnp Gnolplbn pB 1101 ID 1101 Top BI SI ApMI 1 Spl GopM llVOj.- WULBn II... J-55 Tpp lnro0 PROWCTpN ] 61]6 35.0 )436.9 6445.2 26.00 J-55 STC Ub e u nv am pups slnnp xB_. Io O.1 op 0x81 Ml bpm n.. s.l spm (rw1 ... wl Vexl Gne EUEednpnlen TUBING 2)9 2441 329 ],041.8 6,131.) 6.50155 EUEBNABMOO coxpucrpx', ]a Bllap Com tlan Ds411a NM0.1 iop lXxO) Tap(NG) IxBI TPo iM I'1 Ilam Bpt EE ryn) 2.g 32.9 .12 HANGE NGER 75 1.799.8 1,]998 AFETY VLV SSA BAFEIY VALVE FX4LSLKIRA vsBA 1.,. 69944 6093.0 46 SBR 2.312 NVeTWGRE7TMnUMNrUR ]0109 B,t 3642 P N R PA K R 2347 ],0296 6,1214 3fi.36 NI L NO GO 2't5U 7091.2 6130.] 38.33 SOS SUB 2.441 cu 2 pW a Omer In Nob M91krow retHe3nbN s; vs pump., fish, ata Top RVtry Tppmd Tpp mKN xe D.. cpm am BXu mill 1,]88.0 1,)99.0 032 FMC 233.190 SLEEVE IOAl BT 110 180') 111/1799 1800 SLEEVE Perforations E Slats - 6Xol MN 9VSFnC E; ]]pa5F3 Tpp lnxal Bon -lU T,iIsm IT.2 BIm-) 1ry.21 Som Is. ti 11 TRF C. ,1 8.212. 3, 3M06 7l /1 I 17 10 1p RF deg. pNsln9. 0' 55. 1 .0 6, 6,2{29 9 M00 7]6119.1 IO IPE [180 ap Gun EAS LIFT 4,03 1 .1900 6-247-78 6.2510 A1. M-06 ]/611.1 10 WERF 100 4' G..PxaanB, C, G.. Mandrel Inserts mTe ..LIT. 13.111- s1 Bn H TpI...I VBIw LeYX Po,I SIv R(Oeun T iop IM1NBI 1Xxm NOYt opal ODBnf Bpry T Po M 1pt1 quneW Cem Dna w1.3n41 2. 27. ,3264 AMCO 1 DMY• B -2 0.000 0. ]a1H9B] 3,954.3 3,)366 A eM 1 LIFT B -2 0.0 00 7/809.1 3 4,903. AMCO M i MY -BC2-- 4 5, i 4, D5�1 KBM3 I GAS LIFT .2 D900 0.0 ]181107 cAS Loi1TeJ 5 5. 84 A O )GAS[ pW 0.0771887 ,1 .8 5,4548 CA Mp t LIFr pMy .2 00 00 71 117 6552. 5, MCO -KEMG- 1 GASLIFi DMT 3-20 DA ]/8119.1 .11111T ..I- B 8940.8 60M3 nTIS LB 1112 0000 9 71611967 Notes: General a Safety fine Dn•M.wrMn G 0.4LIFi,eW B• n 1 N 7E. viev, sffalnBnCwl a.SFa smaTBllm.D pwtnEA; >.DID.B NIPPLE:)p7B• iGEPi: ].Ia3 C LI.]A NCNp; 7199 D)IGpp� IPEai',I,ISXO],ImA- W CO V CigN, .15 Ol,T4H Area of Review - Milne Point K-09 (PTD #2050140) This Area of Review is required prior to the conversion of well MPK-09 from a producer to a water injector. This AOR discusses wells within '/4 mile of the well's entry point into the Kuparuk Formation to the bottom of MPK-09 well bore completion. One other wellbores, MPK-17, enter the Kuparuk formation in this area of review. The tables below illustrate the wells within the AOR, distance from MPK-09, completion details, and annulus integrity/cement conditions based on in-depth review of each well. ���i1g:QifiFtIYYIZ�)�IIt)• TOC estimated at 4900' MD; Segmented Bond Log 1996 Table 1: Table showing distance & annulus integrity of wells within AOR Welt Name Casing Hole Vol. of Kuparuk depth (MD) Kuparuk depth (TVDss) Size Cement MPK-09 7" 8-3/4" 22 bbls 7200' 6734' WOK -17 7" 8-1/2" 56 bbls 6887' 8733' Table 2: Completion Detail Well MPK-09 (Permit # 2050140) enters the Kuparuk formation at 7200' MD. A 9-5/8" intermediate casing was run to 5173' MD and cemented to surface using 550 bbls of "AS -Lite" and 46 bbls of Class "G" cement, returns of 210 bbls of lead cement were seen at surface after the plug bumped. The 9-5/8" casing was tested to 1000 psi for 30 minutes after bumping the plug. A 7" production casing string was run from surface to 7908' MD. The production casing was cemented with 22 bbls of 15.8 ppg class "G" cement. Plugs bumped with floats holding, and the estimated top of cement is 7198' MD. The 7" production casing was tested to 1500 psi for 30 minutes prior to drilling out the float and the shoe track. A 4-1/2" combination slotted and blank liner was run to TD at 9057' MD, after running the liner and setting the liner top packer a pressure test was performed to 1500 psi for 15 minutes. Although no cement bond log was run after the cementing operation, we are confident that there is competent cement isolation on both the production and surface casing to facilitate a conversion from producer to injector. The well has uncemented slotted liner across the Kuparuk C sands. Well MPK-17 (Permit # 1960280) was completed in May 1996. The completion crossed the Kuparuk formation at 6887' MD. A 9-5/8" casing string was run to 3508' MD and cemented with 740 SX (287 bbls) of 12.0 ppg Type "E" Permafrost and 250 SX (51 bbls) of 15.8 ppg class G cement. A top job was pumped down the 9-5/8" casing to bring the cement top to surface using 96 SX (37 bbls) of 12.0 ppg Type "E" Permafrost cement. A 7" casing was run to 7463' MD and cemented with 285 SX (58 bbls) of 13.1 ppg class G cement with Silicalite. A segmented bond log run in March 1996 showed good cement up to 4900' MD. Figure: Map showing wells within 0.25 mi radius from MPK-09. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS / 20 AAC 25.280 JUL Z J 9.19 A 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubi ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter C ing ❑ Other: Convert to WINJ O 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Developmen p Stratigraphic ❑ Service ❑ 219-054-0 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22419-60-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2E -17L1 Will planned perforations require a spacing exception? Yes ❑ No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25658, ADL 25665 ' I Kupa k River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUM ARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TV MPSP Si): Plugs (MD): Junk (MD): Li 12,258' 6,061' 12256 6081 300Vp i NONE 8797 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 1' 121' Surface 4,439' 95/8 4,481' 3,473' Production 9,165' 7" 9,196' 6,380' Liner 3,455' 23/8 12,25 6,081' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tub' g Size: Tubing Grade: Tubing MD (ft): WA N. I L-80 8,862' Packers and SSSV Type: ackers and SSSV MD (ft) and TVD (ft): PACKER = BAKER FHL PACKER 8735 MD and 6014 TVD SSSV = NONE WA 12. Attachments: Proposal Summary El Wellbore chematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Skate ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service E ' 14. Estimated Date for 8/1 2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ Q WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: YJ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is tru and the procedure approved herein will not be deviated from without prior written app val. Authorized Name: Alex Trower Contact Name: Alex Trower Authorized Title: Sr. Petr ieu ngineer Contact Email: Alex.J.Trower@cop.com i�Z� Contact Phone: (907) 263-3733 / � Authorized Signature: {1.-� �� Date: 1 COMMISSION USE ONLY Conditions of approval: Notify Com ssion so that a representative may witness Sundry Number: 31G- 355 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Ei Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: O R[ G I N A L Submit Form and Form 10-403 Revised 4/2017 Approved application is valid or 12 months from the date of approval. Attachmants in Duplicate k I 12�ADL025658 a E T11NR9E m i ~ o �bgMt � ADL02565 F T11NRIOE; _ T16NPE T10NME � q F g� n A eml I vt� .Irk ADL 2 6 w ADL0M" c� Fo gx 't1 N (I03 YMIWte wlowb INYIBWMa ak�vMk Milm —w.lri.ewr mal �xFReIIMul3uXn —aw. �xc-n opmw.a xxnrualnueuw .. read Co1104fiillip5 �xE•nu qin uuw xxnnlrel of lona&, -MwIFwlryiN A� �]Strl]epen Xeml fflrllPOlq IHMi Buk� F-1 Ilea 2E-17 �Etntrel er.rm.,e Qavuoiwukn� Injection Analysis ��^n'>azeaelmaa �xElrwelaluwkok �x.In:relopoml..0 KUP IN' WELLNAME 2EA7 WELLBORE 2E-17 G/�a�/�/�/�r'� k'� ,.'- Well Altriblrte: Max Angle 8 TD W ocoPrlil6P5 We Name Wellbre APN W WellMles tun ncll'1 MDI KB) Blm KB1 AlBxka.Inc. KUPARUK RIVER UNIT 500292241900 INJ 800 6,16].39 9.2060 3E-11,.11224e7PM Last Tag Vshd vAxlle(e (eeEun Annotation D1mh INKm End Data WNIWR "a MOs By EAST TAG 2E-17 crest NANGER, sso- Last Rev Reason Annotation End Oab Wellbore "St KI By Rev ReasonDummy of gas lift string 6/19,,019 I L-, linanseno Calling Strings eaeina Daaortpllon OD lml ID lml Top InKO) selneyln lnxa) sa Depin ITVDI-. wvLen O._c,eee Top Thread CONDUCTOR 16 15.06 4t5 121.0 1210 fi2.58 H-00 WELDED Casing Douviinown 00(m) IO(In) Top 1.1 Set Dwatepkel 9N DarralIv01--wD'Len 11-111saa Top Is. SURFACE 9518 692 41.5 4,4808 3,4733 36.00 JI BTC Can, DaFOrlptpn OD 11.) ID 6p Top MKB) .10 Mpeel 9N base II v.,.. it 11... Gblla Top Tnms4 COND..,euro PRODUCTION ] 6.28 416 9,207.0 26.00 L40 BTC -MOD Tubing Strings Tvbmg Deampeon sumo Ma... lD(,n) Top(flK0) set Depe(n.. aet Depe(rvD)L..wl(dvn Grana T, Connaenon GAS LIFT: Zen.a TUBING- 3112 2.99 266.0 6861.8 6,1149 9.30 L-80 EUE8RM PRODUCTION Completion Detalls mP ITVD) lbpina Nominal TopprKIN (nMB) I.1 been Des Com mlml 26.0 260 D.00 HANGER Cameron CXS Tubing Hanger Q 1116• x 312" EUE BRM BxP) 2.992 Q001.1 3741 LOCATOR Locatca Sub, Baker (-3'of spamou0 2,992 CURFACE. 41 NpB] 8� 8,7218 6,OD3.5 3740 SEALASSY Seal Assembly, Baker, 8040 2.992 .9 6,014.0 3740 PACKER Baker T" x 3-112" FHL Packer, 2.992 GaSLIFT:4.8m] ,]88.0 Q056.2 37.34 DINDIN HES&112"x2813" XNipple Profile- 2.813 NIPPLE 8,804.0 6,069.0 37.37 OUTER WEDGE NoMern Solutions 3511-700 Outer Wedge 2.990 GASLIF7,eH0.8 8.818.1 6,080.2 37.39 IANDIN HES 3-112•x2813"X Nipple Profile - Blkedock 2.813 NIPPLE 8,8239 6,084.8 37 39 WEDGE I Northern SOIUgDn5350-700 Outer Wedge 2.990 fins LIFT: ],S+flS 8,8379 6,0959 3].36 LANDING HES 3112•x2813"X Nipple Profle- Bakerlock 2.813 NIPPLE 8,849.1 6.104.8 7.5 casing scraper 2510 IGAEINUTrailblazer SCRAPER 8,8600 61134 3733 1 FLOAT SHOE Float soca 299 GAS LIFT: a.Yd3 Other In Hole (Wireline retrievable plugs, valves, pumps, Rah, etc.) Top(TVD) Top incl TOP (ince) Me) P1 Da. Com Run Dare I.p.) 8,7920 A 7. ish TD IL oiluak dnllrnp BHA. S1Uc in windowwie Tan 52312019 TRACK BHA top 615 LIFT, a,618 8,8070 60714 37.38 WHIPSTOCK NORhem1n FITOTive, Wedge W1 RA Toga S' 51512019 from lop. DAL 12'max on 2.625 8,818.1 60802 37.39 77771slos, 2.81' Xbook new Dal flow Nm sub 51512019 17 Thru Sub LOCATOR:18.7188 682].0 608]. J. WHIPSTOCK NoMem luon Inner Wedge WI 3 RA Togs 5' 41912019 smatiaY; e.Tre from top. DAL 12 max od 262F PACKER:6]Y9 8837.0 6095.2 J. X -LOCI, Flow 2.81" X4ock flow ad flow em sub d14201s .JW Thru Sub Mandrel Inserts st WIpNGNIPPLE'.EORD ab N Top PVD) Valve labs PoltSW TRD Run Top(ttl(B) IME) Make Madel Cobb) Ser, Type Type Pn) (ass) Run Dwe Com 1 28738 2,498.4 Camoo MMG 1112 INJ DMV RK 0000 00 611&201 2 4,8832 3)08.] Comes MMG 1112 INJ DMV RK 0000 0.6 &1&2019 3 6,402.8 4,541.4 Cameo MMG 1112 INJ DMv RK 0 WO 0.0 1611712019 OU RWEDGE.S.e D 4 7,518E 5,2020 Cameo MMG 1112 INJ DMY RK O.D00 00 &1712019 Willpa k.. e.roao 5 8,2293 5,650.0 Cameo MMG 112 INJ DMY RK 0.000 671772019 6 8,6627 59567 Cameo MNG 1112 INJ DMY RK 0.000 D. L.......H IANDINGNWRE:B.Bta1 Notes: General B Safety End Dale ..a... XA Rwx Da, suDssb81 41212019 NOTE: view schematic Dal Alaska SchergmeI U.0 OUTER WEDGE: B.BDB WHESTOCK:B,BTO ran CTO COIL TRACK BI 8.60 X PYnvTIPaL B6's]0 Lex IRNDINGNIPPIE:&8318 CPSIN6 SCRAPER: els FLDATa OE:8.M,O PRopucTwN; blsa.mr.o 1 KUP IN " WELLNAME 2E-17 WELLBORE 2E -17L1 a�/��/W 8'�AL1,K`U= Well AtUihute; Max Angled TD ConociiPhillips APW1,11-1e Slitus ll•) MVIXKBj ACI BM II AJwk&IOC. RIVER UNIT 5002922411) INJ 9.60 9.140.81 122580 ar-17L1, 7R<Rn182:141e PM Last Tag WNwl aenemavc lxYW) Annotation OepNl (BKB) Entl 0. WeI11,ore Iasi MI By LAST TAG 2E -17L1 jennalt ----------- ----- Last Rev Reason XPNGER: R.O pnnoWgn End Cale WeIIWIe Iasl Matl By REV REASON. CTD Lateral ./10/2019 121,1JL1 )ennalt Casing Strings Ca sing Geaceiplion 100 (In) IIC (in) Trip (I Bn Geptn lw Bt BN OepIX ITV Ct... WIILen ll... Guide Tap TNIwE LI LATERAL (CTD) 12,258.0 6.0810 M CGNWCMR 4151210 GnB UFr; 287].4 BVRFACE; 41 a1,W B� Gab VFT', 488].2 W]ur,T 6,a02.8 G96 CFT', 7,51&] GAe LIFT; 8.28] CAS IF' a.21— LOCATM. 8.71&6 SFALASSV; 8.7216 i� IPNDING NIPPLE: 8.7&40 FISH CTD CaL TRACK BM B,BA PRODUOMM; 41,1110 Ll IATERA (CTC), 122x80 2 190 54 30 99 5 Letter of Transmittal EA (ER Date: 1-�UGHES July 15, 2019 aGEcompany i To: From: Abby Bell Harvey Finch AOGCC Baker Hughes, a GE Company 333 West 7'" Ave, Suite 100 795 East 94" Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2E -17L1 2E-17LiPB1 2E-17LPB2 2E-171-2 2E-17L2PB1 RECEIVES 1 L 16 2019 AOGCC (1) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com s Lo q"� C:) rn rn M r o CV M u C � a > LL, N w N cod Y Y IL i i J r0 R ti CL C1 7 :3 W Y Y 04 ob OWN R L LU z 2 W # _;_ t c u !!! f { _ 0 N i{{ E< - � of \\\»(\ \ \\\\ \7| o 3 j !! �. 2;0 / t c u |k! | !!! f { _ 0 N \\\»(\ \ \\\\ \7| |k! | f _ 0 N 0 V� C Y m < C � W 6 m d N N � W m m O x 2 c n v U Y Lh Y N N N d V L Ol m m w w 0 m a t m w w w ry� � g x c U U N O N N N m TiTill in n Z R �n in 8 0 pl OI O a N o�n o�n w m oop o000 w p?p? pp+�opp O N� P P 0o Np No f C y N p p p a N� N� � N ry ry ry N V % O Z❑ Z❑ N N m� O OUB P m 0 0 10 P C m � n UB r E (7U C m $ n ry ry > a n n W n n vmi umi N N N St % > 2 9 O > 2 > O L« � Oi pi T q Oi P P m T r T ONi A Omi 0� OI O� O� O = n N YI N V1 N N VI N J J Z Z o e v m m wr o m n 3 Ui m m E m % o ? x a n n m z _ol dz dz ': v 3 3 3 5 = j P q v1 N Yj N Y7 N YI ♦ r m m d d N d r d InO O 0 m N O m H ry 1�' r '& w N Yi `3i 2 m Q% b U W U W S n n n n n n n n n NN 2 NN Q52 m m m m om8�8 m' �;YmN m r f % N N N Lb N N O r O m rri m of W ai � � E o w m` O CI E Em � V O1 T D O O N W w T d� m O1 Oi T 9 Of OI % % N 2 190 54 30 99 4 Letter of Transmittal 010 Date: BA IGHES July 15, 2019 BAT GE company j From: Abby Bell Harvey Finch AOGCC Baker Hughes, a GE Company 333 West 7`h Ave, Suite 100 795 East 94" Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2E -17L1 2E-17L1PB1 2E-17LPB2 2E -17L2 2E-17L2PB1 j I REeE/VEL 16 2019 AOGCC (1) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey. Flnch(a7BakerHughes.com C) rn rn 0 N .M �J =rE Q:. o Wow m L a Y I v L ca O Q m w Vi z Q C LL •� Ui s Cl) 0. :Ew a a o d 0 d M _ > O v wNaN *� 0 Y Y r N L- O u C O i ��� a C'4 G1 L ca U YYcmLo m ■ �;; $ a!§§ \� W7{$ -- f§ '; §R;z;0Ci \)) ::/ / \\) ! \\\ \$! ! | ! ) _ w \F \I\\ ` \ /ii E 00 } - - ° \ƒ!||! �2a2 ] a ® § ; \\«\() l�[ \ < o G/ ` _!|)f§ )k2zm0 ` ,! [!B!B \\ j _ .�, CL §04 0 � .. .. « BA ER Date: FUGHES Duly 15, 2019 BAT GE company To Abby Bell AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 From: I� 2 190 54 30 99 3 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94' Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2E-171-1 2E-17L1PB1 2E-17LPB2 2E-171-2 2E-17L2PB1 RECEIVED JUL 16 1019 AOGCC (1) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com 1 M LA Q1 O O1 cn O r M N Mj a) O N d c co N Y 7 L CL V L w .�- a it Cl) V LLJ ^O i. 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M ni ri ri of ni m n of .;i m r t S P O m 0 m P m i0 � S n Nggl 0 O t0 S d m S A� M N O N< O T Q m � Imo C N fmD OI m m r f7 IOO P 0 V (NV N Imo b m S�� P M N Y' Z � Io m e m �c m m m Id m c6 m ro Id m m �u m 16 Io m Iv m m ro d e e b e m V C W qq yN� C 00 n `m a G m m m m ry INn INn In m m m in m In en m m m m m m m m w 2 K N f Q S 2 2 rIrp m 2 2 n �j v m 17i m R n S$ °�•• 0 0 m m Imp m T R O� 9 9 8 O+ 0 8 p8 R O� O� m S 2 0 0 m m m U Y Y N N N t0 0 0 mmn m a O Q Q Pp O P al O N p Imo (O O S N P P P O 0 m N tp IOO N p fl tm�l m P N m m p p m m 3 3 o u a m r t ; r ■ � ] (000000000 :se § < \\\!{j CL mak!!.00!!o !!!!! //! //!\(/---- )/2 „ k +! : R........... CL \\ O ■,■&■■«\\\ 4 _ BAj<FR { eFJNT DISTMUTION LIST UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. PTT��J•Put 2E -17L1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.RiderC@bakerhughes.com STATUS Final Replacement: COMPANY AD DRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Breads GWsmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxasMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 10M 219054 30 93 8 ;e sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 of this data. LOG TYPE GR - RES LOG DATE May 25, 2019 TODAYS DATE July 1, 2019 Revision Details: Rev. Requested by: FIELD/ FINAL CD/DVD I FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES V VV V V V 0 0 0 0 0 JUL 0 2 2019 0 1 1 1 1 1 0 10 5 DNR- Division of Oil & Gas *** 0 0 1 0 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. ,Anchorage, Alaska 99508 0 0 0 0 0 TOTALS FOR THIS PAGE: 0 1 2 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FREEIVED JUL o 2 20�19 WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil ❑�' Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: ib. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 6/1/2019 14. Permit to Drill Number / Sundry: 219-054 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 5/2/2019 15, API Number: 50.029.22419.60-00 4a. Location of Well (Governmental Section): Surface: 642' FSL, 160' FWL, Sec 36, T11N, R9E, UM Top of Productive Interval: 946' FSL, 1402• FEL, Sec 1, TION, R9E, UM Total Depth: 2568' FNL, 1936' FWL, Sec 1, TION, R9E, UM 8. Date TD Reached: 5/24/2019 16. Well Name and Number: KRU 2E-17L1/2E-17L1PB112E-17L1PB2 9. Ref Elevations: KBA46 GL: 105 . BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MDrFVD: N/A 18. Property Designation: ADL 25658, ADL 25665 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 529971 y- 5944285 Zone- 4 TPI: x- 533712 y- 5939325 Zone- 4 Total Depth: x- 531762 y- 5941082 Zone- 4 11. Total Depth MD1TVD: • 12258/6081 • 19. DNR Approval Number: LONS 84-029 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD1 VD: 1487/1462 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: • 9269/6097 ' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD AMOUNT CASING FT GRADE TOP BOTTOM TOP HOLE SIZE CEMENTING RECORD PULLED WT. PER SETTING DEPTH MD SETTING DM347312.25 16 62.5 H40 41 121 41 24 200sx CMT 95/8 36 J-55 41 4481 41 800sz 11.0 AS III, 600SX Class G 7 26 L-80 31 9196 31 8.5 275sx Class G 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVD of Top and BoUo�: fierfora}ion. Size and Number; Date ION:: N1 OPEN HOLE COMPLETION: � 18807-12258 VER �oF)E� _ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDrfVD) 3 112 8862 8736/6014 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: NIA Method of Operation (Flowing, gas lift, etc.): UNABLE TO PRE -PRODUCE AS PLANNED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10407 Revised 5/2017 U7_/_ N•TJ,NUED ON PAGE 2RBDMS &JUS 0 8 201�ub�m `RIG�.IN�� onlyl 28. CORE DATA Conventional Corals): Yes ❑ No ❑D ' Sidewall Cores: Yes ❑ No ❑J If Yes, list formations and intervals cored (MDlrVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� ' If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1487 1462 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9269 6096 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C4 2E-17L1PB1 / TPI 8827 6067 TD 8874 6125 2E-1711PB2 TPI 9286 6094 TD 9509 6106 ✓ TD 12258 6081 Formation at total de the Ku aruk C4 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolouicalr i n or wellI 7. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: :hames6ttlin erContact Name: Ryan McLau hlin Authorized Title: er LContact Email: an.mclau Klin co .com ��la>"d>2 Authorized J / q Contact Phone: 265-6218 Signature: Date: 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 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinhe 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 10-007 Revised 5/2017 Submit ORIGINAL Only KUP PROD WELLNAME 2E-17 WELLBORE 2E-17 C�������� +°�'' Well Attribut Max Angle T TD onoeoPh)ll)ps blO Nama Wmmre APUGvq W.IIWre51aNs MOO. act Blis 61 Alaska, Ina KLPARUKRIVER UNIT 500292241900 PROD 800 61fi73S 92060 W0: 3G -n. Tnlzmpl¢m:a AM Last Tag seeks vAwiu@Iec ) annotalbn ospin MR.) Ene Dake wNllcre laseMM ey LAST TAG: 2E-1] jennelt nPNGER;:uG� Last Rev Reason Annadlun Entl Dab Williams IastMWOy Rev Reason Dummy off gas lift string 611912019 2E -D linareeno Casing Strings case. Oexnplbn 00 (in) (in) TaP(XKB) Set D=PIn INR81 aM Depen IND)...wden(1...Gratle ToPTneeaE 11. CONDUCTOR 16 15.06 41.5 121.0 1210 62.58 H40 WELDED Cazinp Dexripmn 00 fin) ID9n) GMe Top T11w11 TopgIK81 BM"fies ie" SNDryM(ND)... WNen(I.IL-80 SURFACE 9L8 892 41.5 4480.0 34)3.3 3600 355 BTC i:CND11CTIXt: <1.Sfd1.0 Daziq Exemption Do I'm need Topda"d SNDepnfive" Set Degnros'" wuLen (1..G,Me Tep Tl,w] PRODUCTION I 8.28 41.6 9,20).0 26.00 L410 BTC -MOD cases, Dexamptlon OD (in) IDpn) Toilasse Set 31'l, fiane, SRI Depin Rod, Wn-p_Gretle TopTnreW Gas uTr', zerxe L2 LATERAL (CTD) 2318 1.99 9,286.0 12.9474 460 ED Tubing Wings Tues, 0e11rlgion alnnp Ma... IDlln1 Top IftRB) SRI Depen OL.SeIOroIn ITV01 r..WlDom) GrMa TOp Connectbn TUBING- 312 2.99 2fi0 :S'Rik 6,114.9 9.30 L -BO EUE8RM PRODUCTION Completion Details aos..: 11., a- '-p (win Topmcl Nominal 1.0mr(B) (ME) (°) Ilene Dee Core IO lin) 260 26.0 0.00 HANGER Cameron CXS Tubing Hanger 01116"x3112"FILE BRM BMP) 2992 Gss UE7.4 uz 0,718.6 6,001.1 3741 LOCATOR LucdlW Sub, Baker( -3' of speceouQ 2.992 0,721.6 6,003.5 3740 SEALASSY Seel Assembly, Baker, ROAD 2992 0,734.9 6,0140 3740 PACKER Baker ]"x3-112'FHL Packer 2.992 Gas uFr;&ooze 8. W T 6' '05T.72 37,36 ING HES 3-12' x 2 SIX X Nipple Profile- 2,813 NIPPLE 8, -6769-0 37.37 OUTER WEDGE NoMem Solutions 350-700 Outer Wedge 2,990 GAS UGT; elms 8,8181 6,080.2 37,39 LARITRI HES 3-1/2"x2.813'XNipple Profile - Bakedock 2813 NIPPLE 8,823fi 6,0048 3739 OUTER WEDGE Northern SOlulions 350-700 Outer Wedge 2990 GAS UFT. Baza.3 0,837.9 6095.9 3738 HES 3-112'%2.813"X Nipple Prefile - Bakeriock 2.813 NIPPLE 8,049.1 6104.8 37.35 CASING Trailblazer casing scraper 2.510 SCRAPER Gas LFTl&RE. 88600 61134 3733 FLOAT SHOE Floal since 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tap Me) rep mR1 TOP Frans) (Q) 19 Des coin Run Dm 10 (in) LDCATOR;8.7l&6 8)70 60634 37.36 Fish T ILollUsk 7TDdeilling BHA Stuck In window with 2" Ton 5,2312019 .721 S SEAACKEIR TRACK BHA Wp Cos. PACKER. &TaLB ,807.0 6,0714 3738 WHIPSTOCK NomemoFl Wl Inner Wedge RA Tags 5' 5/5/2019 1 from Wp. DAL 12 max ad 2.625" 8,1.1 SM 2 3739 -ock ovr 281"%flock Flow wl llow her sub 5612019 1.750 Tbre Sub DWOWGrvrvvLe.&vve.D 8, U77 =,7 3740 WHIPSTOCK NO em Solution Fl 3SO Inner Wedge W7 A aga 4192019 Done top. OAL 1Y max ad 2625" 8, ]. =.5, 37.38 Gw 281"X-lockflowwlflowthru sub 4/42019 1750 Tbm Sub OUTERWEDGE&e040 Mandrel Inserts re WHIPSTOCK',&Ba1.D BY H Top TWO) Tpp,873. F2,49 Make MG Were Lauri Pon Slze TRO 00 (m) Type (psi) Run Run Dab Co._ 1 kNevi Nir our &.18EHIII 2,8)3.8 2, 96. Gam. MMG 11 SLIFT DMV RK GOOD IFT IA 00 00 611 1Le 19 4,803.2 3,706.4 Dam. MMG 11 GAS LIFT DMY RK 0000 00 17 1 3 8,401.8 4,5914 dm. MMG Y12 GAS LIFT DMY RK 0000 0.0 9 1 OUTER WEDGE; 8 DOE 4 7,518.5 5,202.0 Cam. MMG 112 GAS LIFT DMY RK 000D 00 8/17/2019 verlvsioelk. 5 8,229.3 5,650.0 Cam. MMG 112 GAS LIFT DMV RK 0000 00 6117/ 019 Fxn mD wlLTRncnMe S,eO 6 8,662.7 5,9567 Camr. MMG 11/2 GAS LIFT DMV RK 0000 00 fill )12019 Notes: General B Safety x.x*F-TNu.wa.an.D VWMNG NIPPLE, e.6ar.9 End Dah gnndelbn 4/1/2019 NOTE. View Schematic wl Alaska Scbemalic10.0 CASIN08CMPERI&W90 FLOAT SHOE. BRW O 1 I 1 I PRODIYTIOH: 419$]N.0 iI 13LATERAL(CTO);&2ES.p. 1.9414- 2E-17 Ounent8chensafic 8518'3SIiJ85 aM1De ® 6181' MO y IDT Mo \ l �LdOiMeQ B196'MO 11rz' 9.311.80 SUE SN Taken te surface Y112' Camce MMG pas k8 mandrels @ 2876', 8853'. 8443', 751P.BMW, BEST RNS Sake, Locator @ 8718' WEI (3'.,.do Baker PSR 80.44 @ 8722' MID (3' 10) Baker FHL Pecker® 8735' MD (8' ID) 3-X' X lending, nipple M 8708 MD (2.813' min ID) Nanhem Solutions WEDGE (see details) Top of Wedge Assembly @ 8755' PIX 3-'A" X lantlln8 nipple al 8818MD (2.B13" ran ID) 3-X"X lancing, nipple at 8838' MD (2.813" irva IDI T,sRl er cadre a.,,Q BMW MD Float Shoe @ BPBP MD ll -Mem BUIWmu Weape 5805 OD( 128'bng) 'NT Total Lanpth D.625- Base thru IA 25- Bore ram Foer Sesctmn - ------ -.-_ nsmeemenw.r se.ow.eM 3E-f]13Va1 -1BiW ®ASae MO, tlpr 3EIIIPSI MD IT. 0aV7 MD Operations Summary (with Timelog Depths) , Ain, 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (fiKB) End Depth (flKB) 4/28/2019 4/28/2019 3.50 DEMOB MOVE DMOB P MOB to 2E-17 18:00 21:30 4/28/2019 4/29/2019 2.50 DEMOB MOVE DMOB P Peak trucks on location. PJSM. Pull 21:30 00:00 pits and sub off well. RID cellar 4/29/2019 4/29/2019 6.50 DEMOB MOVE DMOB P Complete cellar RID, Continue RD 0.0 0.0 00:00 06:30 checklist, Load up shop and halfway house and mobilize from 1C to 2E. Reconfg BOPE 4/29/2019 4/29/2019 0.50 DEMOB MOVE DMOB P RD checklist complete, hook up jeeps, 0.0 0.0 06:30 0700 ready to move, All trucks on location and made up, PJSM 4/29/2019 4/29/2019 7.00 DEMOB MOVE DMOB P Moblize rig towards 2E -pad 0.0 0-0- 07:00 1400 4/29/2019 4/29/2019 1.00 MIRU MOVE RURD P Arrive on location 2E -Pad, remove 0.0 0.0 14:00 1500 jeeps, prep well for rig, shut in 2E-06 4/29/2019 4/29/2019 2.00 MIRU MOVE RURD P Spot sub and pits over well, lay mats, 0.0 0.0 15:00 17:00 secure all landings and stairs. 4/29/2019 4/29/2019 5.00 MIRU MOVE RURD P Begin RU checklist, spot in tiger -tank 0.0 0.0 17:00 22:00 & MU hardl-line, begin NU POPE, continue BOP re-confg in cellar, MU PUTZ, secure rig location, spot warm- up shack, spot ramp and stairs at rig shop, 4/29/2019 4/30/2019 2.00 MIRU MOVE RURD P Configure test joint, swap out annular 0.0 0.0 22:00 00:00 bag, swap lower BOP rams. RIG ACCEPT 22:00 4/30/2019 4/30/2019 2.50 MIRU WHDBOP RURD P Remove riser change out all O rings, 0.0 0.0 00:00 02:30 Grease crew here to service tree. Grease all valves 4/30/2019 4/30/2019 0.50 MIRU WHDBOP BOPE P PJSM for BOPE test. Go over new 0.0 0.0 02:30 03:00 procedure with all hands. Run valve checklist 4/30/2019 4/30/2019 7.50 MIRU WHDBOP BOPE P Fluid pack. Obtain shell test Start full 0.0 0.0 03:00 10:30 BOPE test. Test Witnessed by Austin Mcleod, AOGCC, No fail/pass, Tested gas detection / good. Tested PVT /! good 4/30/2019 4/30/2019 1.50 MIRU WELLPR CTOP P PJSM, R/U CT hydraulic cutter. 0.0 0.0 10:30 12:00 4/30/2019 4/30/2019 6.00 MIRU WELLPR CTOP P Cut 2400' Coil 0.0 0.0 12:00 18:00 4/30/2019 4/30/2019 2.00 MIRU WELLPR CTOP P Epoxy a -line, pump back slack (2.7 0.0 0.0 18:00 20:00 bpm, twice), cut pipe to find coil (115' cut to find a -line, 2515' cut total), 4/30/2019 4/30/2019 2.00 MIRU WELLPR CTOP P Install CTC & pull test, re -head a -line, 0.0 0.0 20:00 22:00 PT UQC 4/30/2019 4/30/2019 0.90 MIRU WELLPR CTOP P PT tiger tank line & PDLS's 0.0 0.0 22:00 2254 4/30/2019 4/30/2019 0.20 MIRU WELLPR CTOP P Open master valve, 400 psi on MP 0.0 0.0 22:54 23:06 line, clear floor 4/30/2019 5/1/2019 0.90 PRODi WHPST PULD P PJSM discuss new PD checklist, load 0.0 0.0 23:06 0000 PDL, begin PD BHA#1 Wiindow Milling Assembly (0.4° fixed bend Weathrford motor, 2.80" NS string reamer & 2.80" NS window mill) 5/1/2019 5/1/2019 1.30 PROD? WHPST PULD P Complete PD BHA#1 Window Milling 0.0 77.0 00:00 01:18 Assembly (0.4° fixed bend Weathrford motor, 2.80" NS string reamer & 2.80" NS window mill), check pack -offs, MU to coil, tag up, set counters 5/1/2019 5/1/2019 1.80 PROD1 WHPST TRIP P RIH w/BHA #1 77.0 8745.0 01:18 03:06 Page 1134 Report Printed: 6/5/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) End DepAn (ftXB) 5/1/2019 5/1/2019 0.20 PROD1 WHPST DLOG P Log K1 for. -10.5' correction 8,745.0 8,796.0 03:06 03:18 5/1/2019 5/1/2019 1.00 PROD1 WHPST DISP P Displace well to milling fluid, PUW = 8,796.0 8,796.0 03:18 04:18 31K, close EDC 5/1/2019 5/1/2019 0.20 PROD1 WHPST TRIP P Continue RIH, dry tag WS pinch point 8,796.0 8,826.8 04:18 04:30 at 8827', PUW = 31 K, come up to 1.8 bpm 511/2019 5/1/2019 13.50 PROD1 WHPST WPST P Milling from 8826.8', FS = 785 psi @ 8,826.8 8,831.9 04:30 18:00 1.8 bpm, CWT = 15K, WOB = 0.6K, pump = 3674 psi 5/1/2019 5/1/2019 2.50 PRODt WHPST WPST P Crew change, continue milling from 8,831.9 8,832.6 18:00 20:30 8831.9', CWT = 13.6K, WOB = 2.5K, pump = 4169 psi, avg rop = 3.4 in/hr "Pre -load PDL w/ build BHA 5/1/2019 5/1/2019 2.50 PROD1 WHPST WPST P Milling window from 8832.6', CWT= 8,832.6 8,833.2 20:30 23:00 13,8K, WOB = 2.3K, dp = 1055 psi, avg ROP = 2.9 in/hr 5/1/2019 5/2/2019 1.00 PROD? WHPST WPST P Milling window from 8833.2', CWT= 8,833.2 8,833.4 23:00 00:00 13.5K, WOB = 2.6K, dp = 983 psi, avg ROP = 2.4 in/hr 5/2/2019 5/2/2019 1.20 PROD1 WHPST WPST P Milling window from 8833.4', CWT = 8,833.4 8,833.5 00:00 01:12 13.5K, WOB = 2.6K, dp = 941 psi, last two tenths slowed, increase WOB to 3K per NS rep 5/2/2019 5/2/2019 2.00 PROD1 WHPST WPST P Milling window from 8833.5', CWT= 8,833.5 8,833.9 01:12 03:12 12.4K, WOB = 3K, dp = 935 psi, avg ROP = 2.4 in/hr 5/2/2019 5/2/2019 1.80 PROD1 WHPST WPST P Milling window from 8833.9', CWT = 8,833.9 8,834.2 03:12 05:00 13.4K, WOB = 2.9K, dp = 900 psi, avg ROP = 2 in/hr 5/2/2019 5/2/2019 0.70 PROD1 WHPST WPST P Milling window from 8834.2, CWT= 8,834.2 8,834.7 05:00 05:42 13.7K, WOB = 2.6K, dp = 965 psi 52/2019 5/2/2019 1.30 PROD1 WHPST WPST P 8834.7 looks like BOW weight drop 8,834.7 8,836.0 05:42 07:00 1 1 off. Time mill for string reamer exit 5122019 5/22019 0.80 PROD1 WHPST WPST P 8836 Milling rathole, 1.76 BPM @ 8,836.0 8,845.0 07:00 07:48 1 3755 PSI FS 5/2/2019 5/22019 1.60 PROD1 WHPST REAM P 8845 End of rathole, Perform reaming 8,845.0 8,842.0 07:48 09:24 passes 15R, 45R, 15L, 165L, Dry drift @ 15R. Looks good 5/2/2019 5/2/2019 1.50 PROD1 WHPST TRIP P 8842', Trip for build section BHA, 8,842.0 77.0 09:24 10:54 PUW=28K 5/2/2019 5/2/2019 1.10 PROD1 WHPST PULD P At surface, flow check well, Lay down 77.0 0.0 10:54 12:00 window milling BHA#1 5/22019 5/2/2019 0.70 PROD? DRILL OTHR P M/U nozzle stab on well. Jet stack 0.0 0.0 12:00 12:42 flush surface lines of metal 5/2/2019 5/2/2019 0.80 PROD1 DRILL PULD P M/U BHA#2 Build section BHA with 0.0 72.2 12:42 13:30 2.5° motor. Make up to coil and surface test 5/212019 522019 2.30 PROD1 DRILL TRIP P RIH BHA #2, Shallow test BHA -Good 72.2 8,735.0 13:30 15:48 High bend motor finding many collars reduce tripping speed. Shut EDC and roll pump 5/2/2019 5/2/2019 0.10 PROD1 DRILL DLOG P Log Kt for -4' correction, PUW=30K 8,735.0 8,770.0 15:48 15:54 5/2/2019 5/22019 0.20 PROD1 DRILL TRIP P Continue in well 8,770.0 8,845.0 15:54 16:06 5/2/2019 5/2/2019 0.70 PROD1 DRILL DRLG P8845', Drill 1.86 BPM @ 3530 PSI FS, 8,845.0 8,874.0 16:06 16:48 BHP=3589, IA=O, OA=32, projections indicate low landing in build, confer with town, decision made to POOH for higher bend motor Page 2134 Report Printed: 6/512019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Pham Op Code Activity Cafe Time P -T -X Operation Stan Depth (WEI) End Depth(11KB) 5/2/2019 5/2/2019 0.50 PRODi DRILL DRLG T Become hung up in window, pull to 8,874.0 8,828.0 16:48 17:18 40K, -12Kk WOB, motor torquing up, unable to orient, attempt pumping at .25 bpm in &.25 bpm out, can circulate, drop pumps to not bind motor 5/2/2019 5/2/2019 0.90 PR0D1 DRILL DRLG T Pumps off, drop differential to -0 psi, 8,828.0 8,828.0 17:18 18:12 work pipe, unable to break free, attempt to orient TF at nuetral weight, unsuccessful, continue working pipe, WOB -12K to 6K, unsuccessful, turn orienter clockwise & work pipe, unsuccessful, rotate hot counter clockwise, work pipe, unsuccessful Begin working pipe down, 5/2/2019 52/2019 1.50 PRODi DRILL DRLG T Work pipe to -1 OK CWT, unable to 8,828.0 8,828.0 18:12 19:42 break free, rotate TF clockwise, work pipe down, unsuccessful, tear down micro motion to look for resin, clean, work down to -20K CWT, unable to free BHA Confer with town, decision made to release off tools & go into fishing OPS 5/22019 5/2/2019 0.40 PROD1 DRILL CIRC T PUW = 25K, circulate bottoms up 8,828.0 8,800.0 19:42 20:06 " BOT on the way with jars & hip tripper 5/2/2019 5/2/2019 1.50 PROD1 DRILL TRIP T POOH 8,800.0 100.0 20:06 21:36 " Pre -load DS PDL 5/2/2019 5/2/2019 0.40 PROD1 DRILL PULD T PJSM, LD tools (close swab 2, 100.0 0.0 21:36 22:00 pumping MP) 52/2019 5/2/2019 0.60 PR0D1 DRILL WAIT T Wait on fishing tools to rig, pumping 0.0 0.0 22:00 22:36 MP, BOT arrives, unload tools 5/2/2019 5/2/2019 1.20 PROD1 DRILL PULD T PJSM, PD BHA #3 Fishing Assembly 0.0 69.0 22:36 23:48 (Accelerator, weight bars, & up/down jars) 5/2/2019 5/3/2019 0.20 PROD1 DRILL TRIP T Begin RIH w/ BHA #3 69.0 200.0 23:48 00:00 5/3/2019 5/3/2019 1.50 PROD1 DRILL TRIP T RIH w/ BHA #3 200.0 8,745.0 00:00 01:30 5/3/2019 5/3/2019 0.10 PROD1 DRILL DLOG T Pi = 29K, log K1 for -11.5' 6,745.0 8,765.0 01:30 01:36 correction 5/3/2019 5/3/2019 0.10 PROD1 DRILL TRIP T Continue RIH, latch into fish at 8,765.0 8,874.0 01:36 01:42 -8774' (put stuck bit at 8830' corrected), close EDC 5/3/2019 5/3/2019 0.30 PRODt DRILL TRIP T Begin jarring down, broke free on 41h 8,874.0 8,874.0 01:42 02:00 jar lick, RIH to 8782', stack weight 5/3/2019 5/3/2019 1.30 PRODi DRILL CIRC T PUH, clear of window & whipstock, 8,874.0 8,732.0 02:00 03:18 open EDC, circulate bottoms up, prep pits & returns truck to pump KWF 5/3/2019 5/3/2019 2.00 PR0D1 DRILL CIRC T Displace well to 11.5 ppg KWF & 8,732.0 65.0 03:18 0518 POOH 5/32019 5/3/2019 0.70 7R0D1 DRILL PULD T Al surface, PJSM, flow check well. Lay 65.0 0.0 05:18 06:00 down tools on dead well. Al fish ecovered 5/3/2019 5/3/2019 1.20 PROD1 DRILL PULD T Make up BHA #4,1°aKO motor and 0.0 62.7 06:00 07:12 2.80 Crayola mill to dress window 5/32019 5/3/2019 1.20 PROD1 DRILL TRIP T RIH BHA#4. Pull BHA out of hole to 62.7 62.7 07:12 08:24 1 adjust wear band on motor Page 3134 Report Printed: 61512019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time our (hr) Phase Op Code AOvily Cade Time P -T -X Operation (111<13) EM Depth (US) 5/3/2019 5/3/2019 1.70 PROD1 DRILL TRIP T RIH BHA #4, Shallow test motor, 62.7 8,740.0 08:24 10:06 Continue in 5/3/2019 5/3/2019 0.10 PROD1 DRILL DLOG T Log 1 for -12' correcion 8,740.0 8,764.0 10:06 10:12 5/3/2019 5/3/2019 0.70 PROW DRILL CIRC T Continue trip in, Displace well back to 8,764.0 8,815.0 10:12 1054 milling fluid 5/3/2019 5/3/2019 1.90 PROD1 DRILL REAM T Start reaming window, 1.78 BPM @ 8,815.0 8,832.3 10:54 12:48 3435 PSI FS, BHP=3580. Ream down @ 15° ROHS @ 1 FPM. Hard stall @ 8832.3. PUW=28K clean pick up. Reset RIH @.5 FPM hard stall @ 8832.01. Clean pick up @ 30K. Reset RIH slower continue to stall multiple times. always clean pick ups 513/2019 5/3/2019 1.60 PRODi DRILL REAM T 8832.3 first time making it back to 8,832.3 8,830.0 12:48 1424 initial stall depth. Stalled out. Pick up initially broke over then became stuck @ 8830. Work pipe withing motor design limits -9K to +9. Motor is stalled. We can orient but looks like we are just overriding the motor. Try Bleeding off coil to relax motor. Orienting in tension. Dump WHP. Pressure up on well. Ramping pump up. Dumping pump 5/312019 5/3/2019 0.10 PRODi DRILL OTHR T Go to neutral weight, 15 ROHS, 8,830.0 8,812.0 14:24 14:30 1 release from coillrak, PUW=29K PUH 5/3/2019 5/3/2019 2.30 PROD1 DRILL CIRC T Displace well to 11.4 PPG KWF. Trip 8,812.0 70.0 14:30 16:48 out of well 5/3/2019 5/3/2019 0.40 PROD1 DRILL PULD T LD BHA #4 70.0 0.0 16:48 17:12 5/3/2019 5/3/2019 0.40 PROD1 DRILL PULD T PU BHA#5 Fishing Assembly 0.0 69.0 17:12 17:36 (Accelerator, weight bars, & up/down jars) 5/3/2019 5/3/2019 1.70 PROD1 DRILL TRIP T RIH w/ BHA #5 69.0 8,735.0 17:36 19:18 5/3/2019 5/3/2019 0.10 PROD1 DRILL DLOG T Log K1 for -12' 8,735.0 8,765.0 19:18 19:24 5/312019 51312019 0.10 PROD1 DRILL TRIP T PUW = 31 K. continue RIH, latch into 8,765.0 8,783.0 19:24 19:30 fish (fish bit depth @ 8830) 5/3/2019 5/3/2019 2.50 PROD1 DRILL JAR T Begin jarring up on fish @ -4K WOB, 8,783.0 8,783.0 19:30 22:00 then straight pull to 40K CWT (-1 OK WOB), work up to jarring at -1 OK WOB, straight pull to 45K, Confer w/ town, begin pulling jars to - 12K WOB, straight pull to -18K WOB, 50 licks in, no success 5/3/2019 5/3/2019 0.70 PROD1 DRILL JAR T Begin jarring down, 12 licks down, fish 6,783.0 8,783.0 22:00 22:42 is free on 12th lick 5/3/2019 514/2019 1.30 PROD1 DRILL TRIP T Open EDC, POOH 8,783.0 69.0 22:42 00:00 5/4/2019 5/4/2019 0.40 PROD1 DRILL JAR T Complete POOH 1,000.0 69.0 00:00 00:24 5/4/2019 5/412019 1.20 PROD1 DRILL PULD T PJSM, flow check, LD BHA #5 & fish 69.0 0.0 00:24 01:36 5/4/2019 514/2019 3.40 PROD1 DRILL SLKL P PJSM, spot slick -line unit, RU slick- 0.0 0.0 01:36 05:00 line, bring BOP's, lubricator, & tools to floor 5/4/2019 5/4/2019 1.30 PROD1 DRILL SLKL P Crew change, orientation, PT, perform 0.0 0.0 05:00 06:18 1 I drift/brush run 5/4/2019 5/4/2019 2.00 PROD1 DRILL SLKL P Trip in with wire brush on slick line to 0.0 0.0 06:18 08:18 I brush profile in tandum wedge Page 4134 ReportPrinted: 615/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SUM Depth start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operabon (WB) End Depth (WB) 5/4/2019 5/4/2019 2.70 PROD1 DRILL SLKL P On surface. Lay down brush. P/U Flow 0.0 0.0 08:18 11:00 through X -lock. Trip in unable to set down after shifting Mine running tool 5/4/2019 5/4/2019 1.50 PRODt DRILL SLKL P On surface. Still have plug on Xline, 0.0 0.0 11:00 12:30 RIH with magnets to clear profile. Lock has metal on it 5/4/2019 5/4/2019 1.90 PROD1 DRILL SLKL P On surface from magnet run. Metal on 0.0 0.0 12:30 14:24 magnets. MIN redressed flow through X -lock. Trip in and set @ 8809 SLM. Trip out 5/4/2019 5/4/2019 2.30 PROD1 DRILL SLKL P On surface, Plug gone. Trip in with 0.0 0.0 14:24 16:42 check set tool 5/4/2019 5/4/2019 1.30 PROD1 DRILL SLKL P On surface. Check set tool sheared 0.0 0.0 16:42 18:00 indicating lock is locked. PJSM rig down slick line unit and load out pressure control equipment 5/4/2019 5/4/2019 1.20 PROD1 DRILL CTOP P Lock out a -line, epoxy a -line end, MU 0.0 0.0 18:00 19:12 noale, stab on, pump slack back 3 times @ 3 bpm, hear wire, pop off injector 5/4/2019 5/4/2019 1.40 PROD1 DRILL CTOP P MU hydraulic cutter, cut & found wire 0.0 0.0 19:12 20:36 in 8', cut total of 150' 5/4/2019 5/4/2019 1.80 PRODt DRILL CTOP P Ream pipe, install CTC, pull test to 0.0 0.0 20:36 22:24 35K, re -head a -line, PT to 4500 psi 5/4/2019 5/4/2019 1.00 PROD2 RPEQPT PULD P PJSM, PU BHA#6 WS Assembly (NS 0.0 74.0 22:24 23:24 inner wedge), slide in cart, check pack -offs, MU to coil 5/4/2019 5/5/2019 0.60 PROD2 RPEQPT TRIP P Begin RIH w/ BHA#6, EDC open, 74.0 23:24 00:00 pumping 1.2 bpm 5/5/2019 5/5/2019 1.30 PROD2 RPEQPT TRIP P Continue RIH w/ BHA #6 74.0 8,750.0 00:00 01:18 5/5/2019 5/5/2019 0.10 PROD2 RPEQPT DLOG P Log K1 for -12.5', PUW = 30K 8,750.0 8,785.0 01:18 01:24 5/5/2019 5/5/2019 0.10 PROD2 RPEQPT TRIP P Continue RIH, set -down 6K at 8788', 8,788.0 7,500.0 01:24 01:30 appears X -Lock set in wrong X -Nipple at 8788' 5/5/2019 5/5/2019 0.70 PROD2 RPEQPT TRIP P PUH, RIBH & re- log K1 for 0' 7,500.0 8,788.0 01:30 02:12 correction, drop pumps, lightly tag at 8788' (2K WOB), apprears x -lock set in incorrect nipple @ 8788', call out slick line to pull & re -set X -Lock in nipple at 8817' 5/5/2019 5/5/2019 1.50 PROD2 RPEQPT TRIP P POOH 8,788.0 70-0- 02:12 03:42 5/5/2019 5/5/2019 0.90 PROD2 RPEQPT PULD P PJSM, LD BHA #6, clear floor 70.0 0.0 03:42 04:36 5/5/2019 5/5/2019 3.30 PROD2 RPEQPT SLKL T PJSM, RU slick -line 0.0 0.0 04:36 07:54 5/5/2019 5/5/2019 1.10 PROD2 RPEQPT SLKL T RIH to retrieve flow through X -lock. 0.0 0.0 07:54 09:00 Latch and pull from 8784' SLM 5/5/2019 5/5/2019 1.80 PROD2 RPEQPT SLKL T Trip in with flow through whipstock. 0.0 0.0 09:00 10:48 Set @ 8814' SLM 5/5/2019 5/5/2019 2.00 PROD2 RPEQPT SLKL T Trip in with check set tool 0.0 0.0 10:48 12:48 5/5/2019 5/5/2019 0.90 PROD2 RPEQPT SLKL T At surface. Check set tool sheared. 0.0 0.0 12:48 13:42 PJSM rig down slick line unit 5/5/2019 5/5/2019 1.00 PROD2 RPEQPT PULD T PJSM, P/U M/U Rerun whipstock tray. 0.0 74.1 13:42 14:42 M/U to coil and surface test 5/5/2019 5/5/2019 2.00 PROD2 RPEQPT TRIP T RIH with whipstock 74.1 8,750.0 14:42 16:42 5/5/2019 5/5/2019 0.10 PROD2 RPEQPT DLOG T Log Kt for-13'to 8775.47, PUW=31K 8,750.0 8,788.0 16:42 16:48 Page 5/34 Report Printed: 6/5/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log amrt Depth start Time End Time our (hr) Phase Do Code Acb y Code Time P -T -X openepon IRKS) End Depth (ftKB) 5/5/2019 5/512019 0.30 PROD2 RPEQPT TRIP T Continue in set @18819, Orient to HS, 8,788.0 8,819.0 16:48 17:06 Shut EDC, Bring on pump .4 BPM. See tool shift @ 2800 PSI. PUW=30K, TOWS -8807' 5/5/2019 5/5/2019 1.30 PROD2 RPEQPT TRIP P Trip out after setting whipstock, EDC 8,819.0 74.0 17:06 18:24 closed 5/512019 5/5/2019 0.60 PROD2 RPEQPT PULD P LD BHA #7 74.0 0.0 18:24 19:00 5/5/2019 5/5/2019 0.90 PROD2 WHPST PULD P PU BHA#8 Milling Assembly #2(0.4° 0.0 64.0 19:00 19:54 Weatherford motor, NS short shank string reamer, & NS short shank mill), slide in cart, check pack -offs, MU to coil, tag up, space out, set counters 5/5/2019 5/5/2019 1.60 PROD2 WHPST TRIP P RIH w/BHA #8, EDC open 64.0 8,735.0 19:54 21:30 5/5/2019 5/5/2019 0.10 PROD2 WHPST DLOG P Log K1 for -12.5' correction 8,735.0 8,774.0 21:30 21:36 5/5/2019 5/5/2019 0.70 PROD2 WHPST DISP P Displace to milling fluid 8,774.0 8,785.0 21:36 22:18 5/512019 5/512019 0.20 PROD2 WHPST TRIP P Close EDC, shut down pumps, PUW = 8,785.0 8,806.5 22:18 22:30 28K, RIH, tag TOWS @ 8807', PUW = 30K 5/5/2019 516/2019 1.50 PROD2 WHPST WPST P Milling window from 8805.5', FS = 8,806.5 8,808.2 22:30 00:00 675 psi @ 1.83 bpm, pump = 3875 psi, CWT = 13.7K, WOB = 0.5K, avg ROP = 1.1 fph 5/6/2019 5/6/2019 2.00 PROD2 WHPST WPST P Milling window from 8808.2, CWT= 8,808.2 8,809.0 00:00 02:00 11.8K, WOB = 3.4K, pump = 3979 psi, rip = 928 psi, avg ROP = 0.4 fph 5/6/2019 516/2019 2.00 PROD2 WHPST WPST P Milling, CWT = 11.9K, pump = 3949 8,809.0 8,810.2 02:00 04:00 psi, WOB = 3.3K, dp = 943 psi, avg ROP = 0.6 fph 5/6/2019 5/6/2019 1.00 PROD2 WHPST WPST P Milling, CWT =11.5K, pump =4088 8,810.2 8,610.6 04:00 05:00 psi, WOB = 3.4K, dip = 1039 psi, avg ROP = 0.4 fph " Pre -load DS PDL 5/6/2019 5/6/2019 9.10 PROD2 WHPST WPST P Milling, CWT = 10.9K, WOB = 3.6K, 8,810.6 8,813.3 05:00 14:06 1 1 pump = 4100 psi, FS = 675 psi 5/6/2019 5/6/2019 2.80 PROD2 WHPST WPST P P/U and reset, PUW=31 K. Progress 8,813.3 8,814.0 14:06 16:54 has slowed 5/6/2019 5/6/2019 1.70 PROD2 WHPST TRIP T Not acting right. Not drilling off, low 8,814.0 50.3 16:54 18:36 differential pressure, Bad feeling 5/6/2019 5/612019 1.40 PROD2 WHPST PULD T PUD BHA *8, Mill out @ 2.79 No Go. 50.3 0.0 18:36 20:00 Motor drive slop @ -40'. Lower bearings tight 5/612019 5/6/2019 0.70 PROD2 WHPST PULD T WU RB WFT.4° fixed bend motor 0.0 65.0 20:00 20:42 with new short shank NS Mill and deploy BHA#9 5/8/2019 5/6/2019 2.40 PROD2 WHPST PULD T Laying down motor started 65.0 0.0 20:42 23:06 investigaleing scribe due to multiple scribes on motor we picked up. Found houseing bent incorrectly. PUD BHA# 9 for closer inspection. Bent the same direction as motor we just pulled out. Confer with town. Plan forward to run .4° AKO X-Treme motor 5/6/2019 5/7/2019 0.90 PROD2 WHPST PULD T PJSM, Re -deploy BHA #9 with 0.0 63.0 23:06 00:00 Inteq.4°Motor 5712019 51712019 1.60 PROD2 WHPST TRIP T RIH w/ BHA #9 63.0 8,735.0 00:00 01:36 5/7/2019 5/7/2019 0.20 PROD2 WHPST DLOG T Log K1 for -13' correction, PUW = 8,735.0 8,775.0 01:36 01:48 1 31 K, close EDC Page 6134 Report Printed: 61512019 Summary (with Timelog Depths) CUperations 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr) Phase Op cWe Activity CMe Time P -T -X Operation Stan Depth (f*(B) End Depth (N®) 5/7/2019 5/7/2019 0.20 PROD2 WHPST TRIP T Continue RIH 8,775.0 8,805.0 01:48 02:00 5/7/2019 5/7/2019 0.30 PROD2 WHPST TRIP T Work slow through window at 0.3 fpm 8,805.0 8,813.7 02:00 02:18 looking for motor -work, FS = 446 psi 1.8 bpm 5/7/2019 5/7/2019 1.70 PROD2 WHPST WPST P Milling from 8813.7', FS = 446 psi @ 8,813.7 8,814.8 02:18 04:00 1.8 bpm, pump = 3667 psi, dp = 554 psi, CWT = 12.8K, let mill off at 8814.8', avg ROP = 0.65 fph 5/7/2019 5/7/2019 1.50 PROD2 WHPST WPST P Milling from 8814.8', CWT = 12.1 K, 8,814.8 8,816.5 04:00 05:30 WOB = 3K, pump = 3799 psi, weight falls off, bottom of window called at 8815', allow string reamer to exit window 5/7/2019 5/7/2019 1.10 PROD2 WHPST MILL P Begin pushing on it, milling rat -hole 8,816.5 8,832.0 05:30 06:36 (25' below TOWS), PUW = 29K 5/7/2019 5/7/2019 0.70 PROD2 WHPST REAM P Perfrom reaming passes (HS, 30R), 8,832.0 8,800.0 06:36 07:18 begin having issues with Nabors counter wheel (depth is decreasing while RIH), pull above TOWS to trouble -shoot, issue 5/7/2019 5/712019 0.50 PROD2 WHPST CIRC P Swap out counter, resolve issue, log 8,800.0 8,832.0 07:18 07:48 K1 for +05 correction, RBIH to continue reaming 517/2019 5/7/2019 1.20 PROD2 WHPST REAM P Cotninue reaming passes, 30L & LS, 8,832.0 8,832.0 07:48 09:00 dry drift window up & down, clean, tag bottom, open EDC 5/7/2019 5/7/2019 1.80 PROD2 WHPST TRIP P POOH 8,832.0 60.0 09:00 10:48 5/7/2019 517/2019 0.90 PROD2 WHPST PULD P PUD BHA #9, mills came out 2.79" no- 60.0 0.0 10:48 11:42 go 5/7/2019 5/7/2019 0.50 PROD2 WHPST BOPE P Function test BOP'S, PU & LD test jnts 0.0 0.0 11:42 12:12 517/2019 5/712019 0.90 PROD2 WHPST PULD P PD BHA#10 Reaming Assembly (1.0° 0.0 62.0 12:12 13:06 AKO motor & crayola mill), slide in cart, check pack -offs, MU to coil, set counters. Mill in at 2.79" NG 5/7/2019 5/7/2019 1.70 PROD2 WHPST TRIP P RIHw/BHA#10 62.0 8,735.0 13:06 14:48 517/2019 5/7/2019 0.10 PROD2 WHPST DLOG P Log K1 for+2.5', PUW = 30K, close 8,735.0 8,766.0 14:48 14:54 EDC 5/7/2019 5/7/2019 0.10 PROD2 WHPST TRIP P Continue RIH 8,766.0 8,005.0 14:54 15:00 5/7/2019 5/7/2019 2.50 PROD2 WHPST REAM P Reaming (HS, 30R, 30L, LS), FS = 8,005.0 8,830.0 15:00 17:30 348 psi, 1 fpm Dry drift window - dean 5/7/2019 5/7/2019 2.00 PROD2 WHPST TRIP P PUH, park and open EDC, POOH 8,830.0 65.0 17:30 19:30 pumping 2.04 bpm, 5/7/2019 5/7/2019 1.10 PROD2 WHPST PULD P PUD BHA # 10. Mill out at 2.79" NG 65.0 0.0 19:30 20:36 5/7/2019 5/72019 0.50 PROD2 DRILL CIRC P Slab injector and jet stack. 0.0 0.0 20:36 21:06 517/2019 5/7/2019 0.90 PROD2 DRILL PULD P PU and pressure deploy BHA #11, L2 0.0 72.0 21:06 22:00 build drilling assembly, 2.5° AKO, bump up, set counters. 5/7/2019 5/7/2019 1.90 PROD2 DRILL TRIP P RIH, displacing coil /well to new mud 72.0 8,730.0 22:00 23:54 system #2. Taking returns to the tiger tank. 5/7/2019 5/8/2019 0.10 PROD2 DRILL DLOG P Tie into the Kt for a +2' correction. 8,730.0 8,761.0 23:54 00:00 j Page 7134 ReportPrinted: 615/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Dephn Sten Time End Time our (hr) Phase Op Code Activity Code Time P-T-x Operation (nKB) End Depth (nKB) 5/8/2019 5/8/2019 0.50 PROD2 DRILL DISP P PU Wt 31 k continue to tum well over 8,761.0 8,787.0 00:00 00:30 to new mud, system #2. New Mud a the bit @ 8787', 00:03, new mud to surface 5/8/2019 518/2019 0.10 PROD2 DRILL TRIP P SID pumps, close EDC, continue to 8,787.0 8,833.0 00:30 00:36 RIH. window clean, 5/8/2019 5/8/2019 3.60 PROD2 DRILL DRLG P CT 3750 psi @ 1.88 bpm in and 1.88 8,833.0 8,930.0 00:36 04:12 bpm out, BHP 3580 psi, targeting 11.4 ppg EMW @ the window. Free spin diff 572 psi, WH 200 psi, IA 12 psi, OA 24 psi. CT RIH Wt 13.83 k, OBD, CT Wt 11.67 k lbs, WOB 1.5 k lbs, Ct PU Wis 33 - 36 k lbs Pump TD Sweeps 5/8/2019 5/8/2019 2.00 PROD2 DRILL TRIP P PU Wt 32 k lbs, PUH, Park and open 8,930.0 70.0 04:12 06:12 EDC, POOH pumping 2 bpm , required holding 11.5 ppg POOH 5/8/2019 5/8/2019 1.20 PROD2 DRILL PULD P PJSM, PUD BHA#11, swap out o-ring 70.0 0.0 0612 07:24 on riser, check pack-offs 5/8/2019 5/8/2019 0.90 PROD2 DRILL PULD P PD BHA *12 L2 Drill Assembly 0.0 78.0 07:24 08:18 (agitator, 0.5 AKO motor, RB HYC A3 bit) 5/8/2019 5/8/2019 2.00 PROD2 DRILL TRIP P RIH w/BHA#12, shallow test tools, 78.0 8.715.0 08:18 10:18 grab transducer sceen MM packed off at -4497', by-pass & clear MM 5/8/2019 5/8/2019 0.10 PROD2 DRILL DLOG P Log K1 for O' correction, PUW = 28K, 8,715.0 8,755.0 10:18 10:24 close EDC 5/8/2019 5/8/2019 0.30 PROD2 DRILL TRIP P Continue RIH, log RA tag at 8812', 8,755.0 8,930.0 10:24 10:42 perform MAD pass of build, stack weight at -8902', PU, cointinue RIH 5/8/2019 5/8/2019 1.60 PROD2 DRILL DRLG P Drilling, FS = 1150 psi @ 1.9 bpm, 8,930.0 8,995.0 10:42 12:18 pump = 4484 psi, CWT = 11.31K, WOB = 1.3K, 100% returns, PU to grab survey, PUW = 30K, drop to 1.8 bpm at DD request to allow for surveys, avg ROP = 41 fph 5/8/2019 5/8/2019 2.20 PROD2 DRILL DRLG P Drilling, pump =4572 psi, CWT= 8,995.0 9,110.0 12:18 14:30 8.5K, WOB = 2.31K, pump 5 x 5 sweeps, attempt to bring rate up, tool dropping gamma & NBI values to surface, drop rate to 1.8 bpm, avg ROP = 52 fph PUW = 30K from 9110' 5/8/2019 5/8/2019 0.30 PROD2 DRILL WPRT P MM packing off, bypass & blow-down, 9,110.0 9,110.0 14:30 14:48 choke B packed off, swap to choke A, PUW = 30K, turn into BHA wiper 5/8/2019 5/8/2019 0.20 PROD2 DRILL WPRT P Difficulty getting started drilling, PU, 9,110.0 9,110.0 14:48 15:00 dip down to 717 psi, pump = 3038 psi, pump #2 popped off though no observable pressure spike, unsure why pump popped off, possibly bleeder valve, investigating, swap to mud pump #1 5/8/2019 5/8/2019 4.00 PROD2 DRILL DRLG P Drilling, CWT = 11.61K, WOB = 1.2K, 9,110.0 9,330.0 15:00 19:00 pump = 4689 psi, dip = 1418 psi " Change out bleeder pump 2 5/8/2019 5/8/2019 0.20 PROD2 DRILL WPRT P PU Wt 32 k lbs, PUH on wiper #1 to 9,330.0 8,939.0 19:00 19:12 just below the build 5/8/2019 5/8/2019 0.20 PROD2 DRILL WPRT P RBIH 8,939.0 9,330.0 19:12 19:24 Page 8/34 Report Printed: 61512019 e Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Ope2lion (MKB) EM Depth (MKB) 5/8/2019 5/9/2019 4.60 PROD2 DRILL DRLG P CT 4771 psi @ 1.86 bpm in and 1.86 9,330.0 9,711.0 19:24 00:00 bpm out, free spin diff 1470 psi, BHP 3680 psi, WH 52 psi, open choke. CT Wt 9.8 k lbs, WOB 2 k lbs, ROP 83 R/hr 5/9/2019 5/9/2019 0.30 PROD2 DRILL DRLG P Drilling 9,711.0 9,730.0 00:00 00:18 CT 4771 psi Q 1.86 bpm in and 1.86 bpm out, free spin diff 1470 psi, BHP 3680 psi, WH 52 psi, open choke. CT Wt 9.8 k lbs, WOB 2 k lbs, 5/9/2019 5/9/2019 0.30 PROD2 DRILL WPRT P PU Wt 33 k lbs, PUH on wiper #2 9,730.0 8,937.0 00:18 00:36 5/9/2019 5/9/2019 0.40 PROD2 DRILL WPRT P RBIH, S/D@ 8970', issue w/ TIF, PU 8,937.0 9,730.0 00:36 01:00 31 k lbs, clean, continue to RIH 5/9/2019 5/9/2019 4.80 PROD2 DRILL DRLG P CT 4766 psi @ 1.86 bpm in and 1.86 9,730.0 10,130.0 01:00 05:48 bpm out, free spin diff 1367 psi, BHP 3676 psi, WH 108 psi, open choke. CT Wt 9.1 k lbs, WOB 2 k lbs, ROP 81 Whir 5/9/2019 5/9/2019 0.50 PROD2 DRILL WPRT P Wiper to window, PUW =33K 10,130.0 8,740.0 05:48 06:18 5/9/2019 5/9/2019 0.30 PROD2 DRILL DLOG P Log K1 for+3' correction 8,740.0 8,772.0 06:18 06:36 Test pump #2, good 5/9/2019 5/9/2019 0.50 PROM DRILL WPRT P Wiper in-hole, RIW = 8.6K 8,772.0 10,130.0 06:36 07:06 5/9/2019 5/9/2019 0.90 PROD2 DRILL DRLG P Drilling, FS = 1150 psi Q 1.8 bpm, 10,130.0 10,200.0 07:06 08:00 CWT = 4684 psi, WOB = 1.2K, annular = 3700 psi, WHP = 98 pis, pump = 4761 psi, pump 5x5 sweeps, difficulty dropping inclination, reduce rate to 1.7 bpm, attempt to get more WOB (will raise rate once dropping) 5/9/2019 5/9/2019 1.40 PROD2 DRILL DRLG P MM packing off, bypass 8 blow down, 10,200.0 10,282.0 08:00 09:24 still packed off, snake MM Drilling, CWT = 6.51K, WOB = 1.8K, annular = 3792 psi, WHP = 223 psi, torquing up TF, continued difficulty dropping inclination, requiring reducing WOB to steer. Once down to 86° increase rate to 1.9 bpm 5/9/2019 5/9/2019 3.50 PROD2 DRILL DRLG P Continuous rotation drilling when 10,282.0 10,530.0 09:24 1254 possible, CWT = 6.6K, WOB = 2.4K, annular = 3650 psi, WHP = 110 psi, PUW = 31 K from 10,295', pump 5x5 sweeps Ultra LoVis at the bit 10,509' 5/9/2019 5/9/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, PUW = 31K 10,530.0 9,700.0 12:54 13:12 5/9/2019 5/9/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, RIW = 1 O 9,700.0 10,530.0 13:12 13:30 5/9/2019 5/9/2019 1.80 PROD2 DRILL DRLG P Drilling, FS = 1200 psi @ 1.9 bpm, 10,530.0 10,624.0 13:30 15:18 CWT = 5K, WOB = 2.9K, annular = 3742, WHIP = 120 psi, pump 4900 psi, lower ROP over interval Stalled at 10,542', PUW = 34K Page 9134 Report Printed: 6/5/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Tim End rare Dur(hr) Phase Op Code Acdvi Code N Tam P -T -x Operefion n De sten Depth End Depth (MB) 5/9/2019 5/9/2019 1.70 PROD2 DRILL DRLG P Experiencing low ROP, spin bit off 10,624.0 10,702.0 15:18 17:00 bottom with LoVis exitiing bit in attempt to clear potentially balled bit Drilling, CWT = 5.8K, WOB = 2.6K, pump = 4895 psi, anuular = 3761 psi, WHP = 126 psi, begin swapping mud, taking returns to tiger -tank, thus unbale to capture some scheduled samples 5/9/2019 5/9/2019 3.00 PROD2 DRILL DRLG P Drilling, PU to check parameters after 10,702.0 10,861.0 17:00 20:00 crew change, PU Wt 31 k lbs CT 4542 psi @ 1.88 bpm in and 1.88 bpm out. Free spin diff 1234 psi. BHP 3748 psi, WH 119 psi, OBD CT Wt 8.6 k lbs WOB 2 k lbs ROP 53 ft/ min " New mud at the bit 10,730' 5/9/2019 5/9/2019 0.40 PROD2 DRILL WPRT P Wiper up -hole, PUW=33K-pulled 10,861.0 10,000.0 20:00 20:24 early due to dose approach to south west comer of the polygon. 5/9/2019 519/2019 0.40 PROM DRILL WPRT P Wiper in-hole, RIW = 11.2 K- Polygon 10,000.0 10,861.0 20:24 20:48 extended 5/9/2019 5/10/2019 3.20 PROD2 DRILL DRLG P CT 4550 psi @ 1.89 bpm in and 1.89 10,861.0 11,057.0 20:48 00:00 bpm out Free spin diff 1187 psi, BHP 3775 psi, WH 112 psi, IA 575 psi, OA 471 psi, OBD CT Wt 6.5 k lbs, WOB 3 k lbs. 10939' PU Wt 32 k lbs 10969' PU Wt 34 k Ibs 5/10/2019 5/10/2019 2.90 PROD2 DRILL DRLG P CT 4787 psi @ 1.88 bpm in and 1.88 11,057.0 11,260.0 00:00 02:54 bpm out BHP 3795 psi, WH 103 psi, IA 540 psi, OA 516 psi, OBD CT Wt 9.7 k lbs, WOB 2.8 k lbs. ROP 70 ftthr Added 1% screen clean to High and low vis sweeps, no improvement in ROP noticed. 5/10/2019 5/10/2019 0.90 PROD2 DRILL WPRT P PU Wt 33 k lbs, Wiper #3, Iongwiper to 11,260.0 8,830.0 02:54 03:48 the K1 for tie in. 5/1012019 5/10/2019 0.20 PROD2 DRILL DLOG P Tie into RA for+5.5' correction 8,830.0 8,846.0 03:48 04:00 5/10/2019 5/10/2019 0.90 PROD2 DRILL TRIP P RBIH RIH WT 11 k lbs - Clean hole 8,846.0 11,260.0 04:00 04:54 5/10/2019 5/10/2019 1.10 PROD2 DRILL DRLG P CT 4559 psi @ 1.87 bpm in and 1.87 11,260.0 11,317.0 04:54 06:00 bpm out, Free spin diff 1068 psi, BHP 3783 psi, OBD CT Wt 7 k lbs, WOB 2.5 k lbs 5/10/2019 5/10/2019 3.00 PROD2 DRILL DRLG P Drilling, CWT= 8.3K, WOB = 1.3K, 11,317.0 11,451.0 06:00 09:00 annular = 3807 psi, WHP = 82 psi, pump = 4873 psi Ultra IoVis sweeps at bit at 11,430', no noticeable improvement w/ SkreenKleen coming around Difficulty drilling at 11,451'. WOB slacking, PUW = 31 K 5/10/2019 5/10/2019 0.60 PROD2 DRILL DRLG P Working on hard spot at 11,449'(3.5K 11,451.0 11,462.0 09:00 09:36 WOB, dp = 1164 psi), drill through, again work on hard spot at 11,455', break through, again hard spot at 11,457' Page 10134 Report Printed: 6/5/2019 - Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start rime End Time our (hr) Phase Op Code A vq Code Time PJA Operation Start Depth (flKB) End Depth (IIKB) 5/10/2019 5/10/2019 2.40 PROD2 DRILL DRLG P Drilling, CWT= 7.9K, WOB = 1.5K, 11,462.0 11,594.0 09:36 12:00 annular = 3820 psi, WHP = 102 psi, pump = 4945 psi, steady state drilling, avg ROP = 55 fph 5/10/2019 5/10/2019 0.30 PROD2 DRILL WPRT P Early wiper (allow geology time to 11,594.0 10,800.0 12:00 1218 determine path forward), PUW = 34K 5/10/2019 5/10/2019 0.40 PROD2 DRILL WPRT P Wiper in-hole, decision made to rejoin 10,800.0 11,594.0 12:18 12:42 plan by 12,000', through the "B", RIW = 1OK, pump 5x5 sweeps 5/10/2019 5/10/2019 1.30 PROD2 DRILL DRLG P Drilling, FS = 1070 psi @ 1.88 bpm, 11,594.0 11,657.0 12:42 14:00 CWT= 8.8K, WOB = 1.5K, annular= 3843 psi, WHIP = 87 psi, pump = 5002 psi, difficulty building, drop rate & push on it in attempt to build, begin building, bring rate back to 1.9 bpm Ultra IoVis sweep hit bit at 11,604' 5/10/2019 5/10/2019 0.30 PROD2 DRILL WPRT P Geo wiper, PUW = 31 K, decison made 11,657.0 11,657.0 14:00 14:18 1 1 1 to taget 86° 5/10/2019 5/10/2019 3.00 PROM DRILL DRLG P Drilling, CWT= 6.6K, WOB = 1.7K, 11,657.0 11,830.0 14:18 17:18 annular = 3889 psi, WHP = 73 psi, pump = 5118 psi, lower rale & squat on it in attempt to drop inclination, continued difficulty dropping inc 5/10/2019 5/10/2019 0.80 PROD2 DRILL DISP T Decision made to pull for a higher 11,830.0 11,606.0 17:18 18:06 bend motor, pump 5x5 sweeps, PUH slowly while sweeps circulated to the bit. 5/10/2019 5/10/2019 1.10 PROD DRILL TRIP T POOH open hole chasing sweeps, 11,606.0 8,787.0 18:06 19:12 1 1 hole and window clean. 5/10/2019 5/10/2019 1.70 PROD2 DRILL TRIP T Parked, opened EDC, POOH pumping 8,787.0 72.0 19:12 20:54 -2 bpm. Jogged tubing @ 891' continue to POOH, some coil brillow in the surge returns at the shaker. 5/10/2019 5/10/2019 1.20 PROD2 DRILL PULD T PUD BHA# 13, lay down motor, 72.0 0.0 20:54 22:06 agitator and spent A3 bit. 5/10/2019 5/10/2019 1.20 PROD2 DRILL PULD T PD 0.9°AKO motor under dirty -41 0.0 72.0 22:06 23:18 hrs, NOV agitator. Skid cart, stab injector, check pack offs, Replaced - 300,000 running feet on this set. bump up, set counters. 5/10/2019 5/11/2019 0.70 PROD2 DRILL TRIP T RIH, close EDC @ 500', shallow test 72.0 3,270.0 23:18 00:00 agitator, 1021 psi @ 1.8 bpm, continue in hole. 5/112019 5/11/2019 0.90 PROD2 DRILL TRIP T Coninue to RIH 3,270.0 8,740.0 00:00 00:54 5/11/2019 5/11/2019 0.20 PROD2 DRILL TRIP T Tie into the K1 for +15 correction. 8,740.0 8,768.0 00:54 01:06 5/11/2019 5/11/2019 1.40 PROD2 DRILL TRIP T Continue to RIH, window clean 8,768.0 11,830.0 01:06 02:30 Stacked out WOB and CT Wt 2x from 9,008' to 9,086'. PU, 36 k lbs and attempted to RIH twice, once at full rate and once at 1.5 bpm. Reduced rate to 0.8 bpm RIH, increased rate @ 9,150'. SID again @ 11,547, PU 38 k lbs, 3 times RIH LS, 17 ft/min @ 1.25 bpm, s/D again at 11,591, PU 38 k lbs, RIH Page 11/34 Report Printed: 6/5/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Acdvky Cole Time P -T -X Operation Start Depth (flKS) End Depth(MB) 5/11/2019 5/11/2019 2.50 PROM DRILL DRLG T CT 4640 psi, @ 1.87 bpm in an 1.87 11,830.0 12,052.0 02:30 05:00 bpm out, Free spin diff 977 psi, BHP 3876 psi, WH51 psi, IA 170 psi, OA 306 psi. CT Wt 3 k lbs, WOB 1.1 k lbs. 5/11/2019 5/11/2019 2.00 PROM DRILL DRLG T Drilling, continuous rotation when 12,052.0 12,166.0 05:00 07:00 possible, CWT = 0.31K, WOB = 1.2K, annular = 3947 psi, WHP = 56 psi, pump = 4907 psi, begin catching samples again at 12,100' per town geology, cutting ratio = 1.56 5/11/2019 5/11/2019 1.30 PROD2 DRILL DRLG T Drilling, CWT= -2.8K, WOB =1K, 12,166.0 12,230.0 07:00 08:18 annular = 3934 psi, pump = 4938 psi, struggling w/ weight transfer, pump 5x5 sweeps 5/11/2019 5/11/2019 0.40 PROD2 DRILL WPRT T Wiper up -hole, PUW = 38K, -36k -38k 12,230.0 11,300.0 08:18 08:42 CWT through the B, small WOB tug at -12,012' 5/11/2019 5/11/2019 0.50 PROD2 DRILL WPRT T Wiper in-hole @ 1.9 bpm, drop to 1.2 11,300.0 12,230.0 08:42 09:12 bpm prior to passing 11,547'& 11,591', bring rate back to 1.5 bpm once past, a bit ratty to bottom, though no PU's required, bring rate up to 1.9 bpm 5/11/2019 5/11/2019 1.10 PROD2 DRILL DRLG T Drilling, FS = 1025 psi @ 1.9 bpm, 12,230.0 12,297.0 09:12 10:18 CWT = 1.51K, WOB = 1 K, annular = 3960 psi, WHIP = 30 psi " PJSM, begin dropping DS PDS to send in for inspection, change out pack -off. 5/11/2019 5/11/2019 3.20 PROD2 DRILL DRUG T Fault did not come in as expected, 12,297.0 12,414.0 10:18 13:30 decision made to climb & cross -cut C4 (up to 104° me), then decison point: if C4 is thick enough to chase, plug - back & re -drill, if not, call lateral & run liner 5/11/2019 5/11/2019 3.30 PROD2 DRILL DRLG T Continue cross -cutting up at 103" 12,414.0 12,537.0 13:30 16:48 inclination to determine C4 thickness, larger pieces of "B" in samples from 12,250'- 12,350', gamma wraps to 190 API 5/11/2019 5/11/2019 0.60 PROD2 DRILL TRIP T PUW = 37K, rig geology confers w/ 12,537.0 11,494.0 16:48 17:24 town, POOH, begin packing off, pulling heavy@ 12,261', RBIH, working pipe to 55 k to -6 k CT Wt nd 38 to -7.6 k WOB. - 6 cycles, started to POOH freely @ 11,910'. 5/11/2019 5/11/2019 1.90 PROD2 DRILL TRIP T Countinue to POOH. Observe 11,494.0 7,365.0 17:24 1918 increased Ct wt and neg WOB -8961'. Lanunch 5x5 and RBIH to 9273'. PUH clenaing up area. Same issue @ 8956', pulling heavy, packing off and WOB 7.8 to -8 klbs. Work pipe, RBIH to 9090', PUH chasing sweeps, clean. Pull through window, clean, pump till sweeps out of hole. 5/11/2019 5/11/2019 1.80 PROD2 DRILL TRIP T Park, open EDC, online @ 2 bpm, 7,365.0 66.0 19:18 21:06 POOH. "rocks at the shaker- started showng up at 1600' bit depth, RBIH jog, pump 5x5, Pull up hole timing sweeps out, returns cleaned up PUH bump up Page 12/34 Report Printed: 6/5/2019 Uperations Summary (with Timelog bepths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Our (hr) Phase Op Coda Adlvity Cafe Time P -T -X Operadon Staff Depth (US) End Deph (t1KB) 5/11/2019 5/11/2019 1.20 PROD2 DRILL PULD T PUD BHA#13, 66.0 0.0 21:06 22:18 5/11/2019 5/11/2019 1.10 PROD2 STK PULD T PD BHA #14, Aluminum billet W open 0.0 72.0 22:18 23:24 hole anchors, Stab injector, check pack offs, good, bump up set counters. 5/11/2019 5/12/2019 0.60 PROD2 STK TRIP T RIH 72.0 3,173.0 23:24 00:00 5/12/2019 5/12/2019 1.10 PROD2 STK TRIP T Continu to RIH 3,173.0 8,745.0 00:00 01:06 5/12/2019 5/12/2019 0.20 PROD2 STK DLOG T Tie into the Ki for a - 5' correction. 8,745.0 8,768.0 01:06 01:18 5/12/2019 5/12/2019 1.00 PROD2 STK TRIP T PU Wt 31 k lbs, Close EDC. RIH, drive 6,768.0 11,331.5 01:18 02:18 by RA tag (+0.5), Bleed off the pump, continue to RIH. 5/12/2019 5/12/2019 0.20 PROD2 STK WPST T Park at 11331.4, Anchors oriented HS, 11,331.5 11,331.5 02:18 02:30 PU 30 k lbs, to slack weight, Stage pump up in 500 lbs increments to 2500 psi, stating pressure 339 psi, Starting WOB -0.13, CT Wt 27.5 k lbs,@ 2500 psi, WOB was zero, rolled pump 0.45 bpm to shear @ 4100 psi, WOB 2.39 k lbs. Slack off. Billet took weight. PU 36 k WOB to 0.04 k lbs. 5/12/2019 5/12/2019 1.00 PROD2 STK TRIP T POOH w setting tool, window clean. 11,331.5 8,648.0 02:30 03:30 Park and open EDC 5/12/2019 5/12/2019 1.40 PROM STK TRIP T Continue to POOH 8,648.0 72.0 03:30 04:54 5/12/2019 5/12/2019 1.40 PROM STK PULD T PUD BHA#14, anchored billet setting 72.0 0.0 04:54 06:18 assembly. 5/12/2019 5/12/2019 1.30 PROD2 STK PULD T Crew change, PJSM, PD BHA#15 0.0 78.0 06:18 07:36 (agitator, 0.5° AKO motor, RB Baker Dynamus bit), slide in cart, check pack -offs, MU to coild, tag up, space out, set counters 5/12/2019 5/12/2019 1.70 PROM STK TRIP T RIH w/ BHA #15, shallow test agitator 78.0 8,740.0 07:36 09:18 (grab transducer screen -shot), baker depth became erratic at -4588', resolve, continue RIH 5/12/2019 5/12/2019 0.10 PROD2 STK DLOG T Log K1 for -4.5' correction 8,740.0 8,773.0 09:18 09:24 5/12/2019 5/12/2019 1.00 PROD2 STK TRIP T Continue RIH, clean through widnow, 8,773.0 11,320.3 09:24 10:24 dry tag TOB at 11,321', PUW = 34K, bring up pump, RBIH to begin side- tracking 5/12/2019 5/12/2019 1.80 PROD2 STK KOST T FS = 1026 psi, stall getting started, 11,320.3 11,321.3 10:24 12:12 PUW = 32K, RBIH, 2K WOB, let mill down to 1 K, begin side tracking, 1 fph for 1 foot from 11320.3' 5/12/2019 5/12/2019 0.50 PROD2 STK KOST T 2 fph for 1 foot 11,321.3 11,322.3 12:12 1242 5/12/2019 5/12/2019 0.30 PROD2 STK KOST T 3 fph for 1 foot 11,322.3 11,323.3 12:42 1300 5/12/2019 5/12/2019 1.20 PROD2 STK KOST T Increase ROP to 8, 10, 20 fph, stall at 11,323.3 11,329.3 13:00 1412 11,329.3', PUW = 36K, stall again at 11,328.6'& 11,328.5', PUW = 35K Page 13/34 Report Printed: 6/5/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur ft) Phase Op Code Acdvlty Code Time P -T -X Operation oepm Sian(ttK End o(e 5/12/2019 5/1212019 2.30 RO PD2 STK KOST T Confer with town, decision made to 11,33 29.3 11,31,3 29.0.0 14:12 16:30 attempt high -side, discuss further on rig, not comfortable orienting at slip, confer w/ town, decision made to attempt at 300` ROHS (3.5 fph), if able to pass stall point by -5", roll back to 330° ROHS, began seeing weight at 11328.4', stalled at 11,328.8' (twice) 5/12/2019 5/12/2019 1.40 PROM STK TRIP T Confer with town, decision made to 11,329.0 5,235.0 16:30 17:54 POOH for anchored billet 5/12/2019 5/12/2019 1.30 PROM STK TRIP T Packed off choke A, swapped to B, 5,235.0 4,974.0 17:54 19:12 packed of choke B, cleared and temped to start pumping and pulling. Packed both chokes and MM off multiple times attempting to restart, cleared choke. 5/12/2019 5/12/2019 0.40 PROD2 STK TRIP T RIH to clean up cased hole after 4,974.0 7,586.0 19:12 1936 1 1 1 spending some time with no pumps. 5/12/2019 5/12/2019 1.40 PROM STK TRIP T POOH with multiple choke and MM 7,586.0 70.8 19:36 21:00 pack of events. Bypass MM to preserve flow path. 5/12/2019 5/12/2019 2.40 PROD2 STK PULD T PUD BHA#15, L2 lateral sidetrack / 70.8 0.0 21:00 23:24 drilling assembly 5/12/2019 5/12/2019 0.40 PROD2 STK PULD T Skid cart, jet stack, pop off. 0.0 0.0 23:24 23:48 5/12/2019 5/13/2019 0.20 PROD2 STK PULD T PD BHA# 16, second attempt, 0.0 70-0- 23:48 00:00 aluminum billet with open hole anchors. 5/13/2019 5/13/2019 1.00 PROD2 STK PULD T Continue PD BHA# 16, second 0.0 70.0 00:00 01:00 attempt, aluminum billet with open hole anchors. Skid can, stab on, check pack offs, Replace! 5/13/2019 5/13/2019 1.90 PROM STK TRIP T RIH wEDC open 70.0 8,745.0 01:00 02:54 5/13/2019 5/13/2019 0.20 PROD2 STK DLOG T Tie into the K1 for a 4.5' correction. 8,745.0 8,778.0 02:54 03:06 5/13/2019 5/13/2019 0.20 PROD2 STK TRIP T PU Weight 31 k lbs, park and close 8,778.0 8,830.0 03:06 03:18 EDC. TF HS, S/D when atempting to run through the window 2x @ 8817.67' and 8817.79' PU Wt 233 k lbs. Roll TF to 270' ROHS, SD 8817.7' PU 34 k lbs, Roll TF LS RIH, WOBup to 850 lbs, pushed through, WOB fell off, RIH 5/13/2019 5/13/2019 0.80 PROD2 STK TRIP T Continue to RIH. 8,830.0 11,293.9 03:18 04:06 5/13/2019 5/13/2019 0.60 PROD2 STK WPST T Park @ 11293.9', Slips @ 30° ROHS, 11,293.9 11,290.0 04:06 04:42 Pressure up in 500 psi to 2,500 psi. Shear off @ 4400 psi and 4.4 k WOB, slacked of and set 3.2 K WOB. TOB @ 11,282', PU Wt 39 k lbs 5/13/2019 5/13/2019 2.10 PROD2 STK TRIP T POOH 11,290.0 60.0 04:42 06:48 5/13/2019 5/13/2019 1.30 PROD2 STK PULD T PJSM, PUD BHA #16 60.0 0.0 06:48 08:06 5/13/2019 5/13/2019 1.60 PROM STK CTOP T Pull] checks, MU nozzle, stab on, roll 0.0 0.0 08:06 09:42 1 coil to fresh water, flush stack & surface lines, grease swab & Tango's 5/13/2019 5/13/2019 0.30 PROD2 WHDBOP PRTS T Test inner reel valve & stripper (250 0.0 0.0 09:42 1000 psi low 13800 psi high) Page 14134 ReportPrinted: 61612019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log DO Start Oeptn Start Time End Time our (hr) Phase Op Code Acdviry Time me P -T -X Operation (WB) EM DepN (fiKB) 5/13/2019 5/13/2019 1.50 PROD2 WHDBOP CTOP T Unstab injector, break off nozzle, clear 0.0 0.0 10:00 11:30 floor, grease Romeo's & Bravo's, fluid pack, line up valves " ODS PDL pre -loaded 5/13/2019 5/1312019 2.70 PROM WHDBOP BOPE T Begin BOP test (250 psi low/ 3800 psi 0.0 0.0 11:30 14:12 high) '" Witness waived by Jeff Jones of AOGCC 5/13/2019 5/13/2019 1.60 PROM WHDBOP BOPE T Difficulty holding pressure on test #8 - 0.0 0.0 14:12 15:48 bag, trouble shoot, track -down to check valve down stream of Romeo 5, test bag with mud pump #1, good test 5/13/2019 5/13/2019 0.80 PROD2 WHDBOP BOPE T Continue BOP test, difficulty holding 0.0 0.0 15:48 16:36 pressure testing Romeo 3, trouble- shoot, track to B7 not holding, good test on Romeo 3 5/13/2019 5113/2019 1.90 PROD2 WHDBOP BOPE T Complet BOP test- 0.0 0.0 16:36 18:30 1 1 • 7 hr test 5113/2019 5/13/2019 1.50 PROD2 STK DISP T Turn coil over to mud 0.0 0.0 18:30 20:00 5/13/2019 5/13/2019 1.50 PROD2 STK PULD T PD BHA#17, NOV Agitator, 0.6°AKO 0.0 0.0 20:00 21:30 motor over a HYC A3 bit. 5/13/2019 5/13/2019 1.40 PROD2 STK TRIP T RIH, Shallow test agitator - 1097 psi, 70.0 8,745.0 21:30 22:54 diff press at 1.76 bpm. 5/13/2019 5/13/2019 0.20 PROD2 STK DLOG T Tie into Kt for -4.5' correction 8,745.0 8,767.5 22:54 23:06 5/13/2019 5/14/2019 0.90 PROD2 STK TRIP T PU, Ct Wt 31 k lbs, line up HIS for 8,767.5 11,247.0 23:06 00:00 window, passage clean. build clean, 5/14/2019 5/14/2019 0.10 PROD2 STK TRIP T Continue to RIH. Dry tag TOB @ 8,767.5 11,281.0 00:00 00:06 11,281'. 5/14/2019 5/14/2019 0.30 PROD2 STK TRIP T PU Wt 36k Set rate, RBIH - Closed 11,281.0 11,281.0 00:06 00:24 manuals. Started exporting mud to the tiger tank in preparation for mud swap. 5/14/2019 5/14/2019 0.90 PROD2 STK KOST T Ct 4685 psi @ 1.82 bpm in and 1.80 11,281.1 11,282.0 00:24 01:18 bpm out, free spin diff 1,107 psi, BHP 3814 psi, targeting 11.4 EMW @ the window. CT Wt 12547 Ibs.WOB 0.5 k lbs. 5/14/2019 5/14/2019 0.50 PROD2 STK KOST T Increase ROP to 2 ft/hr WOB 11,282.0 11,283.0 01:18 01:48 increased to 0.7 k lbs, and milled off to 0.42 k lbs 5/14/2019 5/14/2019 0.35 PROD2 STK KOST T Increase ROP to 3 ft/hr WOB 0.4 k 11,283.0 11,284.0 01:48 02:09 lbs, 5/14/2019 5/14/2019 0.15 PROD2 STK KOST T Increase ROP to 10 ft/hr targeting 0.5 11,284.0 11,285.0 02:09 02:18 WOB, 5/14/2019 5/14/2019 0.10 PROD2 STK KOST T Targeting WOB of- 1k Its. Chase 11,285.0 11,292.0 02:16 02:24 ROP up to 90 fUhr to catch WOB. 5/14/2019 5/14/2019 2.70 PROD2 DRILL DRLG T Drillling ahead 11,292.0 11,480.0 02:24 05:06 CT 4829 psi @ 1.82 bpm in and 1.80 bpm out, BHP 3825 psi, CT Wt 5.6 k lbs, WOB 1.5-3.0 k lbs. Drill to 11,325', PU 33 k lbs, PUH through billet - clean. RBIH, dry drift billet - dean. BOBD. - New mud to surtace 5/14/2019 5/14/2019 3.30 PROD2 DRILL DRLG T Drilling, CWT= 1.5K, WOB= 1.9K, 11,480.0 11,700.0 05:06 08:24 annular = 3857 psi, WHIP = 95 psi, pump = 4797 psi, pump 5x5 sweeps 5/14/2019 5/14/2019 0.30 PROD2 DRILL WPRT T Wiper up -hole, PUW = 35K 11,700.0 10,900.0 08:24 08:42 1 I Page 15134 Report Printed: 615!2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Star) Time End Time our hr ( 1 Phase OP COAs Activity Cafe Time P -T -X Operation (rt KB) EM Depth (flKB) 5/14/2019 5/14/2019 0.30 PROD2 DRILL WPRT T Wiper in-hole, RIW = 81K 10,900.0 11,700.0 08:42 09:00 5/14/2019 5/14/2019 2.50 PROD2 DRILL DRLG T Drilling, FS = 1100 psi @ 1.9 bpm, 11,700.0 11,816.0 09:00 11:30 CWT = 5.81K, WOB = 1.4K, annular = 3815 psi, WHIR = 62 psi, pump = 4667 psi, PUW = 38K from 11,805', hard drilling at 11,805' (-0 fph working through), 137 API gamma spike at 11,795', avg ROP = 46 fph 5/14/2019 5/14/2019 3.50 PROD2 DRILL DRLG T Drilling, CWT =4.7K, WOB =1K, 11,816.0 12,023.0 11:30 15:00 annular = 3853 psi, pump = 4606 psi, back into hard spot at 11,971', avg ROP = 59 fah 5/14/2019 5/1412019 1.50 PROD2 DRILL DRLG T Drilling, CWT =0.8K, WOB =1K, 12,023.0 12,100.0 15:00 16:30 annular = 3885 psi, WHP = 70 psi, pump = 4640 psi, pump 5x5 sweeps, lost pump 1 momentarily at 12,077' (3 simultaneous errors on HMI, alert electrician), RUIN= 42K, close choke, dropped to 9.7 ppg, quickly regain pump & come right back to 11.4 ppg 5/14/2019 5/14/2019 0.20 PROD2 DRILL WPRT T Wiper up -hole, PUW = 35K 12,100.0 11,330.0 16:30 16:42 5/14/2019 5/14/2019 0.30 PROD2 DRILL WPRT T Wiper in-hole, RIW = 7.2K 11,330.0 12,100.0 16:42 17:00 5/14/2019 5/14/2019 2.70 PROD2 DRILL DRLG T Drilling, FS = 1050 psi @ 1.9 bpm, 12,100.0 12,255.0 17:00 19:42 CWT = 4.61K, WOB = 1.41K, annular = 3892 psi, WHIP = 50 psi, pump = 4848 psi, MM out drive gain percentage dirty, bypass & blow -down, RUIN = 39K from 12,255', avg ROP = 57 fph 5/14/2019 5/14/2019 3.90 PROD2 DRILL DRLG T Drilling, CWT = 1.41K, WOB 1.7K, 12,255.0 12,469.0 19:42 23:36 annular = 3878 psi, pump = 4877 psi 5/14/2019 5/15/2019 0.40 PROD2 DRILL DRLG T PU to check numbers and capture a 12,469.0 12,485.0 23:36 00:00 missed survey - PU Wt 35 k Ibs CT 4908 psi @ 1.86 bpm in and 1.85 bpm out, free spin diff 1040 psi, BHP 3945 psi, targeting 11.4 EMW, Wh 58 psi, IA 360 psi, OA 580 psi. CT WT 5.7 k lbs, WOB 2.8 k lbs 5/15/2019 5/15/2019 0.40 PROD2 DRILL DRLG T OBD CT 4908 psi @ 1.86 bpm in and 12,485.0 12.492.0 00:00 00:24 1.85 bpm out, free spin diff 1040 psi, BHP 3945 psi 5/15/2019 5/15/2019 1.60 PROD2 DRILL WPRT T PU Wt 34 k lbs PUH on third wipper 12,492.0 8,830.0 00:24 02:00 to the window for tie in. Pull neg WOB and Ct Wt overpulls at 9068 - 6977'. Jog hole to 8986 PUH to 8933 Jog to 9079' PUH, Bottoms up from trouble spot unloaded a largee amout of very fine cuttings. no rocks. 5/15/2019 5/15/2019 0.20 PROD2 DRILL DLOG T Tie int olhe RA tag for a +5' correction 8,827.0 8,852.0 02:00 02:12 5/15/2019 5/15/2019 1.40 PROD2 DRILL TRIP T RBIH, Cuttings ratio climbed from 1.7 8,852.0 12,497.0 02:12 03:36 to 1.9 and 2 bbls of solids returned on the trip. SID X2 @ 11,940' and 11,944' PU Wt 40 k, reduce rate and bounce through. 5/15/2019 5/15/2019 0.90 PROD2 DRILL DRLG T CT 4696 psi @ 1.85 bpm in and 1.82 12,497.0 12,537.0 03:36 04:30 bpm out, free spin diff 1032 psi, BHP 3928 psi, targeting 11.4 ppg EMW @ the window. OBD, CT -3.4 k lbs, WOB 1.28 k lbs Page 16134 ReportPrinted: 61512019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (flKa) End Depth (WB) 5/15/2019 5/15/2019 1.50 PROD2 DRILL DRLG P OBD, CT 4795 psi, CT Wt 4.7 k Ib, 12,537.0 12,600.0 04:30 06:00 WOB 1.0 k lbs ROP = 42 Whir 5/15/2019 5/15/2019 3.00 PROD2 DRILL DRLG P OBD, CT 4891 psi, CT Wt -0 k Ib, 12,600.0 12,713.0 06:00 09:00 WOB 0.6 it lbs, BHP 3958 psi. ROP = 37 ft/hr 5/15/2019 5/15/2019 3.00 PROM DRILL DRLG P OBD, CT 5088 psi, CT Wt -7 k Ib, 12,713.0 12,833.0 09:00 12:00 WOB 1.9 k lbs, BHP 3950 psi. ROP = 40 ft/hr 5/15/2019 5/15/2019 4.50 PROD2 DRILL DRLG P 12887' PU CT Wt 36 k lbs, RBIH 12,833.0 12,907.0 12:00 16:30 pump 5x5 CT 5004 psi @ 1.87 bpm in and 1.86bpm Free spin diff 1119 psi, BHP 3983 psi, WH 30 psi, IA 458 psi, OA 687 psi OBD CT Wt 3 k Ib, WOB 2.9 k lbs, ROP = Whir 5/15/2019 5/15/2019 0.40 PROD2 DRILL WPRT P PU Wt 36 k lbs PUH on 1 000'wiper 12,907.0 11,900.0 16:30 16:54 1 #1 5/15/2019 5/15/2019 0.40 PROD2 DRILL WPRT P RBIH @ 1 bpm and 24 ft/min. 11,900.0 12,907.0 16:54 17:18 5/15/2019 5/15/2019 2.70 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 5,227 psi, 12,907.0 12,931.4 17:18 20:00 Diff --1,037 psi, WHP=88, BHP=4,016, IA=478, OA=690, slow ROP 3-26 fph, PUW 40 k 5/15/2019 5/15/2019 0.30 PROD2 DRILL WPRT P Stall motor x2, PU heavy, Bit Stuck, 12,931.4 12,530.0 20:00 20:18 set back down to zero surface weight, PUH 68 k, DHWOB=minus 12.6 k, PUH slowly, reboot Rig Watch computers, (WITS is down) 5/15/2019 5/15/2019 0.50 PROD2 DRILL WPRT T Continue PUH, unable to restart rig 12,531.0 12,931.4 20:18 20:48 watch without rebooting server, RBIH to drill ahead without Rig Watch. 5/15/2019 5/15/2019 2.90 PROM DRILL DRLG P BOBD, 1.9 bpm at 5,227 psi, 12,931.4 12,941.0 20:48 23:42 Diff=1,076 psi, WHP=88, BHP=4,042, IA=478, OA=690 5/15/2019 5/16/2019 0.30 PROD2 DRILL WPRT P L2 Lateral TD called early, due to low 12,941.0 12,867.0 23:42 00:00 ROP/Formation, circulate TD sweep down hole, 5/16/2019 5/16/2019 1.75 PROD2 DRILL WPRT P Perform wiper to the window chasing 12,867.0 8,800.0 00:00 01:45 1 1 1 sweeps, perform jog with 5x5 sweep 5/16/2019 5/16/2019 2.25 PROD2 DRILL TRIP P Continue wiper to the swab valve, 8,800.0 78.2 01:45 04:00 Bump up and reset depth. 5/16/2019 5/16/2019 1.80 PROD2 DRILL TRIP P RIH to confirm TD, lay in weighted 78.2 8,740.0 04:00 05:48 liner running pill,and KW. 5/16/2019 5/16/2019 0.20 PROD2 DRILL DLOG P Tie into the K1 for 4.5' corrctio. 8,740.0 8,769.7 05:48 06:00 5/16/2019 5/16/2019 0.60 PROD2 DRILL DLOG P RIH and park @ 8,800.14' CTMD and 8,769.7 8,800.1 06:00 06:36 6,027.24' TVD of sensor. Trap 3626 psi observe pressure build to 3629 psi in 2 min. Bleed to 3535 psi and obsery build to 3569 psi in 6 min. Bleed to 3491 psi and obsery build and stabilize at 3577 psi over 30 min. ••• BHP 11.41 ppg EMW 5/16/2019 5/16/2019 1.50 PROM DRILL TRIP P PU Wt, 32 k lbs 8,800.1 12,936.0 06:36 08:06 Continue to RIH, window, billet clean. pen hole clean. Slight WOB bounce @ 12,177' Set down three times @ 12936'- 5/1612019 5/16/2019 2.20 PROD2 DRILL TRIP P Loiter while LRP and KWF are 12,936.0 12,818.0 08:06 10:18 weighted up. Page 17134 Report Printed: 6/5/2019 Uperations Summary (with Timelog Depths) 2E-17 I& Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stint Tim End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation MKB) End Depth(fiKB) 5/16/2019 5/16/2019 0.30 PROD2 DRILL DISP P Tum the coil over to 11.6+ wieighle 12,818.0 12,933.0 10:18 10:36 beaded liner running pill 5/16/2019 5/16/2019 1.60 PROD2 DRILL DISP P PUH laying in liner running pill and 12,933.0 8,818.0 10:36 12:12 painting flags 11,552'- neg WOB 1.5k Park and paint Yellow flag @ 11,453.26- 11281 - neg WOB 1.2 k Error With pumping /pulling speeds, KW fluid exiting the n=le @ 9250' Diluting LRP with KW - lost prime, regained - Window clean 5/16/2019 5/16/2019 1.40 PROD2 DRILL DISP P Continue to PUH laying in KW fluid. 8,818.0 72.0 12:12 1336 Paint yellow flag @ 7278.14 5/16/2019 5/16/2019 1.30 PROD2 DRILL PULD P Park short to inspect pipe. Open up to 72.0 0.0 1336 1454 the catch drum on the floor - Flow check - Good LD BHA# 17 over a dead well. 5/16/2019 5/16/2019 0.50 COMM CASING PUTB P Prep floor to start picking up liner. 0.0 0.0 14:54 15:24 5/16/2019 5/16/2019 3.00 COMM CASING PUTB P PU Lower L2 completion, 50 slotted 0.0 1,512.7 15:24 18:24 joints under a shorty deployment sleeve w non -ported bullnose. 5/16/2019 5/16/2019 0.50 COMM CASING PULD P PJSM, PU/MU CoilTrak tools with 1,512.7 1,556.9 18:24 18:54 BOT 3" GS spear 5/16/2019 5/16/2019 1.50 COMM CASING RUNL P RIH 1,556.9 8,765.9 18:54 20:24 5/16/2019 5/16/2019 0.20 COMM CASING RUNL P Correct to the EDP - 9', PUW 32 k 8,765.9 8,756.7 20:24 20:36 5/16/2019 5/16/2019 1.10 COMM CASING RUNL P Continue IH 8,756.7 12,950.0 20:36 21:42 5/16/2019 5/16/2019 0.20 COMM CASING RUNL P PUW 42k, DHWOB, -5.3k, set down 12,950.0 11,420.8 21:42 21:54 12,943.96', BHI depth counter quit working, continue IH to 12,950' Nabors depth, BHI depth changed to 12,950', bring pump online 1.6 bpm, 0.6 bpm returns, Di"- 61, PUW 32 k, DHWOB=0.6k, remove liner length from counters, line up across the top 5/16/2019 5/16/2019 1.50 COMM CASING TRIP P PUH @ 50 fpm, PUW 33 k 11,420.8 8,716.0 21:54 23:24 5/16/2019 5/16/2019 0.20 COMM CASING DLOG P Log the K1 marker plus 3.5' 8,716.0 8,716.0 23:24 23:36 5/16/2019 5/17/2019 0.40 COMM CASING TRIP P POOH 8,716.0 3,428.0 23:36 00:00 5/17/2019 5/17/2019 0.60 COMM CASING TRIP P Continue POOH 3,428.0 44.2 00:00 00:36 5/17/2019 5/17/2019 0.50 COMM CASING OWFF P At surface, monlior well for flow, PSJM 44.2 44.2 00:36 01:06 5/17/2019 5/17/2019 0.50 COMPZ2 CASING PULD P LD BHA#18 setting tools over a dead 44.2 0.0 01:06 01:36 well 5/17/2019 5/17/2019 0.25 COMM CASING CTOP P Inspect INJH, and Coiled Tubing 0.0 0.0 01:36 01:51 5/17/2019 5/17/2019 0.30 COMM CASING PUTB P Prep RF for Liner OPS, PJSM 0.0 0.0 01:51 02:09 5/17/2019 5/17/2019 3.40 COMPZ2 CASING PUTB P PU/MU L2 Upper liner segment w/71 0.0 02:09 0533 joints of slotted liner 5/17/2019 5/17/2019 0.80 COMM CASING PULD P PU Coiltrack, check packoffs, set 0.0 2,192.0 05:33 06:21 counters, WOB -6.93 5/17/2019 5/17/2019 1.00 COMM CASING RUNL P RIH 2,192.0 8,700.1 06:21 07:21 1 1 Page 18/34 Report Printed; 61512019 • Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth De start Tlme End Tbne Our h (d Phase Op Cada Adivily Cade Time P -T -X Operation (rt End Depth (flKB) 5/17/2019 5/17/2019 0.20 COMPZ2 CASING DLOG P Tie into white flag for -7.15' correction. 8,700.1 8,693.0 07:21 07:33 5/17/2019 5/17/2019 0.80 COMPZ2 CASING RUNL P PU Wt 31 k lbs -9k WOB continue to 8,693.0 10,870.0 07:33 08:21 RIH 5/17/2019 5/17/2019 0.10 COMPZ2 CASING DLOG P Tie into the Kt for -1.5' 10,870.0 10,893.0 08:21 08:27 5/17/2019 5/17/2019 0.40 COMPZ2 CASING RUNL P Continue to RIH, SID 4.5 k lbs WOB, 10,893.0 11,436.0 08:27 08:51 PO Weight 40 it, S/D 4.7 k WOB, discuss depths, On line W pump, 1.5 bpm, diff to 1000 psi, PU, Ct Wt 26 k - Release off of liner 5/17/2019 5/17/2019 1.70 COMPZ2 CASING TRIP P PUH, reset depth counter, continue 11,436.0 72.0 08:51 10:33 out of hole. 5/17/2019 5/17/2019 1.10 COMPZ2 CASING PULD P Al surface, Flow check, Inspect pipe 72.0 0.0 10:33 11:39 again - good. Lay down BHA#19. 5/17/2019 5/17/2019 1.90 PROD3 STK CTOP P PJSM, Hidden agitator test, MU 6' pup 0.0 0.0 11:39 13:33 with ported bull nose to shorty deployment sleeve in mouse hole under cart. MU assembly to blind sub. Skid cart, stab injector. RIH with pup spaced out across the bag, measure PU and RIH wt 5.5k/2 k respectively. Close Annular to 1500 psi Push Pull test to -2k/ 8 k respectively. Roll pump min rate to establish returns. Increase pump rate to 1 bpm,( vibrations rolling BHI counter) zero Nabors counters, attempt to PU, n release, go to neural, increase rate to 1.5 bpm, PU and release from GS. S/I pump, RBIH, observe latch up of GS on weight indicator, PU to 10 k confirm latch. Neutral weight, open annular, pop off, un stab, and rig down. 5/17/2019 5/17/2019 1.20 PROD3 STK PULD P PU BHA #20 over a dead well. Had to 0.0 72.0 13:33 14:45 fight the BHA a little to get it in the hole. Skid cart, stab injector, check pack offs 5/17/2019 5/17/2019 1.90 PROD3 STK TRIP P RIH w build BHA. 72.0 8,740.0 14:45 16:39 5/17/2019 5/17/2019 0.20 PROD3 STK DLOG P Tie int the K1 for -7' correction. 8,740.0 8,758.0 16:39 16:51 5/17/2019 5/17/2019 1.00 PROD3 STK DISP P Park and open EDC, displace KW fluid 8,758.0 8,758.0 16:51 17:51 from wellbore with drilling mud - Gose EDC 5/17/2019 5/17/2019 0.50 PROD3 STK TRIP P Continue IH through window, dry tag 8,758.0 9,286.0 17:51 18:21 TOB @ 9,286', PUW 30 k 5/17/2019 5/17/2019 0.70 PROD3 STK MILL P Start kicking off billet @ 9,285.5', 1.81 9,286.0 9,286.7 18:21 19:03 bpm at 4,249 psi, Diff=496 psi, WHP=19, BHP=3,779, IA=O, OA=12 5/17/2019 5/17/2019 0.70 PROD3 STK MILL P Time milling 2 fl/hr 9,286.7 9,287.7 19:03 19:45 5/17/2019 5/17/2019 0.50 PROD3 STK MILL P Time milling 3 ft/hr 9,287.7 9,289.0 19:45 20:15 5/17/2019 5/17/2019 0.60 PROD3 STK MILL P Time milling 10 ff/hr 9,289.0 9,293.0 20:15 20:51 1 I 5/17/2019 5/17/2019 0.40 PROD3 STK DRLG P Start pushing on it, ratty drilling, no diff 9,293.0 9,298.0 20:51 21:15 and high WOB, work to drill ahead, clean PU's trouble getting back to bottom. Page 19134 Report Printed: 615/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start De Start Time End Time our (hr) Phase Op Code Ac1rvfiy Coda Time P -T-% Operation (n B) End Depth (fixe) 5/17/2019 5/17/2019 0.20 PRODS STK WPRT T PUH, PUW 33 k, PUH min rate, 9,298.0 9,298.0 21:15 21:27 dragging -1.2 k - 3.5 k, attempt to dry drift billet area, set down 9,290', 4.9 k, PUH dean, bring pump up to 1.8 bpm, continue back to bottom, seeing weight spikes @ 9,290'-9,298' 5/17/2019 5/1812019 2.55 PROD3 STK DRLG T BOBD, 1.8 bpm at 4,145 psi, Diff -486 9,298.0 9,336.0 21:27 00:00 psi, WHP=20, BHP=3,663, IA=10, OA=298 5/18/2019 5/1812019 0.50 PRODS STK DRLG T OBD, 1.8 bpm at 4,145 psi, Diff=515, 9,336.0 9,350.0 00:00 00:30 WHP=88, BHP=3,667, IA=33, OA=315 5/18/2019 5/18/2019 0.40 PRODS STK WPRT T PUH, PUW 38 k, pull above billet, 9,350.0 9,350.0 00:30 00:54 dragging up hole -3.6 k, clean above billet, RBIH, set down 4.6 k, popped by, continue IH 5/18/2019 511812019 4.00 PRODS STK DRLG T BOBD, 1.8 bpm at 4,145 psi, Diff -486 9,350.0 9,450.0 00:54 04:54 psi, WHP=20, BHP=3,663, IA=10, OA=298 5/1812019 511812019 1.50 PRODS STK DRLG T OBD, 1.9 bpm at 4,446 psi, Diff=728, 9,450.0 9,509.0 04:54 06:24 WHP=85, BHP=3,689, IA=148, OA=441 5/18/2019 5/18/2019 0.80 PRODS STK WPRT T PU Wt 37 k lbs, PUH pumping 10 x 10 9,509.0 8,833.0 06:24 07:12 sweep to clean up hole for second billet set. 5/18/2019 5/18/2019 0.40 PRODS STK TRIP T RBIH to billet, dry drift, SID @ 9288.3' 8,833.0 9,288.0 07:12 07:36 4 k lbs, 5118/2019 5/1812019 1.80 PRODS STK TRIP T POOH, park @ 8711' to open EDC. 9,288.0 64.0 07:36 09:24 POOH pumping 1.85 bpm, jog cased hole at 600' 5/1812019 5/1812019 1.40 PRODS STK PULD T PUD BHA 20, Lt drilling assembly, 64.0 0.0 09:24 10:48 blow down and flush motor. 5/18/2019 511812019 1.20 PRODS STK PULD T PU J setting tool, billet and openhole 0.0 0.0 10:48 12:00 anchors 5/18/2019 5118/2019 0.20 PRODS STK WAIT T Wait on perforating of 10' pup, drilled 0.0 0.0 12:00 12:12 6 SPF, 30° phasing w 1/2" holes. 5/18/2019 5/18/2019 1.00 PRODS STK PULD T PD BHA# 21, check packoffs, - 0.0 82.9 12:12 13:12 replace, stab Injector, bump up, 5/18/2019 5/18/2019 2.00 PRODS STK TRIP T RIH @ 80 ft/min with anchored billet 82.9 8,770.0 13:12 15:12 and 10.07' perforated pup ober a solid bullnose ( LOA 21.89') 5/1812019 5/1812019 0.20 PRODS STK DLOG T Tie into the K1 for a - 6' correction. 8,770.0 8,780.7 15:12 15:24 5/18/2019 5118/2019 0.20 PRODS STK TRIP T PU Wt 33 k lbs. Pumps off, Close 8,780.7 9,291.7 15:24 15:36 EDC, RIH through window - dean, continue in hole to 9253' PU Wt 35 k lbs. RIH to 5/182019 5/18/2019 0.20 PRODS STK WPST T Orient slips to 180 ° ROHS, Ct Wt 14 k 9,291.7 9,291.7 15:36 15:48 lbs, WOB 2.14. Pick up to neutral, 33 k - WOB 1.35 k lbs, CT 1031 psi, WH 557 psi Stage CT up to 2300 psi, Come online with the pump, observe shear @ 4,200 psi, WOB 0.77, Slack off, stack 3 k lbs on billet - good PU 33 k lbs. 5/18/2019 5118/2019 2.30 PRODS STK TRIP T POOH 9,291.7 72.0 15:48 18:06 5/18/2019 5/182019 0.20 PRODS STK PULD T At surface, space out, unstab INJH 72.0 72.2 18:06 18:18 5/1812019 5/18/2019 1.50 PRODS STK PULD T PUD setting tools 72.2 0.0 18:18 19:48 Page 20/34 Report Printed: 6/512019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Steri Time End Mme our (hr) Pheae Op Code amity Cafe Time P -T -X Operation Start Depth (MB) End Depth (MB) 5/18/2019 5/18/2019 0.75 PROD3 STK CTOP T Inspect coil, min 0.125", switch out 0.0 0.0 19:48 20:33 BHI upper quick (houred out), wire slide out too far, trim and re -boot, install UQC. double check float valves, makeupttorque flow sub 5/18/2019 5/18/2019 2.00 PROD3 STK PULD T PD kickoff/Drilling BHA #22 0.0 78.3 20:33 22:33 5/18/2019 5/1912019 1.46 PRODS STK TRIP T Tag up, reset counters, RIH, testing 78.3 7,592.0 22:33 00:00 1 1 1 agitator @ 522', obtain snap shots 5/19/2019 5/19/2019 0.15 PRODS STK TRIP T Continue IH 7,592.0 8,740.0 00:00 00:09 5/19/2019 5/19/2019 0.20 PROD3 STK DLOG T Log the K1 marker correction of -6.0' 8,740.0 8,780.0 00:09 00:21 5/19/2019 5/19/2019 0.50 PROD3 STK TRIP T Dry tag TOB @ 9,269' 8,780.0 9,268.4 00:21 00:51 5/1912019 5119/2019 0.60 PROD3 STK MILL T 9,268.4', Start milling @ 1.85 bpm @ 9,268.4 9,272.4 00:51 01:27 4,742 psi, Diff --1,029 psi, WHP=24, BHP= 3,651, IA=O, OA=12 9,268.5', stall motor, PUW 34 k, restart 5/19/2019 5/19/2019 1.90 PRODS STK MILL T 1 ft/hr, 2 tUhr, 3 ft/hr with no to little 9,272.4 9,271.4 01:27 03:21 WOB, 1.9 bpm @ 4,769 psi, Diff -1,030 psi, WHP=64, IA=O, OA=165 5/19/2019 5/1912019 0.35 PROD3 STK MILL T 10 f 1hr, 1.88 bpm at 4,769 psi, 9,271.4 9,274.4 03:21 03:42 Dlff=1,030 psi, WHP=64, BHP=3,652, IA=O, OA=164 5/19/2019 5/19/2019 0.85 PROD3 DRILL DRLG T Drill ahead 1.89 bpm at 5,018 psi, 9,274.4 9,306.5 03:42 04:33 Diff --1,220 psi, WHP=66, BHP=3,673, IA=O, 0A=1 71 5119/2019 5/19/2019 2.23 PROD3 DRILL DRLG T PUH, PUW 42 k restart 1.89 bpm at 9,306.5 9,369.0 04:33 06:46 4,749 psi, Diff --1,058 psi, WHP=71, BHP=3,672, IA=O, OA=224- pump 5x5 sweep in anticipation of billet dry drift. 5/19/2019 5/19/2019 0.30 PROD3 DRILL WPRT T PU Wt 35 k lbs, PUH to dry drift billet, 9,369.0 9,369.0 06:46 07:04 drag neg WOB up to -9.7 k lbs then fell to -1.3 k lbs all the way up hole. Billet clean, neg weight appears to be hole / geometry related. RBIH, Hole ratty, stacking out, once @ 9280', PU and run past billet, fight way back t bottom, again it appears to be hole / geometry related, not issues with the billet. 5/19/2019 5/19/2019 4.00 PROD3 DRILL DRLG T CT 4837 psi @ 1.86 bpm in nd 1.83 9,369.0 9,509.0 07:04 11:04 bpm out, free spin diff 1213 psi, BOBD, CT Wt 11-8 k lbs, WOB 0.4 to 3+ k lbs, indication of BHA sticking, WOB with no diff, tubing up low vis sweeps W 2% Low torque/ 776. ROP = 35 fUhr - ratty drilling 5/19/2019 5/19/2019 0.30 PRODS DRILL DRLG P OBD, CT 5109 psi @ 1.86 bpm, BHP 9,509.0 9,550.0 11:04 11:22 3691 psi, holding 11.45 EMW at the window, CT Wt 9 k lbs, WOB highly variable to 3 k lbs. - pump 5x5 in anticipation of build TD ROP - 164 ft/hr 5/19/2019 5/19/2019 0.70 PROD3 DRILL WPRT P PU Wt 34 k lbs, POOH chasing 9,550.0 8,637.0 11:22 12:04 sweeps for lateral drilling assembly. " Pulled 12 k overr CT wt and -8 k WOB @ 8976' RBIH, SID, work pipe, PUH. Same trouble spot as seen on previous L2 lateral. Page 21134 Report Printed: 6/5/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Da(Irn Pttese Op Code Activity Cotle Time P-T-X O re11on pe Stan DepUn (WB) End DepN (ftKB) 5/1912019 5/19/2019 1.70 PROD3 DRILL TRIP P Park, Open EDC, Pooh pumping 8,637.0 72.0 12:04 13:46 1.90bpm in and getting 1.45 bpm out, jogged at 500' bumped up spaced out. 749 psi WH 5/19/2019 5/19/2019 0.70 PROD3 DRILL PULD P PUD BHA# 22, high bend build 72.0 72.0 13:46 14:28 assembly. 5/19/2019 5/19/2019 1.80 PROD3 DRILL CTOP T 2.5 ° AKO motor hung up in well/stack 72.0 72.0 14:28 16:16 on the way out, inbetween wrap 14 and 15 on the slickline drum. While working wire slick line parted and tool fell 47' to the no go ring. Make notifications, discuss plan forward, inspect PDL sheave to verify wire in track ad not damagd. Attach chic-ago clamp to wire w/ sash cord lanyard run to rig floor. 5119/2019 5/1912019 1.80 PROD3 DRILL CTOP T Close 2-3/8" rams, unstring ODS PDL 72.0 72.0 16:16 18:04 from stump to expose SIL confection and top of BHA in no go ring. 5/19/2019 5/19/2019 0.30 PROD3 DRILL PULD T Crew Changeout, PJSM for out of 72.0 72.0 18:04 18:22 scope work 5/19/2019 5/19/2019 1.00 PROD3 DRILL PULD T Pressure up on PDL, function open 72.0 72.0 18:22 19:22 deployment rams, properly space out tools, function closed deployment rams, bleed pressure, brake off PDL lubricator, plug into CoilTrak tools wttest cable (good-test), slide card forward, MU to tools, perform surface Vest (good-test) 5/19/2019 5/19/2019 1.75 PROD3 DRILL TRIP T Tag up, reset counters, RIH 72.0 8,740.0 19:22 21:07 Niote: Tag and S/D at 8,235', 8 k DHWOB, PUW 29 k 8669' 5/19/2019 5/19/2019 0.20 PROD3 DRILL TRIP T Log the K1 marker correction of minus 8,740.0 8,785.0 21:07 21:19 7.0' 5/19/2019 5/19/2019 0.50 PROD3 DRILL TRIP T Perform static pressure survey 8,785.0 8,785.0 21:19 21:49 6,015.83' TVD, 11.564 ppg, WHP=692 5/19/2019 5/19/2019 0.60 PROD3 DRILL DISP T Displace well to 11.7 ppg completion 8,785.0 8,795.0 21:49 22:25 fluid 5/19/2019 5/19/2019 0.60 PROD3 DRILL TRIP T Continue displacing well to 11.68 ppg, 8,795.0 5,997.4 22:25 23:01 while POOH 5/19/2019 5/20/2019 0.97 PROD3 DRILL TRIP T Park and check well for flow 5,997.4 5,997.4 23:01 00:00 5/20/2019 5/20/2019 0.30 PROD3 DRILL TRIP T Continue flow check (no-flow) 5,997.4 5,997.4 00:00 00:18 5/20/2019 5/20/2019 1.00 PROD3 DRILL TRIP T POOH 5,997.4 78.3 00:18 01:18 5/20/2019 5/20/2019 0.50 PROD3 DRILL OWFF T At surface, perform flow check, PJSM 78.3 78.3 01:18 01:48 5/20/2019 5/20/2019 0.50 PROD3 DRILL PULD T LD build assembly on a dead well. 78.3 0.0 01:48 02:18 5/20/2019 5/20/2019 0.20 PROD3 DRILL CTOP P Perform BOPE Function test 0.0 0.0 02:18 02:30 5/20/2019 5/20/2019 0.75 PROD3 DRILL PULD P PD Lateral Drilling Assembly 0.0 80.2 02:30 03:15 512012019 5/20/2019 1.70 PROD3 DRILL TRIP P Tag up, reset counters, RIH, surface 80.2 8,740.0 03:15 04:57 test stryder @ 502' 5/20/2019 5/20/2019 0.20 PROD3 DRILL DLOG P Log the K1 marker for depth control - 8,740.0 8,788.0 04:57 05:09 8.5' correction. Page 22134 Report Printed: 615/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time EM Time our inn Phase Op Code Activity Code Time P -T -X Operation Start (ftKS)pth End Depth(fIKB) 5/20/2019 5/20/2019 0.90 FROM DRILL DISP P Continue to tum wel over to new 8,788.0 8,753.0 05:09 06:03 drilling mud. Park and Gose EDC. "' New mud at the bit 9550'. 5/20/2019 5/20/2019 0.40 PRODS DRILL TRIP P Run into open hole, window clean. 8,753.0 9,550.0 06:03 06:27 Wob spike @ 9076', 4.7k lbs, plus CT Wt s/d, bounce through with reduced rate, Billet clean 5/20/2019 5/20/2019 5.50 FROM DRILL DRLG P CT 4117 psi @ 1.83 bpm in and 1.83 9,550.0 9,778.0 06:27 11:57 bpm out, free spin diff 735 psi - note Strider tool. BHP 3750 psi, targeting 11.6 ppg EMW. OBD CT Wt 7 k lbs and 2.5 k WOB. 9596'- PU 32 k lbs 9614'- PU 34k lbs 9680'- PU 35k lbs ROP = 41 It/hr 5/20/2019 5/20/2019 3.05 PRODS DRILL DRLG P CT 4247 psi @ 1.83 bpm in BHP 9,778.0 9,850.0 11:57 15:00 3768 psi, targeting 11.6 ppg EMW. CT Wt 3.8 k lbs and 3 k WOB. 9794'- PU 34k lbs 9837'- PU 33k lbs 5/20/2019 5/20/2019 5.00 FROM DRILL DRLG P CT 4247 psi @ 1.83 bpm in BHP 9,850.0 9,950.0 15:00 20:00 3768 psi, targeting 11.6 ppg EMW. CT Wt 3.8 k lbs and 3 k WOB. 9892'- PU Wt 351 lbs 5/20/2019 5/20/2019 0.20 FROM DRILL WPRT P PU Wt 35 k lbs, wiper trip #1 9,950.0 9,300.0 20:00 20:12 -WOB lug 5/20/2019 5/20/2019 0.20 FROM DRILL WPRT P RBH 9,300.0 9,950.0 20:12 20:24 5/20/2019 5/20/2019 1.80 FROM DRILL DRLG P CT 4310 psi @ 1.87 bpm in and 1.86 9,950.0 10,030.0 2024 22:12 bpm out, free spin 724 psi, BHP 3782 psi, holding 11.6 ppg EMW at the window, WH 150 psi, IA 235 psi OA 513 psi, CT 6 k lbs, WOB 1.5 k lbs 5/20/2019 5/20/2019 0.70 FROM DRILL WPRT P PU Wt 34 k lbs, smelled something 10,030.0 8,740.0 22:12 22:54 hot in the service VFD room, pulled wiper to window for tie in. Pulled neg WOB to -11 k CT Wt overpull 16 k lbs, at 9065 and again at 8961. Continue up hole. 5/20/2019 5/20/2019 0.20 FROM DRILL DLOG P Tie into the K1 for +2' correction 8,740.0 8,780.0 22:54 23:06 5/20/2019 5/20/2019 0.50 FROM DRILL TRIP P RBIH 8,780.0 10,030.0 23:06 23:36 Found seized cooling fan in VFD room. SID x3 @ 9464' popped throug with TF @ 60 ROHS 5/20/2019 5/21/2019 0.40 FROM DRILL DRLG P 4278 psi @ 1.87 bpm, free spin diff 10,030.0 10,052.0 23:36 00:00 718 psi, BHP 3783, CT W17.7 k lbs, WOB 1.1 k lbs 5/21/2019 5/21/2019 2.00 FROM DRILL DRLG P OBD, 1.87 bpm at 4,308 psi, Diff=953 10,052.0 10,148.0 00:00 02:00 psi, WHP=136, BHP=3,800, IA=326, OA=592 5/21/2019 5/21/2019 2.00 FROM DRILL DRLG P OBD, 1.87 bpm at 4,308 psi, Diff -953 10,148.0 10,242.0 02:00 04:00 psi, WHP=136, BHP=3,800, IA=326, OA=592 Page 23134 ReportPrinted: 6/512019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stert Depth De Start Time End Time Dur hr ( ) Phase O Code p Acd Code vtty Time P -T -X Operation (n End Depth (fiKB) 5/21/2019 5/21/2019 2.00 PRODS DRILL DRLG P OBD, 1.87 bpm at 4,308 psi, Diff --953 10,242.0 10,316.0 04:00 06:00 psi, WHP=136, BHP=3,800, IA=326, OA=592 PiU @ 10,263', PUW 33 k PU @ 10.292', PUW 33 k 5/21/2019 5121/2019 2.00 PROD3 DRILL DRLG P OBD, 1.87 bpm at 4,308 psi, Diff --953 10,316.0 10,381.0 06:00 08:00 psi, WHP=136, BHP=3,800, IA=326, OA=592 PU @ 10,330', PUW 34 k 5/21/2019 5/21/2019 1.20 PRODS DRILL DRLG P OBD, 1.87 bpm at 4,308 psi, Diff=953 10,381.0 10,430.0 08:00 09:12 psi, WHP=136, BHP=3,800, IA=326, OA=592 PU @ 10,398', PUW 35 k 5/21/2019 5/21/2019 0.30 PRODS DRILL WPRT P Wiper up hole to 9,550', PUW 37 k 10,430.0 9,550.0 09:12 09:30 5/2112019 5/21/2019 0.30 PRODS DRILL WPRT P Wiper back in hole, RIW 6 k 9,550.0 10,430.0 09:30 09:48 5/21/2019 5/21/2019 2.00 PROD3 DRILL DRLG P BOBD, 1.87 bpm at 4,616 psi, 10,430.0 10,511.0 09:48 11:48 Diff --720 psi, WHP=145, BHP=3,806, IA=416, OA=669 5/21/2019 5/21/2019 2.00 PRODS DRILL DRLG P BOBD, 1.87 bpm at 4,616 psi, 10,511.0 10,616.0 11:48 13:48 Diff --720 psi, WHP=145, BHP=3,806, IA=416, OA=669 PU @ 10,521', PUW 34 k 5/21/2019 5/21/2019 2.00 PROD3 DRILL DRLG P BOBD, 1.87 bpm at 4,705 psi, 10,616.0 10,728.0 13:48 15:48 Diff -720 psi, WHP=129, BHP=3,818, IA=500, OA=730 5/21/2019 5121/2019 2.80 PROD3 DRILL DRLG P OBD, 1.85 bpm at 4,599 psi, Diff --862 10,728.0 10,813.0 15:48 18:36 psi, WHP=129, BHP=3,824, IA=537, OA=762 5/21/2019 5/21/2019 1.00 PROD3 DRILL WPRT P Pull 1000'wiper tripLow ROP, Low 10,813.0 10,813.0 18:36 19:36 DHWOB, PUW=35K 5121/2019 5/21/2019 2.30 PROD3 DRILL DRLG P 10813', Drill, 1.9 BPM 4661 PSI FS, 10,813.0 10,904.0 19:36 21:54 BHP=3815 5/21/2019 5/22/2019 2.10 PRODS DRILL DRLG P 10904', Drill, 1.9 BPM @ 4661 PS, 10,904.0 10,958.0 21:54 00:00 RIW=-1.8K, DHWOB=.8K, ROP -20 FPH 5/22/2019 5/22/2019 1.90 PRODS DRILL DRLG P 10958', Drill, 1.9 BPM @ 4661 PSI 10,958.0 11,023.0 00:00 01:54 FS, BHP=3878, RIW=1.2K, DHWOB=I.2K 5122/2019 5/22/2019 2.30 PRODS DRILL DRLG P 11,023' Drill, 1.9 BPM @ 4661 PSI FS, 11,023.0 11,076.0 01:54 04:12 PJSM. Line up pits to swap mud, Start taking mud to TT. Trucks enroute 5/22/2019 5/22/2019 0.40 PRODS DRILL DRLG P 11076', Drill, 1.9 BPM @ 4661 PSI FS, 11,076.0 11,083.0 04:12 04:36 BHP=3837, New mud going down CT 5/22/2019 5/22/2019 4.30 PRODS DRILL DRLG P 11,083, Drilling, New mud at bit, 11,083.0 11,196.0 04:36 08:54 continue drilling ahead 1.9 bpm at 4,572 psi, Diff --822 psi, WHP=211, BHP=3,847, IA=508, OA=725 5/22/2019 5/22/2019 0.90 PRODS DRILL DRLG P OBD, 1.92 bpm at 4,629 psi, Diff=888, 11,196.0 11,219.0 08:54 09:48 WHP=221, BHP=3,827, IA=508, OA=726 5/22/2019 5/22/2019 0.70 PRODS DRILL WPRT P Wiper to the window, PUW 33k. 11,219.0 8,830.0 09:48 10:30 5/22/2019 5/22/2019 0.20 PRODS DRILL DLOG P Log RA marker. Correction= +2.5'. 8,830.0 8,868.0 10:30 10:42 5/222019 5/22/2019 0.90 PRODS DRILL WPRT P Wiper back in hole. RIW 13k. 8,868.0 11,219.0 10:42 11:36 Page 24134 Report Printed: 61512019 Operations Summary (with Timelog Depths) 2E-17 Qg: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (VB) End Depth (WB) 5/22/2019 5/22/2019 7.00 PROD3 DRILL DRLG P BOBD, 1.9 bpm at 4.204 psi, Diff -662, 11,219.0 11,414.0 11:36 18:36 WHP=220, BHP=3,830, IA=450, OA=687 " Note: Noon Depth 11,237' 5/22/2019 5/22/2019 0.20 PRODS DRILL WPRT P Pull 300'wiper, PUW=34K 11,414.0 11,414.0 18:36 18:48 5/22/2019 5/22/2019 1.50 PRODS DRILL DRLG P 11,414', Drill, 1.9 BPM @ 4636 PSI 11,414.0 11,462.0 18:48 20:18 1 1 1 FS, BHP=3856 5/22/2019 5/22/2019 0.20 PRODS DRILL WPRT P Pull BHA wiper, PUW=35K 11,462.0 11,462.0 20:18 20:30 5/22/2019 5/23/2019 3.50 PRODS DRILL DRLG P 11,462', Drill, 1.87 BPM @ 4770 PSI 11,462.0 11,543.0 20:30 00:00 FS, BHP=3856 5/23/2019 5/23/2019 1.80 PRODS DRILL DRLG P 11543', Drill 1.87 BPM @ 4644 PSI 11,543.0 11,580.0 00:00 01:48 FS, BHP=3871 5/23/2019 5/23/2019 0.80 PRODS DRILL WPRT P Pull 1000' wipertdp, PUW=34K 11,580.0 11,578.0 01:48 02:36 5/23/2019 5/23/2019 2.00 PRODS DRILL DRLG P 11,578', Drill, 1.88 BPM @ 4704 PSI 11,578.0 11,667.0 02:36 04:36 FS, BHP=3889, RIW=-4.8K, DHWOB=2.3K 5/23/2019 5/23/2019 1.50 PRODS DRILL DRLG P 11667, Drilling break, ROP=110 FPH, 11,667.0 11,755.0 04:36 06:06 Started loosing fluid -.5 BPM. Healed up close to 1 to 1 5/23/2019 5/23/2019 2.00 PRODS DRILL DRLG P OBD, 1.88 bpm at 4,840 psi, Diff=719 11,755.0 11,824.0 06:06 08:06 psi, WHP=327, BHP=3,780, IA=499, OA=767 PU @ 11,765', PUW 35 k PU @ 11,841', PUW 33 k 5/23/2019 5/23/2019 0.75 PROD3 DRILL DRLG P OBD, 1.88 bpm at 4,840 psi, Diff --719 11,824.0 11,858.9 08:06 08:51 psi, WHP=327, BHP=3,780, IA=499, OA=767 5/23/2019 5/23/2019 0.20 PRODS DRILL WPRT P Stall motor, PUH, PUW 33 k, attempt 11,858.9 8,644.0 08:51 09:03 to bring pump back up x 4, motor still seems to be stalled, continue PUH slowley, 5/23/2019 5/23/2019 3.25 PRODS DRILL WPRT T Wiper to the window @ reduced 8,644.0 80.5- 09:03 12:18 speed (30 fpm), pumping 1.14 bpm at 3,591 psi, Diff -1,081. WHP=294, BHP=3,778, IA=477, OA=749 5/23/2019 5/23/2019 1.20 PRODS DRILL PULD T At surface, PJSM for LD BHA #23 80.3 0.0 12:18 13:30 5/2312019 5/23/2019 0.50 PRODS DRILL PULD T Inspect BHA assembly, BHI motor 0.0 0.0 13:30 14:00 lower bearing housing out of spec. 5/23/2019 5/23/2019 1.50 PRODS DRILL PULD T PU/PD drilling assembly BHA#24, 0.0 78.3 14:00 15:30 surface test CoilTrak tools (good -test) 5/23/2019 5/23/2019 1.70 PRODS DRILL TRIP T Tag up, reset counters, 78.3 8,740.0 15:30 17:12 5/2312019 5/23/2019 0.20 PRODS DRILL DLOG T Log formation (Kt), correction of -8.5', 8,740.0 8,765.0 17:12 17:24 PUW=31K, Swap pump 5/23/2019 5/23/2019 0.30 PRODS DRILL TRIP T Continue in well, Clean pass through 8,765.0 9,460.0 1724 17:42 window, Stack out @ 9460 5/23/2019 5/2312019 0.50 PROD3 DRILL TRIP T Work pipe, attempting to get past 9,460.0 9,460.0 17:42 18:12 9460. Try multiple TF's & speeds. Not going. Consult town. Decision made to drill through 5/23/2019 5/23/2019 0.30 PRODS DRILL TRIP T Bring on pumps, 1.88 BPM @ 4937 9,460.0 9,600.0 18:12 18:30 PSI FS, BHP=3725. TF=95° as drilled. Try motoring through @ 7-10 FPM Stall out. Retry and stall. Pick up try .3 BPM and pop throughRIH to end of build Page 25134 Report Printed: 615/2019 operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SiertTime End Time Dur (hr) Pheae Op Code Acdvdy Code Time P -T -X OpenMm Start Depth (dKB) End Depth (ftKB) 5/23/2019 5/23/2019 0.70 PRODS DRILL TRIP T Back ream area 9600-9380 with 9,600.0 9,380.0 18:30 19:12 sweeps. Multiple toolfaces. Area cleaned up 9460 dean 5/23/2019 5/23/2019 1.50 PROD3 DRILL TRIP T Trip in hole to drill 9,380.0 11,858.0 19:12 20:42 5/23/2019 5123/2019 2.80 PROD3 DRILL DRLG P 11858' Drill, 1.88 BPM @ 4936 PSI 11,858.0 11,988.0 20:42 23:30 FS, BHP=3896, RIW=-5.5K, DHWOB=.7K, ROP- 50 FPH 5123/2019 5/23/2019 0.30 PROD3 DRILL WPRT P Pull BHA wiper, PUW=36K, Had to 11,988.0 11,987.0 23:30 23:48 work to gel back to bottom. 5/23/2019 5/24/2019 0.20 PROD3 DRILL DRLG P 11987', Drill, 1.88 BPM @ 5080 PSI 11,987.0 11,998.0 23:48 00:00 FS, BHP=3919. Free spin pressure higher. Possible noule from working to bottom 5/24/2019 5/24/2019 2.20 PROD3 DRILL DRLG P 11998', Drill, 1.88 BPM @ 5080 PSI 11,996.0 12,100.0 00:00 02:12 FS, BHP=3915 5124/2019 5/24/2019 4.50 PRODS DRILL DRLG P 12100, Drilling, 1.88 BPM @ 5080 PSI 12,100.0 12,258.0 02:12 06:42 FS, BHP=3922. Well took a drink returns down to 1.5 BPM. Recovered to 1.7. Shift in resisivity in this area. 5/24/2019 5/242019 0.40 PROD3 DRILL WPRT P L1 Lateral TD called at 12,458' 12,258.0 12,167.0 06:42 07:06 circulate 10/10 TD sweep down hole. 5/24/2019 524/2019 1.10 PROD3 DRILL TRIP P Perform wiper to the window, chasing 12,167.0 8,875.0 07:06 08:12 sweeps. 5/24/2019 5/24/2019 3.00 PROD3 DRILL TRIP T Pull tight @ 8,875', top of BHA at 8,875.0 8,875.0 08:12 11:12 window, hung up. No circulation. Work pipe down, attempting to get free, squat down minus 18 k, bring pump up to full rate 1.5-1.9 bpm, with no returns, work coil down, decision was made to line up down the back side, bring WHIP up to 1,200 psi, popped free, got full string weight back, RIH to top of billet @ 9,269', PUH to 8,910' packed off, RBIH, set down weight popped free, establish returns again, 5/24/2019 5/24/2019 1.00 PROD3 DRILL WPRT T RIH, working back to bottom with 8,875.0 10,265.0 11:12 12:12 multiple set downs, 5/24/2019 5124/2019 0.50 PRODS DRILL WPRT T 10,265' Pull wiper up hole to 9,600', 10,265.0 9,600.0 12:12 12:42 PUW 39 k 5/2412019 524/2019 3.25 PRODS DRILL WPRT T RBIH, steering, multiple set downs, 9,600.0 12,257.0 12:42 15:57 9,047', 10,625', 10,401', and 11,990', circulate 10x10 sweep 5/24/2019 5/24/2019 3.70 PROD3 DRILL WPRT T Wiper to the window, PUW 36 k, 12,257.0 9,000.0 15:57 19:39 Pumping multiple sweeps, Full returns. Start overpull and packing off @ 9050. Unable to RBIH. Continue up, No DHWOB reaction. Try to RIH. Able to move uphole. Cannot RIH. Become stuck @ 9000'. No returns 5/242019 5/24/2019 0.60 PROD3 DRILL WPRT T Stuck @ 9000', reduce pump rate to .5 9,000.0 9,000.0 19:39 20:15 BPM. work pipe. Started getting returns. 524/2019 5/24/2019 2.00 PROD3 DRILL WPRT T Pull free at 41K up. RBIH to 8940' 9,000.0 8,940.0 20:15 22:15 Slack out and stuck @ 8940. Loose returns Work pipe. 5/24/2019 5/25/2019 1.75 PROD3 DRILL WPRT T Pump 7 BBIs down CT@.5 BPM. 8,940.0 8,940.0 22:15 00:00 Circulate to bit. Returns spotty 5/25/2019 5/25/2019 0.30 PROD3 DRILL WPRT T Continue Circulating 7 BBIs LVT down 8,940.0 8,940.0 00:00 00:181 ICT Page 26134 Report Printed: 6152019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Cade Acb0ty Cod. Time P -T -x Operation (MB) End DepM (NCB) 5/25/2019 5/25/2019 0.30 PRODS DRILL WPRT T Get 2 BBIs out ct and shut down. See 8,940.0 9,115.0 00:18 00:36 string weigh shift. Come free. Trip in hole to 9115. Very choppy with packing. Able to move fairly easy @ 120OPSI WHP 5/25/2019 5/25/2019 1.30 PROD3 DRILL WPRT T Tum around, PUW=31 K, WHP=1200, 9,115.0 8,868.0 00:36 01:54 PUH to 8868. Stuck, Work pipe, pump, and WHP. Unable to move 5/25/2019 5/25/2019 1.80 PRODS DRILL WPRT T Park @ 49K. Pump 7 BBIs LVT. .6 8,868.0 8,868.0 01:54 03:42 BPM in. .5 BPM out. Try to pump faster. Out rate would not increase with in rate. Let 2 BBIs out and soak, Work pipe -21K to 70K. 5/25/2019 5/25/2019 0.70 PRODS DRILL WPRT T Pump 2 more BBIs. Let soak, work 8,868.0 8,868.0 03:42 04:24 pipe, -10K to 70K 5/25/2019 5/25/2019 0.30 PRODS DRILL WPRT T Pump two more BSIs LVT out coil. Let 8,868.0 8,868.0 04:24 04:42 soak. Work pipe -10K to 75K. Line up and pump down backside. .8 BPM 1600 PSI WHP 5/25/2019 5/25/2019 0.20 PRODS DRILL WPRT T Work pipe while pumping down the 8,868.0 8,868.0 04:42 04:54 backside, shut down and dump wellhead pressure 5/25/2019 5/25/2019 1.00 PRODS DRILL WPRT T Shutdown and relax pipe and circulate 8,868.0 8,868.0 04:54 05:54 0.6 bpm in tention 50 k 5/25/2019 5/25/2019 1.50 PRODS DRILL WPRT T Circulate down the coil, squat down 8,868.0 8,868.0 05:54 07:24 weight -15 k, work pipe, dump wellhead pressure on up cycle x 3, attempt to dump on down cycle as well, with no movement 5/25/2019 5/25/2019 1.80 PROD3 DRILL WPRT T Circulate 7.0 bbls of LVT, 3 bbl out the 8,868.0 8,868.0 07:24 09:12 bit, shutdown & let soak for 20 min. .• Note: Inspect INJH, reel, and stack 5/25/2019 5/25/2019 1.00 PRODS DRILL WPRT T Work pipe up and down -15 k-78 k, 8,868.0 8,868.0 09:12 10:12 with no movement 5/25/2019 5/25/2019 4.00 PRODS DRILL WPRT T Call for 80 bbis of Dead Crude, 8,868.0 8,868.0 10:12 14:12 wroking pipe every hour 5/25/2019 5/25/2019 0.50 PROD3 DRILL WPRT T Little Red on location, move in and RU 8,868.0 8,868.0 14:12 14:42 1 1 Ito customer line, PT 4000 psi 5/25/2019 5/25/2019 2.00 PRODS DRILL WPRT T Circulate 40 bbls of crude into coil, 8,868.0 8,868.0 14:42 16:42 pump 10 bbls out the bit, soak for 20 mins, work pipe, pump additional 10 bbls, lel soak 15 mins, no movement, dump coil pressure fromm 812 psi to 0 psi, looks like the checks are holding, pull to 80 k 5/25/2019 5/25/2019 1.00 PROD3 DRILL WPRT T Line up down the backside, 1,400 psi 8,868.0 8,868.0 16:42 17:42 on the WHP, dump pressure quickly, work pipe w/no movement, liner back up to the coil pump 10 bbls 1.3 bpm @ 6,300 psi. Work pipe. Dump WHP. Work pipe 5/25/2019 5/25/2019 0.60 PRODS DRILL WPRT T Pump pipe in compression, -10K Let 8,868.0 8,868.0 17:42 18:18 1 relax 5/25/2019 5/25/2019 1.30 PRODS DRILL WPRT T Work pipe three cycles, 12K to -9 K. 8,868.0 8,868.0 18:18 19:36 Hold in tesnsion 68K. Line up and pump down back side. Work pipe down. 5/25/2019 5/25/2019 1.20 PRODS DRILL WPRT T Hook LRS back up and PT. Pump 40 8,868.0 8,868.0 19:36 20:48 BBIs crude down coil, Rig down and releae LRS Page 27134 ReportPrinted: 6/512019 -, Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Time End Time Dur (hr) Phase Op Code ACMY Corse Time P -T -X Openition sten Depth (WS) End Depth (itKB) 5/25/2019 5/25/2019 2.10 PRODS DRILL WPRT T Work pipe, 75K to -15K. Pump 20 8,868.0 8,868.0 20:48 22:54 BBIs crude out of coil. Put Coil in compression -16.5K. Let soak. Work pipe down 60K to -11 K. 5/25/2019 5/25/2019 0.30 FROM DRILL WPRT T Line up and pump down backside, 8,868.0 8,868.0 22:54 23:12 Work pipe down 42K to -17K 5/25/2019 5/25/2019 0.10 FROM DRILL WPRT T Work pipe up. a0emating pumping 8,868.0 8,868.0 23:12 23:18 down backside and dumping WHIP, 85K to -18K 5/25/2019 5/26/2019 0.70 PROD3 DRILL WPRT T Line up and circulate crude to tiger 8,868.0 8,868.0 23:18 00:00 tank. Work pipe 3X during circulation 5126/2019 5/26/2019 0.30 FROM DRILL WPRT T Complete circulating crude to tiger 8,868.0 8,868.0 00:00 00:18 tank 5/26/2019 5/26/2019 1.20 FROM DRILL WPRT T Work pipe. Pumping down ct, Work 8,868.0 8,868.0 00:18 01:30 pipe pumping down back side. Dump WHP at different points in cycle 5/26/2019 5/26/2019 0.50 FROM DRILL WPRT T Put pipe at neutral weight, Obtain 8,868.0 8,868.0 01:30 02:00 down hole static pressure, Sensor TVD @ 6084' Annular pressure 3778 EMW=12.0 5/26/2019 5/26/2019 0.60 FROM DRILL WPRT T Give one more pull up 92K. go to 8,868.0 8,868.0 02:00 02:36 neutral weight 32K. Send disconnect Contend. See EDC go to 200%. Pull up to 60K. RBIH. PUH again. Go to 1 OK Kick on pump. Loose comms with tool. Cycle CT pumping 1.8 BPM down CT. S/D pump and line up on back side 1.4 BPM. Work pipe 5/26/2019 5/26/2019 1.00 FROM DRILL WPRT T Park in compression -10K, Line up 8,868.0 8,868.0 02:36 03:36 down CT. Pump sweeps @ 2 BPM in 2 BPM out. Work pipe as sweeps coming out. Returns dropped to 1 BPM when sweep exited coil. Work coil at lower pump rates. Pressure up well. Dump pressure while working pipe 5/26/2019 5/26/2019 14.40 FROM DRILL WPRT T Park pipe at neutral weight. Circulate 8,868.0 8,868.0 03:36 18:00 well down CT @ 0.5 BPM with good returns. 23 bbls lost. 2,000 psi circulating pressure and 600 psi wellhead pressure. Check bolts on tree and stack. R/U PDL. Prep KWM. Identify and prep items for coil recovery operations. Swapped to line power. 5/26/2019 5/26/2019 0.50 FROM DRILL CTOP T Crew change, Valve check list, walk 8,868.0 8,868.0 18:00 18:30 1 around 5/26/2019 5/26/2019 0.60 FROM DRILL CTOP T PJSM, Go over 2E-17 Stuck coil 8,868.0 8,868.0 18:30 19:06 recovery procedure, Nabors CT pipe recovery procedure, and tool list and logistical worksheet 5/26/2019 5/26/2019 1.40 FROM DRILL CTOP T Bring all equipmet to rig floor. 8,868.0 8,868.0 19:06 20:30 Inventory and inspect, Lock out E -line, Shut down pump and test floats in UQC - Good test 5/26/2019 5/26/2019 1.90 FROM DRILL DISP T Line up to 12.2 NaBr pump down CT. 8,868.0 8,868.0 20:30 22:24 Circulate 12.2 up back side. Pumped tubed up 12.2 down coil 5/26/2019 5/26/2019 1.30 FROM DRILL OWFF T Flow check well - Pass had to bleed 8,868.0 8,868.0 22:24 23:42 1 off a couple of times 5/26/2019 5126/2019 0.10 FROM DRILL DISP T Pump on backside to fill hole. 1 BBI to 8,868.0 8,868.0 23:42 23:48 1 fill. Static loss rate 2 BBI/HR Page 28134 Report Printed: 61512019 . Operations Summary (with Timelog Depths) - 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Sten Time Ptd Time Dur (m) Phase Op Code Activity Cade Time P -T -X Operation (ItKB) End Depth(HKS) 5/26/2019 5/27/2019 0.20 PRODS DRILL CTOP T PJSM. Work pipe to 5K over pick up 8,868.0 8,868.0 23:48 00:00 weight 35K. Shut upper 2 " pipe / slips goto high bypass. Shut manual locks on BOPE 5/27/2019 5/27/2019 1.00 FROM DRILL CTOP T Work checklist to strip off injector. 8,868.0 8,868.0 00:00 01:00 Push pull CT +5K/ -5K. Strip off injector to correct height 527/2019 5/27/2019 1.80 FROM DRILL CTOP T Install hot tap on CT. Cut hole. Bleed 8,868.0 8,868.0 01:00 02:48 off fluid. No pressure. Rig down hot tap. Cut coil 86" up from floor. Able to pull 7' of slack by hand. Install cable damp on top of CT. Cut E -line. Skid back injector 5127/2019 51272019 0.20 PROD3 DRILL CTOP T PJSM. RON weight indicator rigged 8,868.0 8,868.0 02:48 03:00 up. R/U T bar to tugger 5/2712019 5/27/2019 0.80 FROM DRILL CTOP T Scaffolders here, suspend T bar ops. 8,868.0 8,868.0 03:00 03:48 Bring scaffolding up to rig floor and assemble 5/27/2019 5/27/2019 0.90 FROM DRILL CTOP T Scaffold erected. SLB a -line 8,868.0 8,868.0 03:48 04:42 equipment on rig floor. PJSM to pull a- line loose from UOC anchor with T bar. On 4th pull see anchor release 1360 to 800LBS 5/27/2019 5/27/2019 2.25 PROD3 DRILL CTOP T Rig wire to a line truck to retrieve wire 8,868.0 8,868.0 04:42 06:57 from CT 5/27/2019 5/27/2019 0.30 PROD3 DRILL CTOP T Eline out of hole w/boot and anchor, 8,868.0 8,868.0 06:57 07:15 (8,800' eliner recovered per SLB counter), fill the coil with 12.2 ppg (1.7 MIS) 5/27/2019 5/27/2019 0.80 FROM DRILL CTOP T PJSM, Install BOT external graple 8,868.0 8,868.0 07:15 08:03 connector, pull lest to 25 k 5/272019 5/27/2019 0.80 FROM DRILL CTOP T MU, 1502 iron to dumb end of coil 8,868.0 8,868.0 08:03 08:51 wtih lateral and 1-1/2" high pressure hose. 5/27/2019 5/27/2019 0.20 PROD3 DRILL CTOP T PT BOT CTC 800 psi good lest 8,868.0 8,868.0 08:51 09:03 5127/2019 5127/2019 1.00 FROM DRILL CTOP T Install addtional plug valve on 8,868.0 8,868.0 09:03 1003 manifold to PT E -line Lubricator. 5/2712019 5/27/2019 2.50 FROM DRILL ELNE T PJSM, spot, load and RU SLB E -line 8,868.0 8,868.0 10:03 1233 527/2019 5/272019 1.75 FROM DRILL ELNE T PT SLB lubricator, wait on hose for sib 8,868.0 8,868.0 12:33 14:18 equipment, raise scaffolding up one level 5/27/2019 5/27/2019 0.70 PROD3 DRILL ELNE T SLB changeout and orientation new to 8,868.0 8,868.0 14:18 15:00 the rig x 2 5127/2019 5/27/2019 4.30 PRODS DRILL ELNE T RIH 8,868.0 8,868.0 15:00 19:18 5/27/2019 5127/2019 1.25 PRODS DRILL ELNE T Flag a -line, POOH 8,868.0 8,868.0 19:18 20:33 5/27/2019 5/27/2019 0.40 FROM DRILL ELNE T At surface, drain rigup iron, inspect 8,868.0 8,868.0 20:33 20:57 5/27/2019 5/27/2019 1.20 FROM DRILL ELNE T PJSM, MU 1.375" Cutter 8,868.0 8,868.0 20:57 22:09 5/27/2019 5/27/2019 1.30 FROM DRILL ELNE T RIH, hesitate 15 mins, fire cutter @ 8,868.0 8,868.0 22:09 23:27 8,802' (good indication) hesitate for another 5 mins, PUH slowly, no overpull observed 5/27/2019 5/28/2019 0.55 PRODS DRILL ELNE T POOH 8,868.0 8,868.0 23:27 00:00 5128/2019 5/28/2019 1.20 FROM DRILL ELNE T Continue out of well after firing chem 8,868.0 8,868.0 00:00 01:12 cutter Page 29134 Report Printed: 61512019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Stan Time Endnme our (m) Phase Op Code Aae fty Code Time P -T -X Operelbn (W13) End Oepei(WEI) 5/28/2019 5/28/2019 2.00 PRODS DRILL ELNE T PJSM w/SLB aline. At surface break 8,868.0 8,868.0 01:12 03:12 off grease head. Lay down chem cutter. Rig back E -line equipment 5/28/2019 5/28/2019 0.60 FROM DRILL ELNE T Redress elevators to 2 3/4'. Latch CT 8,868.0 8,868.0 03:12 03:48 to blocks. Unlock rams. Pull up 20K over block weight 50K. Open 2" pipe slips. Observe weight drop to 36K. P/U CT string 25' PUW=37K String is free. RBIH with string. Set 2" pipes on CT. 5/28/2019 5/28/2019 1.20 PRODS DRILL ELNE T Rig down SLB E -Line and load out 8,868.0 8,868.0 03:48 05:00 5/28/2019 5/28/2019 1.60 FROM DRILL RURD T Rig down rig floor scaffolding, Prep 8,868.0 8,868.0 05:00 06:36 floor for CT injector ops, Dress elevators back to 2 3/8" inserts 5/28/2019 5/28/2019 3.00 FROM DRILL CTOP T Skid injector to floor. Remove pipe 8,868.0 8,868.0 06:36 09:36 clamp. Install spoolable CT splice on injector side of CT. Cut CT on stump and prep for dimple connection. Change out all o ring on riser. Skid injector over stump. Stab CT splice into stump side and dimple 5/28/2019 5/28/2019 0.30 FROM DRILL CTOP T PJSM, Strip on well. Pull test splice to 8,868.0 8,868.0 09:36 09:54 30K. Open 2" pipe slip rams. Pull splice to storage reel 5/28/2019 5/28/2019 2.00 FROM DRILL TRIP T POOH with 8802' CT 8,868.0 400.0 09:54 11:54 5/28/2019 5/28/2019 1.00 PRODS DRILL OWFF T 400'. Flow checkwell. Unstab injector. 400.0 0.0 11:54 12:54 Pull to surface. Close swab. Stab back on well 5/28/2019 5/28/2019 0.60 PRODS DRILL CIRC T Circulate CT to water recovering 12.2 0.0 0.0 12:54 13:30 NaBr. PJSM w HES N2 pumpers. Start cooling down N2 5/28/2019 5/28/2019 0.80 FROM DRILL CTOP T PT HES N2 unit to 4000 PSI. Come 0.0 0.0 13:30 14:18 online with N2 1500 SCFM for 12 minutes. SID N2 pumper and bleed off N2 5/28/2019 5/28/2019 2.00 PRODS DRILL CTOP T PJSM, Unstab injector. Hand cut end 0.0 0.0 14:18 16:18 of CT Prep for grapple installation 5/28/2019 5/28/2019 2.20 PRODS DRILL CTOP T Install graple, remove inner -reel iron & 0.0 0.0 16:18 18:30 pressure bulkhead, unstab & secure coil 5/28/2019 5/28/2019 1.00 FROM DRILL CTOP T Prep reel for pick & removal, dg up 0.0 0.0 18:30 19:30 shackles & slings, remove saddle clamps 5/28/2019 5/28/2019 2.50 PRODS DRILL CTOP T New reel arrives at dg at 19:00 his, 0.0 0.0 19:30 22:00 PJSM, pick old reel off rig, Peak truck sunk into pad w/ reel on bed, pickup, lay mat, re -pick reel from rig, pick & drop new reel on dg (reel # 53723) 5/28/2019 5/29/2019 2.00 PRODS DRILL CTOP T Shim hubs, install saddle clamps, 0.0 0.0 22:00 00:00 remove stripper, grease master, swab, & tango valves, grease Romeo, Bravos, MM, & choke (post N2 blow - down), pull riser, install night cap 5/29/2019 5/29/2019 2.10 PRODS DRILL CTOP T Continue reel install & greasing for 0.0 0.0 00:00 02:06 BOPE test, change out riser o -rings from OTS to top off bag, change out brass, re -install stripper, slide back injector, fluid pack, perfrom shell test 5/29/2019 5/29/2019 0.80 FROM DRILL PRTS T PJSM, line up valves per modified 0.0 0.0 02:06 02:54 1 checklist, perfrom shell test Page 30134 ReportPrinted: 6/5/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sten Time End Time Dur(hr) Phase op Code Acllvdy Code Tim P -T -X operaGw fn(B) End Depth (WS) 5/29/2019 5/29/2019 3.10 PRODS DRILL BOPE T BOPE test (250 psi low 13800 psi 0.0 0.0 02:54 06:00 high), witness waived by Adam Earl of AOGCC, difficulty holding high on swab #2 (re -grease), better though still difficulty holding high, carry on w/ test Difficulty holding high on test 2, cycle blind shear rams, no good, cycle again, no success, shut whitey valve, leaking past chadie 5, re -grease, 5/29/2019 5/29/2019 5.50 FROM DRILL BOPE T Crew change out. Continue with Full 0.0 0.0 06:00 11:30 BOPE test. On test 5. Complete test 11. PJSM to replace blind shear rams and test. Perform draw down test. Test gas detection equipment 5/29/2019 5/29/2019 3.80 FROM DRILL CTOP T PJSM. R/U to stab coil in injector, 0.0 0.0 11:30 15:18 verify reel alignment 5/29/2019 5/29/2019 2.20 PRODS DRILL SLKL T RU slick -line, MU tools with LIB, tag 0.0 0.0 15:18 17:30 up, PT 5/29/2019 5/29/2019 2.20 PRODS DRILL SLKL T RIH w/ LIB on slick -line, setdown on 0.0 0.0 17:30 19:42 fish @ 8820' slick -line depth, POOH, fish appears to be sitting at approx 150' ROHS (pits on S: drive) Installing pressure bulkhead 5/29/2019 5/29/2019 2.80 FROM DRILL SLKL T Bevel & RU overshot, RIH on slick- 0.0 0.0 19:42 22:30 line, attempt to caputre fish with overshot for 20 min, unable to overshot fish, POOH to inspect tools, continue installing pressure bulkhead 5/29/2019 5/30/2019 1.50 FROM DRILL SLKL T Redress overshot, MU tools & add 0.0 0.0 22:30 00:00 more weight, discuss additional lubricator, MU tools, begin RIH for second overshot run, ream pipe & install CTC, pull test 5/30/2019 5/30/2019 1.30 PRODS DRILL SLKL T Continue RIH, beat down for 30 min 0.0 0.0 00:00 01:18 attempting to overshot fish unsuccessful, POOH to PU gauge ring, test & rehead a -line 5/30/2019 5/30/2019 2.20 PRODS DRILL SLKL T MU gauge ring, PT, RIH to beat down 0.0 0.0 01:18 03:30 & crimp top of fish, POOH (had slight overpull when done beating on fish), LD tool, appears that gauge ring did not swallow fish 5/30/2019 5/30/2019 1.50 FROM DRILL SLKL T Decision made to run another LIB (3 0.0 0.0 03:30 05:00 runs made beating on tap of fish), PT, RIH, pump 5 bbl methanol spear 5/30/2019 5/30/2019 2.50 FROM DRILL SLKL T Slick line on surface. same marks as 0.0 0.0 05:00 07:30 orginal LIB run. R/D slick line and load out 5/30/2019 5/30/2019 1.70 PRODS DRILL CTOP T P/U QTS, Skid injector to floor. M/U 0.0 0.0 07:30 09:12 nozzle. Check packoffs. Stab on well. Fill pushing 5 BBI methanol spear circulating spear to TT. 5/30/2019 5/30/2019 0.50 PRODS DRILL CTOP T Circulate slackl.53 BPM for 1 1/2 0.0 0.0 09:12 09:42 volumes 5/30/2019 5/30/2019 0.80 PRODS DRILL PRTS T Line up to test inner reel valve - iron, 0.0 0.0 09:42 10:30 1 1 1 1 1 1 and packoffs with chart to 4400 PSI 5/302019 5/30/2019 1.60 PRODS DRILL PULD T Unstab injector, Install floats in UQC. 0.0 71.8 10:30 12:06 i P/U BHA#25. Fishing BHA with overshot, jars, weight bar, and accelerator. M/U to CT and surface test Page 31/34 Report Printed: 6/5/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tim Dur (hr) Phase Op Code A yCode Time NTA Operation (M(B) End Depth(ftKB) 5/30/2019 5/30/2019 1.70 PRODS DRILL TRIP T Trip in hole 71.8 8,565.0 1206 13:48 5/30/2019 5/30/2019 0.30 PROD3 DRILL DLOG T Log lie in for +144' - New CT string 8,565.0 8,773.0 13:48 14:06 with protective coating. Reel counter right on 5/30/2019 5/3012019 0.70 PRODS DRILL TRIP T Continue in hole. Tag TOF @ 8797. 8,773.0 8,797.0 14:06 14:48 Attemp to get over fish. 14 cycles hitting it at different speeds and down weights. Set down and hold weight on it. Decission made o not jar down 5/30/2019 5/30/2019 1.50 PRODS DRILL TRIP T POOH for reconfiguration. PUW=30K 8,797.0 71.0 14:48 16:18 5/30/2019 5/30/2019 0.90 PRODS DRILL PULD T PJSM, LD tools (overshot close to 71.0 0.0 16:18 17:12 swallowing fish, pic on S:drive) 5/30/2019 5/30/2019 2.30 PRODS DRILL WAIT T Wait on tools from BOT, tolls arrive at 0.0 0.0 17:12 19:30 rig 5/30/2019 5/30/2019 0.60 PRODS DRILL PULD T PJSM, PU BHA#26 Bowen Overshot 0.0 80.0 19:30 20:06 w/ Spiral Grapple, slide in cart, MU to coil, tag up, set counters 5/30/2019 5/30/2019 1.50 PRODS DRILL TRIP T RIH w/ BHA #26 80.0 8,675.0 20:06 21:36 5/30/2019 5/30/2019 0.30 PRODS DRILL DLOG T Log K1 for+38', PUW = 32K 8,675.0 8,783.0 21:36 21:54 5/30/2019 5/30/2019 0.10 PRODS DRILL TRIP T Continue RIH, tag top of fish at 8798' 8,783.0 8,798.0 21:54 22:00 @ 6.7K, PUW = 32K 5/30/2019 5/30/2019 0.70 PRODS DRILL FISH T Tag fish, set -down 2.5K WOB, 8,798.0 8,798.0 22:00 22:42 oriented HIS, rotate TF clockwise, weight fell off to 0.7K, oriented to 195° ROHS, set down -6K WOB, PU to see if fish is latched, fish not baited Repeat starting at 45° ROHS, chasing weight as it falls off up to -6K WOB, PU, no succes, attempt starting at 90° ROHS, PU, have negative WOB, setdown 10K WOB, wait 15 min for jars to fire, did not fire, PU to 35K (- 4.5K WOB), latched into fish 5/30/2019 5/31/2019 1.30 FROM DRILL FISH T Begin jarring down on fish, setting 8,798.0 8,798.0 22:42 00:00 down 12K WOB, filling hole as required, 28 licks down 5/31/2019 5/31/2019 0.70 PRODS DRILL FISH T Continue jarring down, at 43 licks PU 8,798.0 8,798.0 00:00 00:42 to cock jars & bait sub pins sheared (expected) 5/31/2019 5/31/2019 1.60 PRODS DRILL TRIP T POOH, flow check, PJSM 8,798.0 70.0 00:42 0218 5/31/2019 5/31/2019 1.30 PRODS DRILL PULD T Drop off HOT, MU BHA#27 Fishing 70.0 68.0 02:18 03:36 Assembly (Accelerator, weight bars, jars, 3" GS Spear looking down), check pack -offs, MU to coil, tag up, set counters 5/31/2019 5/31/2019 1.70 PRODS DRILL TRIP T RIH w/BHA #27 68.0 8,740.0 03:36 05:18 5131/2019 5/31/2019 0.30 PRODS DRILL DLOG T Log K1 for 31', PUW=30K 8,740.0 8,765.0 05:18 05:36 5/31/2019 5/31/2019 2.50 PRODS DRILL JAR T Continue in wll. Set down@ 8796' and 8,765.0 8,796.0 05:36 08:06 latch up. Jar down 5 times - 13K. Jar both ways -13K 45K up 10 cycles. Jar down 40 cycles. 5/31/2019 5/31/2019 1.50 FROM DRILL TRIP T Pump off fish. POOH for coil fatigue 8,796.0 85.0 08:06 09:36 management 5/31/2019 5131/2019 0.40 PRODS DRILL PULD T At surface. Flow check well. PJSM lay 65.0 0.0 09:36 10:00 down BHA on dead well Page 32134 Report Printed: 61512019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Slan T.me Ed Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(W8) 5/31/2019 5/31/2019 5.00 PROD3 DRILL CTOP T Prep for slack mgmt. Pull UQC Boot e- 0.0 0.0 10:00 15:00 line. Stab on and reverse circulate 2.8 BPM. Unstab. Cut 37' coil to find wire. Cut 100' coil. Prep coil and install CTC. Pull test to 35K. Head up E -line. Pressure test connector and UQC. Make up Nozzle. Stab on well. Pump forward 2 BPM for 60 BBIs. Unstab CT 5/31/2019 5/31/2019 0.60 PROD3 DRILL PULD T PJSM, PIU BHA#28 with GS, 2 1/4" 0.0 68.2 15:00 15:36 Up Down jars, weight bar, and accelorator. Make up to cil and surface test 5/31/2019 5/31/2019 2.30 PROD3 DRILL TRIP T Trip in well, EDC open, pmping min 68.2 8,725.0 15:36 17:54 rate, build beaded pill 5/31/2019 5/31/2019 0.10 PROD3 DRILL DLOG T Log Kt for+27.5' correction 8,725.0 8,740.0 17:54 18:00 5/31/2019 5/31/2019 1.00 PROD3 DRILL TRIP T Close EDC, PUW = 31 K, pill built & 8,740.0 8,796.0 18:00 19:00 ready to pump, pump 35 bbl beaded/tubed pill, continue RIH, latch into fish 5/31/2019 5/31/2019 1.00 PRODS DRILL FISH T Begin jarring down, 30 licks down, so 8,796.0 8,796.0 19:00 20:00 movement on fish 5/31/2019 5/31/2019 0.20 PROD3 DRILL FISH T Begin jarring up, S licks up & pull free, 8,796.0 8,796.0 20:00 20:12 come to surface to check for fish 5/31/2019 5/31/2019 1.90 PROD3 DRILL TRIP T POOH, flow -check well, PJSM 8,796.0 68.0 20:12 22:06 5/31/2019 5/31/2019 0.40 PROD3 DRILL PULD T LD BHA #28, Have overshot & no fish 68.0 0.0 22:06 22:30 5/31/2019 6/1/2019 1.50 PROD3 DRILL WAIT T Difficulty breaking down overshot & 0.0 0.0 22:30 00:00 grapple, overshot too damaged to redress, missing piece of grapple (pic on S: Drive) Plan forward: Re -bait fish, PU & RIH with Hip -Tripper 6/1/2019 6/1/2019 1.70 PROD3 DRILL WAIT T BOT attempting to track down 0.0 0.0 00:00 01:42 additional over -shot & grapple, confer with town, decision made to RDMO 6/1/2019 6/1/2019 0.80 DEMOB WHDBOP PULD P PJSM, PU BHA#29 0.0 0.0 01:42 02:30 **Call out LRS for 5AM w/ freeze protect 6/1/2019 6/1/2019 1.60 DEMOB WHDBOP TRIP P RIH w/BHA #29 0.0 8,700.0 02:30 04:06 6/1/2019 6/1/2019 0.10 DEMOB WHDBOP DLOG P Log K1 for+32' 8,700.0 8,713.0 04:06 04:12 6/1/2019 6/1/2019 0.70 DEMOB WHDBOP DISP P Continue RIH to TOWS, displace well 8,713.0 8,745.0 04:12 04:54 to seawater 6/1/2019 6/1/2019 2.30 DEMOB WHDBOP TRIP P Trip out of hole. Diesel freeze protect 8,745.0 42.0 04:54 0712 well from 2500' to surface 6/1/2019 6/1/2019 1.00 DEMOB WHDBOP PULD P Tag up and space out. PJSM PUD 42.0 0.0 07:12 08:12 BHA #29. Lay down tools, Final WHP=1222 PSI 6/1/2019 6/1/2019 1.20 DEMOB WHDBOP CLEN P Make up nozzle, Stab on well. Jet 0.0 0.0 08:12 09:24 stack. Flush rig surface lines 6/1/2019 6/1/2019 0.30 DEMOB WHDBOP PULD P Unstab injector, remove nozzle, Pull 0.0 0.0 09:24 09: 1 1 floats from UQC 6/1/2019 6/1/2019 3.50 DEMOB WHDBOP NUND P Start working BOPE stack change out 0.0 0.0 09:42 13:12 swab 2/ Cellar rig down / Work rig down check list / Load out mud products Page 33/34 Report Printed: 6/5/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur(hr) Phase Op Code Anvily Code Time P -T -X Operabon ('KB) End Iql (RKB) 6/1/2019 6/1/2019 0.60 DEMOB WHDBOP NUND P Complete unloading pits. Lid stack off 0.0 0.0 1312 14:00 well with new upper swab. RIG RELEASE 14:00 Page 34134 ReportPrinted: 6/512019 ConocoPhillips ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit Kuparuk 2E Pad 2E -17L1 50-029-22419-60 Baker Hughes INTEQ Definitive Survey Report 26 June, 2019 BA ER F UGHES GE company Conmolthillips W116s COOOC3�1wP5 Definitive Survey Report Company. Cimmv igips Alaska Inc_Kupamk Local Conrdlnate Reference: Wed 2E-17 Project: Kupamk River Unit WD Reference'. 2E-17 @ 146.00u30 (2E-17) Site: Kupamk 2E Pad MO Reference: 2E-17 a 146.00uaB(2E-17) Well: 2E-17 North Reference: True Wedben: 2E -17L1 Survey Calculation Method Minimum Curvature Design: 2E -17L1 Database: EDT 14 Alaska Production Project Kupamk River Unit Nodh Slope Alaska, United Slates Map System: US State Plane 1927 (Enact solution) System Datum: Mean Sea Level Geo Datum: NAD 1827 (NADCON CONUS) Using N.bll Reference Point Map Zone: Alaska Zone 04 Using geodetic scale fact., Well 2EA7 Well Position +WS 000 unit Nmthm9: 6944284.83taX Latitude: 70°15'31,849N -Eli 0.00 usfl Eemin9: 529,971.26tsR Longitude: 149°45'77907W Position Uncertainty 900 till Wellhead Elevation; usfl Ground Level: 0.00 usfl Wellbore ---- 2E -17L1 Ma9netloa Model Name Sample Doh UecllnMbn 01p Angle Flats Stni PI 11) (-T) SGGM2➢1e 71112019 16.49 8091 57,405 Design 2E -17u Audit Notes'. Version: 10 Phase: ACTUAL Tie On Depth: 9,241.32 Vemcal Section: Depth From (WO) +N +0401 Opposed. [.aft) (tam Wi 1°I 14600 0.00 0.00 135.00 Survey Ptogne Dam Fran 1. sorvry Survey (uaR) Isd01 Sunay (weNban) Toot Nanta Dercdpgon Suit Date End Dan 15000 8,80620 2E -17(2E-17) GCT -MS Schlumberger GCT multsh.t 1112/2001 8807.00 8,863.11 2E-17UPB1 MW INC (2E-17UPB1) MW41NC ONLY MW0.1NC_ONLY FILLER 5192019 5192019 8893.44 9,241.32 2E-17UPB1 MM(2E-17UPB1) MNUOWSG 01 MM -Standard 511112019 5/112019 9269.00 12,222.43 2E-1711 MkAD(2E-17L1) MWD OWSG 01 MIND - Standard 5252019 51252019 6262019 2'V2 fhw Pege2 COMPASS 5000.14 Bal 80 ConocoPhillips a ConocoPhillips Definitive Survey Repot company: Project: She Well: Wellbore: Design: Survey ConocDPIelips Alaska lnc Kupamk Kupamk River Unit Kupamk 2E Pad 2E-17 2E-171-1 2E-171.1 Local Coardlnah Ref eras 720 Reference: MO Reference: North Reference: Survey Calculation Method: Decrease: Wall 2E-17 2E-17 ®14S.00usR (2E-17) 2E-17 @ 140.00usR (2E-17) True Minimum Ourvature EDT 14 Alaska Production Annotation TIP KOP 646*0192:32:08PM Role COMPASSS000.f4a 1180 Map Map Vertinl MD Inc AN NII NOSE .1414*EI-W Northing Eacting DLS Section (am) (usm ("aft) (use) Ia) Irtl 1.1100') (a) Survey Torl Name 8,241.32 96.21 141.16 6,10028 5,854.28 4,951.82 3,705.66 5,939.349.29 533.696.T1 10,62 6,121.26 MAD OWSG(3) 926900 8.26 143.04 6,096.45 595045 492345 3,M.50 5939326.73 53321315 11.23 8,14&96 MWDMSG (4) 930039 04.09 154.52 6,1)1 5,949.55 -5,000.16 3,238.67 5,939,30000 53322&43 60.6 8,9939 "DMSG (4) 9,33044 M.M 106.37 8,09&06 5,95232 -5,029.53 3]47.92 5,98.27175 533)3&29 49.34 620558 MWOMSG (4) 9,36038 8529 184.79 6,110.07 5954.82 -5,05033 3]49.43 5,98,24206 533,24042 51.33 6222.86 MWOMSG (4) 8,380.43 8505 M.44 6.10.42 5,85742 5,08232 3.742.41 5.939.213711 533.73352 Sam 6,243.49 MWD MSG (4) 9,420.61 08.28 218.34 6.106.19 5.959.19 -S.N312 3]22.22 5.09,187.0 58,718,42 5362 6,251,06 MWD MSG (4) 9.450.92 0202 85.n &11-8.26 5906.44 -6.18]2 3,205.11 5.939,106.41 5860640 57.35 6,249.99 MWD MSG (4) 9,01.01 38.03 8223 6,10175 5,861]5 5,148.84 3.678.23 5,938,153.18 58,86958 55.01 6240.22 MWD MSG (4) 9,508.06 Be. 26540 6,106.23 5.962.23 5,151.83 3,652.99 5,939,14&06 58644.8 5152 6,28.85 MWD MSG (4) 8,5358 saw 233.61 SAM36 5,642.36 5,15034 3.624.63 5,939.149.47 533,61599 538 6,204.84 MWD O MSG (4) 9564.70 09.23 23863 6,10.65 5,962.65 5.14285 3,595.13 5.939,15&84 58,507.47 27.91 6,12939 MWD MSG (4) 9,595.51 8126 81.21 6,106.59 5963.59 -6.13234 3,56737 5.939.167,24 58,55952 too 6,15155 MWD MSG (4) 9,830.21 0&16 83.49 6.110.98 5964.89 5,11915 3,535.21 5,939,1908 58.52646 706 6,11956 MWD MSG (4) 96608 9045 295]5 8.111.34 5,865.34 5,10664 3.507.90 SA39,192M 58.48.10 10.23 6,00140 MWD MSG (4) 969011 8098 88.40 6,110.86 5,984.98 5.09305 3,481.8 5,939,206.9 5334848 905 6.83.10 DMSG(4) 9 Mal 90.52 8197 6,110.56 5964.56 5.02757 3,454]0 5.939,22155 533.44506 HW 6,033.8 MWD MSG (4) 9,74973 89.26 83]6 6,110.61 5,5&.62 -6.061.93 3.430.50 5938,23706 58.421.8 7.60 6.005.06 MWD MSG (4) 9,780.96 8742 3(5.03 6.111.52 5,965.52 5,04380 3.405.02 5,839,25&02 58.395.99 11.46 5,974.8 MWD MSG (4) 9.803]6 8565 309.38 6.113.21 5,96721 4,026.16 338240 5,939$7266 58,373.30 10.33 5,945.75 MWD MSG (4) 984016 8674 31143 6.115.7 5,969.18 4.0m 51 3,359.8 5,9393928 533.3$12 740 5,915.52 MWD MSG (4) 8068.22 8979 313.01 6,116.02 5,970.07 4,98662 3,337.38 5.939,312@ 533,326.13 HW 5.885.96 MWD O SG 14) 9,89912 91.84 31641 6,118.64 5969.64 4.9052 3,316.07 5.93933304 58,wam 13.23 5.855.92 MWD MSG (4) 9,98.24 90.31 319.0 6.11507 5,968.07 4,942.97 3,295.59 Same9 55.50 58,256.16 1013 5,825.54 MWD OWSG (4) 9,660.13 8018 3218 611494 5,96995 4.9211.00 396.47 5,830.378.39 58,206.% 767 5,29518 MWDOWSG(4) PSSGw 89.50 man 6.11520 5,06039 4.896.27 3,25&29 5,93940206 58.243.69 0.63 5.256.14 MWDO MSG (4) 10,00.11 8783 8641 6,116.31 5.970.31 4,62162 3,241.08 5939426.62 58818 939 5.736.55 MWD0 MSG (4) 10.M.11 87.94 328,33 6.117.46 5,87147 4,946.30 3,22504 5,93945188 5831524 0.29 5,2078 MID MSG (4) 10.01 90.37 331.81 6,117.91 587191 4,8211.32 321018 5830.421.0 58,200.23 1221 5,62842 MWD OWSG(4) 10.110.11 80.64 33031 6117.64 5,971.64 4794.4 3195.59 5,98.504.@ 58,185.8 442 5.649.52 MWbGW5G(4) Annotation TIP KOP 646*0192:32:08PM Role COMPASSS000.f4a 1180 ConocoPhillips RA Dc Es • COf1000PftIlllPS Definitive Survey Report Company. ConocoPhillips Alaska lnc Kupamk Local CoarXinate Reference. Well 2E -t] Protect Kup huk River that NO Reference: 2E-17 @ 146.00usX(2E-17) She: Kupamk 2E Pad MD Reference: 2E-17 @ 146.00usR(2E-17) Well'. 2E-17 North Reference: Tlve Wellbore: 2E -17L1 Survey Calculation Method: Minimum Curvalmm Daslgn: 2E -17L1 Database: EDT 14 Alaska Production survey 6262019 2:32:08W Pape 4 COMPASS 5000.14 SWd 85D Map Mop Vertical MD Inc Atl 111D TMlls9 eNBs 4V1 NO(111 EaInnB OLS SeoXon Survey Tooi Neme AnnOlafiOa (Deft) P) (') (Sam (Dalry (-a) (Daft) R) RI Oleo.) RI 10,139.. Saw 327.05 6117 55 5,97156 -0j0.40 3,160.24 5,9395Ya.59 533,17014 8.79 5,620.54 MWOMSG (4 10,1]11.. ..8 325,90 6117M 5,971.02 <,743.24 3,163.82 5,939,554.89 533.153.62 665 5,591.14 MNOMSG (4( 10,200.26 WAS 323.85 6.117.90 5,971.96 471652 3,146.44 5,939,579.33 533136.14 7A0 5,561.37 Men MSG (4) 10,23027 92.03 322.10 6117.38 5.871.30 -0,694.57 3,128.37 5.939.603.21 53111298 BAB 5.531.66 MMMSG(4) 1o,mo.19 0,75 321.33 5,115.35 5,969.36 -0671.14 3,109.88 5939,626.56 52;099.40 12.70 5.5@.01 MNOMSG (4) 10,28020 95.60 322.65 611239 5,966.39 -0,647.82 3.091.49 5,838,650.01 533600.91 4.41 5.4]3.3] MWOMSG (4) 10,320.05 96.15 32281 6109.33 5.963.33 4,823.99 3.073.51 5,939.6]3.5] 533.852.84 1.92 5.44285 MMMSG (4) 10,350.13 95.64 322.03 SINAI) 5,960.19 160020 3.055.27 5,939,69]2(1 533WSO 2.70 5,413.8 MMMSG (4) 10380.67 95.5 MW 6,103.24 5,957.24 4MS,31 3035.57 5,939.721.09 5330255! 1.90 5,303.12 MW00WSG(4) 10,410.57 95.39 3820 aloo.m 5.854.46 455281 3,018.30 5.939.744.52 58,007.35 0.61 5#4.59 MWD MSG (4) 10.440.59 91.14 32238 6080.75 5,95275 4,58.10 2999.87 5.838,768.15 532988.93 14.17 5,323.W MND MSG (4) 1047053 9307 38.32 6097.44 5.951.44 45605 2881.81 5,838.791.92 58.970]8 9.64 5.284.23 Neat) MSG (4) 1050110 9583 324.11 6894.83 5,948.83 4490.]1 2963.88 5,939,816.39 53295265 7.21 5,264.12 MWD MSG (4) 1053131 9590 3WA7 50918 5,945.8 4456.30 29M.33 5.939,840.73 532935.01 1.19 5,234.45 MND MSG (4) 10,561,49 9569 324.15 6,OWS7 5,84267 4,431.93 2,928.83 5.939,855.03 53291241 1.25 5.260.84 MND MSO (4) 10,591.17 94.79 32354 6005.95 5939.96 4,40806 2911.39 5,939.BBB.82 532099.88 165 5,95.64 MWD MSG (4) 10820.80 9301 32262 6083.95 5,937.95 4,384.43 2893.63 5,938,91238 532.882.03 675 5.1..37 MWD MSG (4) 1065039 93. 32202 6,082.30 5.936.30 4,36076 287562 5,939,935.88 532853.92 124 5,116.88 MND MSG (4) 10,680.90 92.15 32210 8,08.85 5,83406 4,33616 289.17 5,939,959.91 532.845.38 4.53 5.0.8°.88 MAID MSG (4) 10710.81 91.48 321.58 8,08.91 5,93391 4,313.25 2838]0 5,939.983.33 533,026.82 2.88 5,057.19 MAID MSG (4) 10.740.01 9246 Mm 6WaSo 5,93290 -0,290.8 2820.69 5,940005.22 532,808.8 4.06 502622 MMD MSG (4) 10,71121 9188 321.00 6,077.72 5,931.8 4,265 70 280153 5,940,03D.8 532]89.45 214 4997.28 MMD MSG (4) 10,001N 8230 3585 8,08.53 5,930.83 424239 2]B263 594D,053.9] 532770.47 6.31 4,907.44 MMD MSG (4) 10,610.49 92.98 35.61 8.0]5.8 5929.5 4,219.86 2754.02 5,940,076.42 532.751.71 3.54 4,910.35 MMD MSG (4) 10.860.11 9283 3514 6,0]3.99 5,82].. 4.19783 2745.19 5.940.9,9 53273286 3.96 4,908.89 MMD MSG (4) 10898.41 8080 316. 6,0n,71 5,92].]1 4,167.91 2720.33 5,940,18.18 532]60.88 984 4,0]0]2 MMM) MSG (4) 10.920.63 91.45 319.67 6,073.74 5,92274 -0,151ID 270503 5,940,144.97 53269332 10.72 4040.56 MWD OWSG(4) 10.951159 93.44 81.39 6,0860 6,98.% -0,12286 2686.00 5940188.00 532.67420 DAG 4,810.77 MND MSG (4) 10960.18 93.38 8116 6.0]0. 5924.80 4,104.92 2888.33 5,9401909] 532,65563 000 4.76941 MAD MSG (4) 11418.03 9344 31q 87 6608.55 5922.55 -0,07536 2644.30 5940.22003 532631.W 341 475100 MJA MSG (4) 11 M0.19 91.47 321.51 505].60 5,921.60 4059.63 263020 594087.10 53261741 1155 472977 MD 6262019 2:32:08W Pape 4 COMPASS 5000.14 SWd 85D ConncoPhillips Cono4hillips Definitive Survey Report Company: Con..P611llps Alaska Inc_Kupamk Local Conrction Referenu: Pocono,: Kupamk Rwer Unit P Relerence: SRe: Kuparuk 2E Pad MD Reference: Well: 2E-17 Nunn ReMram.c Weli6om: 2E-171.1 Survey Calculation Method: Design: 2E-171.1 Database: Survey Wait 2E-17 2E-17 ® 146.00usR (2E-17) 2E-17 (11t 146.00usR(2E-17) True Minimum Cunmwre EDT 14 Alaska Pm6uceon 6/[62019 2:320SPM Petra 5 C MMSS 5000.14 Budd 850 Map Map Vertical MO Ix A41 WD TVDSS eNl5 +V41i Ne Eazting DLS Se(ft) Survey Tool Name Annotationlurttl 17 h) lusnl lusfil lusfil lusrt) (11) IRI IRI 1-1100.) (ft) 11,07049 8683 321.99 6.752 5,921.52 4,034.84 2611.52 5No.. 82 532.59656 8.86 469960 MWD 0...(4) 11,10041 0748 320.91 .06.A0 5,922A9 -0,011.45 2592.00 5,907.284.13 532.579.83 578 460997 MWD MSG (4) 11130.47 06BS 321.13 6.07D.03 5,924.03 -3.988.11 2574.00 5,940.307.39 532.580.65 286 4640.11 MWD MSG (4) 11.16203 0637 32143 6071.95 5.925.95 -3.853.Sa 2554.23 5,907.331.83 532.54099 ,Be 4,60679 MWD MSG (4) 1119049 8567 321.97 6073.92 5.927.92 -3,941.35 25%.58 5907.353.99 532.52325 3.84 458059 MWD MSG (4) "'noel 83.35 32104 6,076.83 5,93083 -3,917.66 2517.73 6,940.377.61 532504.31 821 4.550.50 MD I 1125009 8392 32140 6000.14 5934.14 .3,895.05 2499.57 5,940.400.14 532.485.06 1.54 4,52198 MWD MSG (4) 11.28024 86.93 321.62 6082.07 5.933.83 -3,81 248087 5,940,423.58 KG.467.27 1100 4491.03 MWOMSG (4) 1131038 a9.00 321.90 6,083.47 5.937.47 -3.81 2bR.15 5907.447.10 532.448.45 9.80 4.46191 MWD MSG (4) 1134060 92.15 321.45 8.003.93 5.936.93 -3.824.2. 2443.30 5,907,471.69 532.42952 7,50 4431.85 MWD MSG (4) 11.370.03 9273 3n.27 6001,.60 5,93568 -3,801.18 2425.17 5840,48371 533.411.29 3.42 4.94,V) MWD OWSG(4) 11.40032 9396 322.15 6079.91 5,933.91 -3,777.29 2409.84 5,940.517.52 632.39267 4.08 4.37269 MWD OWSG(4) 11,430.63 84.46 X2.65 6U77.69 5,931.69 4,753.34 238620 5,940,541.40 KQ.374.14 233 434272 Mel) MSG (4) � 11,46049 99.38 322.69 6,0360 5.931.80 4.729.61 2370.10 5,940,565.05 533.35595 18.98 4313.15 MWD OWSO (4) n,490.42 Mom 3M.45 6076.3 5.93075 -3,70585 2351.(11 5,907.588]4 532.33767 327 4,28 W 3,48 MD MSG (4) 11529,47 9117 32416 60336 5,930.36 -3,601]8 2333.96 5,84061276 533.319.62 6.32 4,25375 MWD MSG (4) 118009 91,70 324.09 6,075.60 5,929.60 -3.657.711 231661 5,840.fi35.fiB KU.M2.17 207 4.214.52 MWD MSG (4) 11,80.67 9271 324.05 6,074.40 5.928.40 -3.633.02 229668 5,940.6131.35 532.284.15 3.04 419434 MWD MSG (4) j 11,610.61 93.10 323.28 6p'R08 5.926.88 -3.60693 2280.96 5907.685.35 532.56.34 208 41603 MWD MSG (4) 1 11,"053 91.63 321.78 6,071.65 5.925.65 -3.5.531 2,262.77 5907.709.01 532.240.06 702 4,135.15 MWDO G(4) 11.67082 90.00 32178 60ln, 2 592522 -3,561.57 2244.16 5,940.732.57 5ffi,229.35 5.42 4106.9 MWD MSG (4) 11.70D.30 89.91 320.93 6071.24 5,925.24 -3,538.39 2225.83 5940.75567 532.210.3 288 4,07570 MWD MSG (4) 113091 .0." 319.58 6,071.39 5.925.39 -3.514.W 2205.06 5,940,778.13 532.191.07 457 4M529 MWD MSG (4) 11,76034 .935 316.40 6.OT1.67 5.925.67 -3.492,99 21..36 5907.80D.91 632.171.29 1082 401581 MWD MSG (4) 11,79030 86]1 313.97 0,07210 5,916.18 -3,47168 2165.19 5,994.@2.07 M.15i 8.37 3,98507 MWD MSG (4) 11,020.37 88.13 310.8 607100 5.92700 -3,451.51 2143.03 5,940.84222 532127.79 11.24 3,955" MWD MSG (4) 11,65243 88.53 307.07 6,073.94 5,927.94 -3,431.24 2,11621 5,94006239 532.102.90 882 3.92405 MWD MSG (4) 1188225 R9.Se 3".14 6074.3 5.928.70 -3.413.72 2094.10 5,"0.8381 532.078.72 1244 3,.9462 MWD MSG (4) j 11,91235 .74 301,15 607542 5.92942 -3,39749 2058.77 5,907.895.94 532.05332 e. 3,865.22 MWD MSG (4) 11,94336 W.66 307.37 603.39 5,99439 -3,381.64 20,1213 6M.911,68 =,M 63 4.30 3101 MWD MSG (4) 11978.20 r"a 1.. 6077. 5071.26 -3.353.38 2012.40 5,940.929.82 5319..90 8.85 3,80130 MWD MSG (4) 6/[62019 2:320SPM Petra 5 C MMSS 5000.14 Budd 850 Conocolahillips Definitive Survey Report Damian. ConomPhillipa Alaska Inc_Kupamk Local Coroninate Reference: Wen aE-17 P.Jem: Kupamk River Unit ND Reference 2E-17®146.00uen(2E-17) She: Kupamk 2E Pad MD Reterence. 2E-17@M.00usn(2E-17) Well: 2E-17 Nonb Relerence'. True WeaEOre: 2E-1711 Survey Calculation Method: Mmimumcurvalure D.tlgn: 2E -17L1 Database: EDT 14 Alaska Production Survey i Annotation 6252079 2:02.96PM Page 6 COMRISS 5000.148uade50 Map Map Manuel MD Inc AE TVD TIMES .WS .EJ.W No Eaatln9 DL5 section saner Tptl made (uanl I°I 19 luznl lam Ivan) (usnl to) Inl Inl 1°/1Do•1 In) 12002.50 9021 302li 6,01.33 5.93133 3,350.22 1992.05 5,94094289 5319]642 3.07 3,777,55 MOLD M6G (4) 12,03SW 89.42 302.76 6,07744 dual 4 3,33103 1,W345 5,946961.17 531.947.76 233 3,744.33 MJJD OWSG(4) 12,063.05 89.48 30336 6,07769 5,67169 -,31734 1,841.20 5.940.975.57 531.925.46 227 3.718.35 MMOMSG (4) 12,09412 88.71 304.30 6,078.18 5,932.19 3,31)(104 1,915.40 5,906,992.76 631,699.59 385 3,687.88 MND OMG(4) 12,125.52 88.40 303,5,1 6,078.98 5,93298 3,28253 1,W9.35 5,941.010.17 631p73A7 261 3.07.07 MND OMG (4) 12.15292 87.76 303.78 6.079.89 693389 3.25735 1,.,SS 5,941,026.26 531806.62 2.49 3,63O.Y2 MND DIVES (4) 12.183.57 86.28 303.37 8.083.95 5,93495 3.25041 1.61104 5,941,042.10 531625.04 2.16 3,606.211 MWD OWSG (4) 12,211.78 90.49 303.26 6.081.26 Scrota -3,23491 1,817,46 5,941057.06 531801.40 7.84 3.6R.66 MWD OW6G (4) 1222243 9025 306.24 6,06,18 6,83x.18 $228.15 1,808.52 5,841063.22 53l 79Z43 1003 3,5529 MWD OWSG (4) 12358.00 90.25 302M 6,081.03 5,93303 -3,210.17 1.778.43 6941,082.06 53176227 000 3,527.47 PROJECTED W ID i Annotation 6252079 2:02.96PM Page 6 COMRISS 5000.148uade50 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2E Pad 2E-17L1PB1 50-029-22419-70 Baker Hughes INTEQ Definitive Survey Report 26 June, 2019 BAKER J"ES .GE.mp ConocoPhillips Company: ConowPhillips Alaska Inc Kupamk Wce project Kupamk River Unit Tb Bea: Kupamk 2E Pad Just) Well: 2E-11 Tool Mme Wellbore: 2E-17LiP81 2E.17(2E.17)GCT-MS Dealgn: 2E-111-113131 8,827.00 Project Kupamk R'hm,Unit, North Slope Alaska, United States Map Sysbm: US Slate Plane 1927 (Exact solution) System Dalai Gee Datum: NAD 1927 (NADCON CONUS) Map Zorre: Alaska Zone 04 Well 2E-17 Well Position AWS 0.00 ush Northing. aEf-W 0.00 Usft EasOng: Position Uncertainty 0 D9 usX Wellhead Wellbore 2E-17LiPB1 Magnates Model Name Sample Dab BGGM2D18 71112019 Design 2E-1111 P81 Audit Notes: Version. 10 Phuu: ACTUAL Vertical Beaton: Dept Fnm (TVD) IIrMry 145.00 CorocoPhlllips Definitive Suwey Report Lecal Donramab Reference: Wb112E-11 WD Rebrence: 2E-17 @ M.00use (2E-11) MD Rebrence: 2E-11 @ ta6.O0usg (2E-11) North Reference: True Survey Calculation Method: Minimum Curvature Database'. EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using gimde0c scale boor BIg iES to 5 944 284.03usg Lietude: 10" 15 31.849 N 529,971.26Usb Longhuda: 149°45'27,907W 1¢vetion: uafl ground UWE 000 usft ( Destination Oy Anpb FMWBbenplh i InTI 16.49 Net 51,405 ! The On Depth: 8180620 ♦1644 IuM) 0.00 Survey Pm9rem Wce — From Tb Bbd Dab EM Dob - Just) I -M) 8arveylWellbon) Tool Mme 150.00 8,806.20 2E.17(2E.17)GCT-MS 8.827.00 8,827.00 2E-17LiPB1 BUND(2E-17L1PB1) BLIND ♦EI W take) 0.00 Description Schlumberger GCT muftishot Blind tinting DlreQbn 1°) 135.00 Bua¢ey Burney Bbd Dab EM Dob - 111&2001 M2019 WWO19 6 (OSO19 2:31:33PM Paget COMPASS 5000.145ui1d 851D ConocoPhillips 0 ConocoPhillips Definitive Survey Report Campany. ConocoPhllllpa Alaska Inc Kupamk Project: Kupauk River Unit Sire: Kupamk 2E Pad Well: 2E-17 We11b. 2E-17LiP61 Dealgn: 2E-l7VPB1 Survey Local CoarEinate Reference Well 2E-17 TVD Reference: 2E-17 ® 146.00ush (2E-17) MD Reference. 2E-17 C 146.00mi (2E-17) North Reference'. TNe Survey Calculation Method Minimum Ourvature Database: EDT 14 Alaska Production 6262019 2: 31:33W Page 3 COMPASS 5000.14 Bulk 850 Map Vertical MD Inc Ae1 TO Mans aW4 aEly/ NRMapap Eeatinp DLs Section (..ft) (°) PI (-*M team ("M (w l III M) ) (-11'1 Survey Tool Name 01) Annotation .A....A....A...])3B 143.32 fi3O]0.]2 6.829.8 <.658.69 3414.62 5.939.638.02 633,0033.90f.W 0.97 5,709, 55 6LIN0(2) TIP 8.81 37.40 143.10 6,087.24 5,941,N -0,67001 3,423.19 5,939.638.94 533<11.E6 0.65 5,M 05 BLIND (2) KOP 8.874.W 37.40 143.10 6,124.58 5,978.58 4,69284 3,439.]3 5,939,E06.18 533428.89 coo 5.750.31 PROJECTED lu TD 6262019 2: 31:33W Page 3 COMPASS 5000.14 Bulk 850 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2E Pad 2E -17L1 PB2 50-029-22419-72 Baker Hughes INTEQ Definitive Survey Report 26 June, 2019 IUER I UGHES aGE..', ConocoPhillips Co.,., COnocoPhithps Alaska Inc Kuparvk Pmfem: Kuparvk River Unit Site: Kupmuk 2E Pad Well: 2E-17 Wallbora: 2E-17L1PB2 Design: 3EA9L1PB2 Project Kuparvk, River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact whoon) System Datum Geo Datum: NAO 1927(NADCON CORDS) Map Zone: Alaska Zone 04 Well 2E-17 ConocoPhilllps AWS Definitive Survey Report Nonhing: Local Coardimte Reference: Wall 2E-17 TVD Referenm: 2E.17 @ I48 00m0 (2E-17) MD person nca: 2E-17 ®146.00usk (£E-17) North Reference: Tree Survey Calculation Method. Minimum Curvature Datacase: EDT 14 Alaska Production Mean Sea Level Model Name Using Wen Reference Point Using goodsh, scale harder Well Position AWS 006 usfl Nonhing: ♦EI -W 0.00 ask pasting: Position Unceminty 0 D usfl Wellhead Elevation: Wellleare _ 2E -17L1 PB2 Magnetise Model Name Sample Data BGGM2018 7/1/2019 Dealgn 2E-17L1PB2 Audit Notes: version: IS Phase: ACTUAL Vertical Sects n: OeVak F. (M) (sant 146.00 5,944,284.83 usX 529, 971.26 ush unit Declination r 1649 no On Depth: 9.271.10 eNF.I lintel 0.0 -HWW (plan 0.0 Leakage: Longitude: ground Level: Dly Angle r) 80.81 Dlrcdfen 1'1 135.00 7 70° 15' 31.849 N 149° 45' 27.907 W 0.00 all Paid Strength (nT) 57405 6162019 23100PM Paget COMPASS 500014 Scold 850 6202019 2'31.10PM Paye 3 COMPASS SI 14 Budd 850 Cortmofthillips IwN6s Cor1000Plillips Definitive Survey Report .,..�.. Company: Con-Phillips Alaska Inc_Kuparuk Local Ooarninate Relmmoe: We92E-17 Project: Kupamk River Unit WO Reference: 2E-17®1M.00usfl(2E-17) site: Kupamk 2E Ped MO Reference: 2E-17a W.00usO(2E-17) ! Well: 2E-17 North Reference: True Welibom: 2E-17UP132 Survey Calculation Method: Minimum Curvature Dul,n: 2E-17L1PB2 Daall.a. EDT 14 Alaska Production Survey Pro9mm Date Survey Sureey From (USM To luenl Survey[W.More) Teal Nem. Description biters Dem EMDaIe 150.00 8,806.20 2E.17(2E-1 T) GCT-MS 3C1flumber9er GCT muBisM1o1 1112/2001 8,80].00 8,863.11 2EA7UPB1 MWD-INC (2E-17UPB1) MW INC ONLY MW61NC ONLY FILLER 5MI2019 5192019 0,89344 9,271.10 2E-1712PBi MAD (2E-17L2PB1) MWD DMG OWBG MWD-StandaN 51112019 5/112019 9,286.00 9,334.36 2E-171.1PB2 MWD-INC(2E-1]1.1 P82) VW INCONLY MW0.1NCONLYFILLER 511812019 51182019 9,359.51 9,499.21 2E-171.1 PB2 MM(2E-17L1 P82) MWD OWSG OWSG MWD-Sanded 511812019 5116/2019 Map Map Vertical MO N) Ari TVD 1VO35 ♦Nh9 NOMI FaM1 DW section survey Tool Name Annotation (Ma1s M 1% Iu.M lural (usM t+VMuam luaM IMS Mlp 1'HwT M) 9,2]1.10 99.39 143.10 8.0%.it 5950.11 1,9]510 ]j23.74 5,038,325.08 CM 714.40 1123 6,15101 MrW GWSG(3) TIP 9,2%.00 90.31 144.3] fi09369 5,94]87 A, 966.66 1]3243 5,71931335 533,723.13 ].90 6.16554 M INC ONLY(4) KOP 9,334.36 6304 168.21 6,09235 5,046.35 -5,030.49 3,]5242 5,93926961 53374330 551.1 6210A6 MND-INC_ONLY(4) Interpolated Mim0th 9.359.51 82.17 171.5] 6,095.43 5,949A3 6.055.16 3,]55.95 5.93934515 531]4602 45.34 6,230A0 M"DW6G (5) 9,390.12 84.99 1W.B5 6,0%.8] 5,952.87 4.085.32 3752.82 5.939,21499 533.7..01 53.64 6,249.58 WD OW53 (5) 8,419.64 8167 211.08 6.1.]8 5,95418 5,11244 3,]41.]0 5,939.187.83 533,]32.60 SB 94 6,260.62 MMD OW53(6) 9,449.. as 225.66 6.102.7 5.856.27 5.135.86 3.]23.07 5,939,164.24 53171437 48.52 5,Nd.20 M1TNO ON5G(5) 9,4]9.21 86.59 24063 6104.01 5,95BA1 6.153.54 3.8%.61 5.939.146.57 533.690.98 5968 6.360.12 MWD MSG (5) " 9,509,03 W59 241363 6105.76 5.959.78 5,16912 3,67370 $838.13180 533,665.13 0.00 6,252.11 PROJECTED to TD 6202019 2'31.10PM Paye 3 COMPASS SI 14 Budd 850 BA ER0 ,PRINT DISTRIBUTIOw LIST 1 UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2E-17L1PB1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Ridera-bakerhuahes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V I BP North Slope. 'EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 219054 30 93 9 ;e sign and return one copy of this transmittal form to: 3coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. ioraee. Alaska 99510 LOG TYPE GR - RES LOG DATE May 2, 2019^ TODAYS DATE July 1, 2019 Revision No Details: Rev. Requested by: FIELD I FINAL CD/DVD PRELIM (las, dlis, PDF, META, I sFINAL REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES 1# OF COPIES 1# OF COPIES JUL 0 2 2019 AOGCC 0 0 0 0 0 0 1 7 1 1 1 0 10 5 DNR -Division of Oil & Gas *** 0 0 0 0 Ann: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 0 0 0 0 0 Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 A. (ER i-�UC HES 0 PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2E-17L1PB2 FIELD Greater Kuparuk Area COUNTY North Slope Borough 219054 30 94 0 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES BHI DISTRICT Alaska -- LOG DATE May 18, 2019 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE July 1, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V ) BP North Slope. EDA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExconMobil, Alaska Attn: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Ann: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 FIELD / FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES I#OFGOPlES # OF COPIES 01 0 0 1 0 10 � 1%110 0 1 1 0 0 5 DNR -Division of Oil & Gas *** 0 0 1 0 Q Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Q 1 0 Q Q Q Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2E-17LI ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-054 (revised) Surface Location: 642' FSL, 160' FWL, SEC. 36, TI IN, R9E, UM Bottomhole Location: 17647' FNL, 508' FWL, SEC. 1, TION, R9E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.olaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 193-174, API No. 50-029-22419- 00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner �/ , DATED this 15d�a'y of May, 2019. STATE OF ALASKA ALt A OIL AND GAS CONSERVATION COMMI, ON PERMIT TO DRILL �E Y i CJl1 20190'9 20 eer os nns 1� 1a. Type of Work: tb. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ ic. Specify if well is proposed for: Drill ❑ Lateral ❑' Stratigraphic Test ❑ Development - Oil Q Service - Winj ❑ Single Zone Q Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ I Exploratory -oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 2E-171_1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14,003' TVD: 6096' Kuparuk River Field / Kuparuk River Oil Pool - 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 642' FSL, 160' FWL, Sec 36, T11 N, R9E, UM ADL 0025658, ADL 25665 8. DNR Approval Number: 13. Approximate ate: y,.Q 11 t v Top of Productive Horizon: 943' FSL, 1398' FEL, Sec 1, T1 ON, R9E, UM LONS 84-029 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1764' FNL, 508' FWL, Sec 1, TION, R9E, UM 2560 11560' 41b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 146' 15. Distance to Nearest Well Open Surface: x- 529971 y- 5944285 1 Zone- 4 GL / BF Elevation above MSL (ft): 105' to Same Pool: 1346', 2E-0611 16. Deviated wells: Kickoff depth: 9275' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99 degrees Downhole: 3412 Surface: 2804 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 4478' 8802' 6068' 14,003' 6096' Slotted Liner 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): 9206' 6388' N/A 9108' 6311' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 200 sx CMT 121' 121' Surface 4440' 9-5/8" 800 sx AS III, 600 sx Class "G" 4481' 3473' Production 9165' 7" 275 sx Class "G" 9196' 6380' Perforation Depth MD (it): Perforation Depth TVD (h): N/A N/A Hydraulic Fracture planned? Yes El No Q 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch 8 Seabed Report a Drilling Fluid Program e✓ 20 AAC 25.050 requirement 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: Ryan McLaughli Authorized Name: James Ohlinger Contact Email: an.mclaU hlin CO .com Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 ` Date: Authorized Signature: Commission Use Only Permit to Drill 1API Number: Permit Approval See cover letter for other Number: — D 50- 0 7—— — 6-0 —0 J Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed metha�n-,e, gas hydrates, or gas contained in shales: Other: '0,9)C> te:57F -/z,-/z, 3g0C� /pb�L - Samples req'd: Yes[:] NO/Mud log req'd: Yes❑ No[e ff5 � � Z 50C)PSU92S measures: Yes Ly Nor❑�/ Directional svy req'd: Yes EKNo❑ ,1 kJV7V 1 C4V-,0r"VC s2 J!r Yes ❑ No Inclination -only svy req'd: Yes[] NOR' 4 �—G y.h goPs1-uck (�[ ttach gym) Spacing exception req'd: Ln Post initial injection MIT req'd: Yes❑ No[9' '1'nprV v -ed Fv r-f15•� . // / 41, APPROVED BY Approve I S THE COMMISSION Date: p� V7-5115//9 vnIVI1vhL Submit Form and Form 01 Revisetl 5/2077 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate a ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2E Pad 2E-17 2E-171-1 Plan: 2E-17L1_wp05 Standard Planning Report 13 May, 2019 BA UGHES a GE company ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2E-17 Mean Sea Level 2E-17 Q 146.00usft (2E-17) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor BA ER F�UGHES a GEcompany Site Kupamk 2E Pad 2E-17 ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_Kupamk Project: Kupamk River Unit Site: Kupamk 2E Pad Well: 2E-17 Wellbore: 2E -17L7 Design: 2E-17Ll_wp05 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2E-17 Mean Sea Level 2E-17 Q 146.00usft (2E-17) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor BA ER F�UGHES a GEcompany Site Kupamk 2E Pad 2E-17 Site Position: Northing: 5,944,247.48 usft Latitude; 70'15'31.481N From: Map Easting: 529,971.75 usft Longitude: 149" 45'27.897 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.23 ° Well 2E-17 Magnetics Model Name Sample Date Well Position +NIS 0.00 usft Northing: 5,944,284.83 usft Latitude: 70° 15'31.849 N 7/1/2019 +E/ -W 0.00 usft Easting: 529,971.26 usft Longitude: 149° 45'27.907 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2E-1711 Magnetics Model Name Sample Date Declination BGGM2018 7/1/2019 16.49 Design 2E-17L1_wp05 Audit Notes: Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/S (usft) (usft) 0.00 0.00 Dip Angle 80.81 Tie On Depth: +E/ -W (usft) 0.00 Field Strength (nT) 57,405 9,271.10 Direction (°) 13500 511312019 8:38:52PM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips Planning Report Bq�(ER i1UGHES s GEcompary Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 2E-17 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-17 @ 146.00usft (2E-17) Site: Kuparuk 2E Pad North Reference: True Well: 2E-17 Survey Calculation Method: Minimum Curvature Wellbore: 2E -17L1 Dogleg Build Design: 2E-17L1_wp05 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/S +E/ -W Rate Rate Rate TFO (usft) V) (°) (usft) (usft) (usft) (°/100usft) ('1100usft) (°7100usft) (^) Target 9,271.10 99.39 143.18 5,950.11 -4,975.10 3,72374 0.00 0.00 0.00 0.00 9,275.00 99.37 143.49 5,949.48 4,978.19 3,726.04 7.86 -0.51 7.95 93.72 9,305.00 87.64 150.20 5,947.64 -5,003.21 3,742.37 45.00 -39.10 22.36 150.00 9,335.00 84.24 163.30 5,949.78 -5,030.63 3,754.16 45.00 -11.34 43.66 105.00 9,625.00 93.74 293.65 5,959.50 -5,183.25 3,580.69 45.00 3.28 44.95 90.00 9,865.00 85.31 308.20 5,961.50 -5,060.37 3,375.55 7.00 -3.51 6.06 120.00 10,111.06 93.27 323.49 5,964.58 -4,884.49 3,204.82 7.00 3.23 6.21 62.75 10,231.59 93.27 323.49 5,957.70 -4,787.77 3,133.22 0.00 0.00 0.00 0.00 10,396.11 90.00 334.54 5,953.00 -4,647.03 3,048.71 7.00 -1.99 6.72 106.27 2E -171-1_T04 10,511.22 94.45 341.26 5,948.53 -4,540.54 3,005.46 7.00 3.87 5.84 56.39 10,621.84 94.45 341.26 5,939.95 -4,436.10 2,970.03 0.00 0.00 0.00 0.00 10,926.23 90.00 320.40 5,928.00 -4,172.08 2,822.58 7.00 -1.46 -6.85 -101.51 2E-171-1_705 10,976.37 86.49 320.57 5,929.53 -4,133.43 2,790.69 7.00 -6.99 0.33 177.33 11,313.88 86.49 320.57 5,950.17 -3,873.24 2,576.72 0.00 0.00 0.00 0.00 11,373.58 90.00 318.29 5,952.00 -3,827.92 2,537.91 7.00 5.87 -3.81 -33.01 2E-17L1_TO6 11,381.59 89.66 318.74 5,952.02 -3,821.91 2,532.60 7.00 -4.20 5.60 126.87 11,691.04 89.66 318.74 5,953.84 -3,589.30 2,328.53 0.00 0.00 0.00 0.00 11,770.27 93.00 314.31 5,952.00 -3,531.84 2,274.06 7.00 4.21 -5.59 -52.98 2E -171-1_T07 11,942.79 89.11 302.87 5,948.81 -3,424.46 2,139.48 7.00 -2.25 -6.63 -108.61 12,581.21 89.11 302.87 5,958.70 -3,077.99 1,603.34 0.00 0.00 0.00 0.00 12,652.47 90.40 298.05 5,959.00 -3,041.88 1,541.93 7.00 1.81 -6.76 -75.06 2E-17L7_T09 14,003.05 90.40 298.05 5,949.57 -2,406.75 350.05 0.00 0.00 0.00 0.00 5/1311019 8: 38.52PM Page 3 COMPASS 5000. 14 Build 85D �, ConocoPhillips BA ER ConocoPhillips Planning Report BAT a GEcompary Database: EDT 14 Alaska Production Local Coordinate Reference: Well 2E-17 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Mean Sea Level Project: Kupamk River Unit MD Reference: 2E-17 @ 146.00usft (2E-17) Site: Kupamk 2E Pad North Reference: True Well: 2E-17 Survey Calculation Method: Minimum Curvature Wellbore: 2EA71-7 Design: 2E-171-1_wP05 Planned Survey Measured TVD Below Vertical Dogleg Toclface Map Map Depth Inclination Azimuth System -NIS +E/ -W Section Rate Azimuth Northing Easting (usft) (1) (e) (usft) (usft) (raft) (usft) (°1100usft) (°) (usft) (usft) 9,271.10 99.39 143.18 5,950.11 -4,975.10 3,723.74 6,151.01 000 0.00 5,939,32508 533,71440 TIP 9,275.00 99.37 143.49 5,949.48 4,978.18 3,726.04 6,154.82 7.86 93.72 5,939,322.00 533,716.71 KOP 9,300.00 89.60 149.09 5,947.52 -4,998.89 3,739.84 6,179.22 45.00 150.00 5,939,301.35 533,730.59 9,305.00 87.64 150.20 5,947.64 -5,003.21 3,742.37 6,184.05 45.00 150.44 5,939,297.05 533,733.14 Start DLS 45.00 TFO 105.00 9,335.00 84.24 163.30 5,949.78 -5,030.63 3,754.16 6,211.79 45.00 105.00 5,939,269.67 533,745.04 Start DLS 45.00 TFO 90.00 9,400.00 84.97 192.67 5,956.02 -5,094.59 3,756.40 6,258.59 45.00 90.00 5,939,205.74 533,747.53 9,500.00 88.44 237.62 5,962.08 -5,174.07 3,700.35 6,275.17 45.00 87.18 5,939,126.03 533,691.80 9,600.00 92.81 282.42 5,960.93 -5,190.97 3,604.38 6,219.25 45.00 84.45 5,939,108.76 533,595.92 9,625.00 93.74 293.65 5,959.50 -5,183.25 3,580.69 6,197.04 45.00 84.97 5,939,116.38 533,572.19 Start DLS 7.00 TFO 120.00 9,700.00 91.10 298.20 5,956.33 -5,150.50 3,513.32 6,126.25 7.00 120.00 5,939,148.86 533,504.70 9,800.00 87.58 304.25 5,957.47 -5,098.70 3,427.87 6,029.19 7.00 120.19 5,939,200.32 533,419.05 9,865.00 85.31 308.20 5,961.50 -5,060.37 3,375.55 5,965.09 7.00 120.12 5,939,238.43 533,366.58 Start DLS 7.00 TFO 62.86 9,900.00 86.43 310.38 5,964.02 -5,038.26 3,348.53 5,930.36 7.00 62.75 5,939,260.43 533,339.48 10,000.00 89.67 316.59 5,967.43 4,969.52 3,276.07 5,830.51 7.00 62.59 5,939,328.88 533,266.76 10,100.00 92.91 322.80 5,965.17 4,893.33 3,211.44 5,730.94 7.00 62.38 5,939,404.81 533,201.83 10,111.06 93.27 323.49 5,964.58 -4,884.49 3,204.82 5,720.01 7.00 62.52 5,939,413.61 533,195.17 10,112.25 93.27 323.49 5,964.51 -4,883.53 3,204.11 5,718.83 0.00 0.00 5,939,414.57 533,194.46 Start 120.47 hold at 10112.25 MD 10,200.00 93.27 323.49 5,959.51 4,813.12 3,151.99 5,632.18 0.00 0.00 5,939,484.76 533,142.06 10,231.59 93.27 323.49 5,957.70 -4,787.77 3,133.22 5,600.99 0.00 0.00 5,939,510.04 533,123.20 10,232.72 93.25 323.56 5,957.64 4,786.87 3,132.55 5,599.88 7.00 106.27 5,939,510.94 533,122.53 Start DLS 7.00 TFO 106.45 10,300.00 91.92 328.09 5,954.61 -4,731.27 3,094.81 5,533.88 7.00 106.28 5,939,566.38 533,084.57 10,396.04 90.00 334.53 5,953.00 4,647.08 3,048.74 5,441.76 7.00 106.48 5,939,650.38 533,038.16 Start DLS 7.00 TFO 56.36 10,396.11 90.00 334.54 5,953.00 -4,647.03 3,048.71 5,441.71 7.00 106.59 5,939,650.43 533,038.13 10,400.00 90.15 334.76 5,952.99 -4,643.51 3,047.04 5,438.04 7.00 56.39 5,939,653.94 533,036.45 10,500.00 94.02 340.60 5,949.36 4,551.12 3,009.11 5,345.89 7.00 56.40 5,939,746.17 532,998.16 10,511.01 94.44 341.25 5,948.54 4,540.74 3,005.53 5,336.02 7.00 56.61 5,939,756.53 532,994.53 Start 110.94 hold at 10611.01 MD 10,511.22 94.45 341.26 5,948.53 -4,540.54 3,005.46 5,335.63 7.00 56.66 5,939,756.73 532,994.47 10,600.00 94.45 341.26 5,941.64 -4,456.72 2,977.02 5,256.45 0.00 0.00 5,939,840.43 532,965.70 10,621.84 94.45 341.26 5,939.95 -4,436.10 2,970.03 5,236.92 0.00 0.00 5,939,861.02 532,958.62 10,621.95 94.45 341.26 5,939.94 -4,436.00 2,969.99 5,236.83 0.00 0.00 5,939,861.12 532,958.59 Start DLS 7.00 TFO -101.61 10,700.00 93.34 335.89 5,934.63 -4,363.54 2,941.56 5,165.48 7.01 -101.51 5,939,933.46 532,929.86 10,800.00 91.88 329.04 5,930.07 4,275.01 2,895.40 5,070.25 7.00 -101.87 5,940,021.79 532,883.36 10,900.00 90.39 322.20 5,928.09 4,192.55 2,838.97 4,972.04 7.00 -102.19 5,940,104.02 532,826.61 10,926.17 90.00 320.41 5,928.00 -4,172.13 2,822.61 4,946.03 7.00 -102.32 5,940,124.38 532,810.17 Start DLS 7.00 TFO 177.38 10,926.23 90.00 320.40 5,928.00 -4,172.08 2,822.58 4,945.97 7.00 -102.33 5,940,124.42 532,810.13 10,976.31 86.50 320.57 5,929.53 -4,133.47 2,790.73 4,896.15 7.00 177.33 5,940,162.90 532,778.14 Start 337.54 hold at 10976.11 MD 10,976.37 86.49 320.57 5,929.53 4,133.43 2,790.69 4,896.09 7.00 177.32 5,940,162.95 532,778.10 11,000.00 86.49 320.57 5,930.98 -4,115.21 2,775.71 4,872.62 0.00 0.00 5,940,181.10 532,763.05 11,100.00 86.49 320.57 5,937.09 4038.12 2,712.31 4,773.27 0.00 0.00 5,940,257.94 532,699.35 .5/132019 8:38:52PM Page 4 COMPASS 5000.14 Build 85D `, ConocoPhillips BA ER Cohilllps Planning Report I'�I iIOCOGHES BAT GE company Database: EDT 14 Alaska Production Local Coordinate Reference: Well 2E-17 Company: ConocoPhillips Alaska Inc_Kupawk TVD Reference: Mean Sea Level Project Kupawk River Unit MD Reference: 2E-17 @ 146.00usft (2E-17) Site; Kuparuk 2E Pad North Reference: True Well; 2E-17 Survey Calculation Method: Minimum Curvature Wellbore: 2E-171-7 Azimuth System Design: 2E-1711_wP05 Section Rate Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System •N/ -S +E/4N Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) ('/100usft) (°) (usft) (usft) 11,200.00 86.49 320.57 5,943.21 -3,961.03 2,648.91 4,673.93 0.00 0.00 5,940,334.77 532,635.65 11,300.00 86.49 320.57 5,949.33 -3,883.93 2,585.51 4,574.59 0.00 0.00 5,940,411.60 532,571.95 11,313.85 86.49 320.57 5,950.17 -3,873.26 2,576.73 4,560.83 0.00 0.00 5,940,422.24 532,563.13 Start DLS 7.00 TFO -32.98 11,313.88 86.49 320.57 5,950.17 -3,873.24 2,576.72 4,560.80 0.00 0.00 5,940,422.26 532,563.11 11,373.53 90.00 318.29 5,952.00 -3,827.96 2,537.95 4,501.38 7.00 -33.01 5,940,467.38 532,524.17 Start DLS 7.00 TFO 127.04 11,373.58 90.00 318.29 5,952.00 -3,827.92 2,537.91 4,501.32 7.00 -32.94 5,940,467.42 532,524.13 11,381.50 89.67 318.74 5,952.02 -3,821.98 2,532.66 4,493.41 7.00 126.87 5,940,473.34 532,518.86 Start 309.53 hold at 11381.50 MD 11,381.59 89.66 318.74 5,952.02 -3,821.91 2,532.60 4,493.32 7.00 126.87 5,940,473.40 532,518.80 11,400.00 89.66 318.74 5,952.13 -3,808.08 2,520.47 4,474.96 0.00 0.00 5,940,487.19 532,506.61 11,500.00 89.66 318.74 5,952.72 -3,732.91 2,454.52 4,375.17 0.00 0.00 5,940,562.09 532,440.37 11,600.00 89.66 318.74 5,953.31 -3,657.73 2,388.57 4,275.39 0.00 0.00 5,940,636.99 532,374.13 11,691.03 89.66 318.74 5,953.84 -3,589.30 2,328.54 4,184.55 0.00 0.00 5,940,705.17 532,313.84 Start DLS 7.00 TFO -52.96 11,691.04 89.66 318.74 5,953.84 -3,589.30 2,328.53 4,184.54 0.00 0.00 5,940,705.18 532,313.83 11,700.00 90.04 318.24 5,953.86 -3,582.59 2,322.60 4,175.60 7.00 -52.98 5,940,711.87 532,307.87 11,770.22 93.00 314.31 5,952.00 -3,531.88 2,274.10 4,105.44 7.00 -52.98 5,940,762.38 532,259.17 Start OLS 7.00 TFO -108.60 11,770.27 93.00 314.31 5,952.00 -3,531.84 2,274.06 4,105.40 7.00 -53.08 5,940,762.41 532,259.13 11,800.00 92.33 312.34 5,950.62 -3,511.47 2,252.46 4,075.71 7.00 -108.61 5,940,782.70 532,237.45 11,900.00 90.08 305.71 5,948.51 -3,448.56 2,174.83 3,976.34 7.00 -108.70 5,940,845.29 532,159.58 11,942.79 89.11 302.87 5,948.81 -3,424.46 2,139.48 3,934.30 7.00 -108.84 5,940,869.25 532,124.14 Start 638A3 hold at 11942.79 MD 12,000.00 89.11 302.87 5,949.70 -3,393.41 2,091.44 3,878.37 0.00 0.00 5,940,900.11 532,075.97 12,100.00 89.11 302.87 5,951.24 -3,339.14 2,007.46 3,780.62 0.00 0.00 5,940,954.03 531,991.79 12,200.00 89.11 302.87 5,952.79 -3,284.87 1,923.48 3,682.86 0.00 0.00 5,941,007.96 531,907.60 12,300.00 89.11 302.87 5,954.34 -3,230.60 1,839.50 3,585.10 0.00 0.00 5,941,061.89 531,823.42 12,400.00 89.11 302.87 5,955.89 -3,176.33 1,755.52 3,487.35 0.00 0.00 5,941,115.82 531,739.23 12,500.00 89.11 302.87 5,957.44 -3,122.07 1,671.54 3,389.59 0.00 0.00 5,941,169.75 531,655.04 12,581.21 89.11 302.87 5,958.70 -3,077.99 1,603.34 3,310.20 0.00 0.00 5,941,213.55 531,586.67 12,581.22 89.11 302.87 5,958.70 -3,077.99 1,603.33 3,310.19 0.00 0.00 5,941,213.55 531,586.67 Start DLS 7.00 TFO -75.05 12,600.00 89.45 301.60 5,958.93 -3,067.97 1,587.45 3,291.88 7.00 -75.06 5,941,223.50 531,570.75 12,652.42 90.40 298.06 5,959.00 -3,041.90 1,541.98 3,241.29 7.00 -75.05 5,941,249.39 531,525.18 Start 1350.68 hold at 12652.42 MD 12,652.47 90.40 298.05 5,959.00 -3,041.88 1,541.93 3,241.25 7.00 -75.04 5,941,249.41 531,525.13 12,700.00 90.40 298.05 5,958.67 -3,019.53 1,499.99 3,195.78 0.00 0.00 5,941,271.59 531,483.11 12,800.00 90.40 298.05 5,957.97 -2,972.50 1,411.74 3,100.13 0.00 0.00 5,941,318.26 531,394.68 12,900.00 90.40 298.05 5,957.27 -2,925.48 1,323.49 3,004.47 0.00 0.00 5,941,364.93 531,306.25 13,000.00 90.40 298.05 5,956.57 -2,878.45 1,235.24 2,908.82 0.00 0.00 5,941,411.60 531,217.82 13,100.00 90.40 298.05 5,955.88 -2,831.42 1,146.99 2,813.16 0.00 0.00 5,941,458.27 531,129.40 13,200.00 90.40 296.05 5,955.18 -2,784.40 1,058.74 2,717.51 0.00 0.00 5,941,504.94 531,040.97 13,300.00 90.40 298.05 5,954.48 -2,737.37 970.49 2,621.85 0.00 0.00 5,941,551.61 530,952.54 13,400.00 90.40 298.05 5,953.78 -2,690.34 882.24 2,526.20 0.00 0.00 5,941,598.28 530,864.11 13,500.00 90.40 298.05 5,953.08 -2,643.32 793.99 2,430.55 0.00 0.00 5,941,644.95 530,775.69 13,600.00 90.40 298.05 5,952.39 -2,596.29 705.74 2,334.89 0.00 0.00 5,941,691.62 530,687.26 13,700.00 90.40 298.05 5,951.69 -2,549.27 617.49 2,239.24 0.00 0.00 5,941,738.29 530,598.83 13,800.00 90.40 298.05 5,950.99 -2,502.24 529.24 2,143.58 0.00 0.00 5,941,784.96 530,510.40 13,900.00 90.40 298.05 5,950.29 -2,455.21 440.99 2,047.93 0.00 0.00 5,941,831.63 530,421.98 14,000.00 90.40 298.05 5,949.59 -2408.19 352.74 1952.27 0.00 0.00 5,941,878.30 530,333.55 5/132019 8:38:52PM Page 5 COMPASS 5000.14 Build 85D _, ConocoPhillips ER Cono4hilf1ps Planning Report UGHE$ a GE.nrpany Database: EDT 14 Alaska Production Local Coordinate Reference: Well 2E-17 Vertical Casing Company: ConocoPhillips Alaska Inc_Kuparuk Depth Target Name TVD Reference: Mean Sea Level (usft) Name (in) Project: Kupamk River Unit 5,949.57 2 3/8" 2.375 MD Reference: 2E-17 @ 146.00usfr (2E-17) Dip Dir. Site: Kupamk 2E Pad +E/ -W Northing North Reference: True -Shape Well: 2E-17 (usft) (usft) Survey Calculation Method: Minimum Curvature (usft) Latitude Wellbore: 2E -17L1 0.00 0.00 5,952.00 -3,531.84 2,274.06 5,940,762.41 Design: 2E-17L1_wp05 149'44'21.775 W - plan hits target center Planned Survey - Point Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (_) (e) (usft) (usft) (usft) (usft) (°/100usft) (") (usft) (usft) 14,003.00 90.40 298.05 5,949.57 -2,406.77 350.09 1,949.40 0.00 0.00 5,941879.71 530,330.89 Planned TD at 14003.00 2E-17Li T04 14,003.05 90.40 298.05 5,949.57 -2,406.75 350.05 1,949.35 0.00 0.00 5,941,879.73 530,330.85 Targets Measured Vertical Casing Hole Depth Depth Target Name Diameter (usft) (usft) Name (in) (in) 14,003.00 5,949.57 2 3/8" 2.375 3.000 -hit/miss target Dip Angle Dip Dir. TVD •NIS +E/ -W Northing Easting -Shape N V) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2E-171-1 T07 0.00 0.00 5,952.00 -3,531.84 2,274.06 5,940,762.41 532,259.13 70° 14' 57.110 N 149'44'21.775 W - plan hits target center - Point 2E-1711_705 0.00 0.00 5,928.00 <,172.08 2,822.58 5,940,124.42 532,810.13 70° 14'50.811 N 149" 44'5.830 W - plan hits target center - Paint 2E-17Li T04 0.00 0.00 5,953.00 -4,647.03 3,048.71 5,939,650.43 533,038.13 70° 14'46.139 N 149° 43'59.260 W - plan hits target center - Point 2E-1711_706 0.00 0.00 5,952.00 -3,827.92 2,537.91 5,940,467.42 532,524.13 70' 14'54A97 N 149° 44' 14.104 W - plan hits target center - Paint 2E-17Li T09 0.00 0.00 5,959.00 -3,041.88 1,541.93 5,941,249.41 531,525.13 70° 15' 1.930 N 149° 44'43.063 W - plan hits target center - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,003.00 5,949.57 2 3/8" 2.375 3.000 5/13,2019 8:38.52PM Page 6 COMPASS 5000.14 Build 85D , ConocoPhillips B A Measured Conoco`Phillips Planning Report F�UERGHES GEmmpany Depth Depth a Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 2E-17 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-17 @ 146.00usft (2E-17) Site: Kuparuk 2E Pad North Reference: True Well: 2E-17 Survey Calculation Method: Minimum Curvature Wellbore: 2E-171-1 KOP 9,305.00 Design: 2E-17Ll_wp05 -5,003.21 3,742.37 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NI-S +E/ -W (usft) (usft) (usft) (usft) Comment 9,27110 5,950.11 -4,975.10 3.723.74 TIP 9,275.00 5,949.48 -4,978.19 3,726.04 KOP 9,305.00 5,947.64 -5,003.21 3,742.37 Start DLS 45.00 TFO 105.00 9,335.00 5,949.78 -5,030.63 3,754.16 Start DLS 45.00 TFO 90.00 9,625.00 5,959.50 -5,183.25 3,580.69 Start DLS 7.00 TFO 120.00 9,865.00 5,961.50 -5,060.37 3,375.55 Start DLS 7.00 TFO 62.86 10,112.25 5,964.51 4,883.53 3,204.11 Start 120A7 hold at 10112.25 MD 10,232.72 5,957.64 4,786.87 3,132.55 Start DLS 7.00 TFO 106.45 10,396.04 5,953.00 4,647.08 3,048.74 Start DLS 7.00 TFO 56.36 10,511.01 5,948.54 -4,540.74 3,005.53 Start 110.94 hold at 10511.01 MD 10,621.95 5,939.94 -4,436.00 2,969.99 Start DLS 7.00 TFO -101.51 10,926.17 5,928.00 -4,172.13 2,822.61 Start DLS 7.00 TFO 177.38 10,976.31 5,929.53 -4,133.47 2,790.73 Start 337.54 hold at 10976.31 MD 11,313.85 5,950.17 -3,873.26 2,576.73 Start DLS 7.00 TFO-32.98 11,373.53 5,952.00 -3,827.96 2,537.95 Staff DLS 7.00 TFO 127.04 11,381.50 5,952.02 -3,821.98 2,532.66 Start 309.53 hold at 11381.50 MO 11,691.03 5,953.84 -3,589.30 2,328.54 Start DLS 7.00 TFO-52.96 11,770.22 5,952.00 -3,531.88 2,274.10 Start DLS 7.00 TFO-108.60 11,942.79 5,948.81 -3,424.46 2,139.48 Start 638.43 hold at 11942.79 MD 12,581.22 5,958.70 -3,077.99 1,603.33 Start DLS 7.00 TFO-75.05 12,652.42 5,959.00 -3,041.90 1,541.98 Start 1350.58 hold at 12652.42 MD 14,003.00 5,949.57 -2,406.77 350.09 Planned TD at 14003.00 5/1312019 8:38:52PM Page 7 COMPASS 5000.14 Build 85D Kuparuk CTD Laterals 2E-171-1 and 2E-171-2 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)).._....... ................. _ ...... ..... ......................... .... ............ ................2 2. Location Summa ..... .•..•••• •••• ••••• •••••• 2 (Requirements of 20 AAC 25.005(c)(2)) . ......................... .... .......... ........ ......... ......... . ..........2 3. Blowout Prevention Equipment Information................................................................................. 2 ... (Requirements of 20 AAC 25.005 (c)(3)).. ............... .......................... ....... _..... ............. .................. ....................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)).. . _............................ ._-..-... ............. ......-................ ........ ..................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))... ........... ..... ..................... ............ ......... ........ ...... .... ................... ..._........2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) ...... ............-.._............................. --- .... .............. ................-- ..............................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7)) ... ............... ..........._................ .................... ............ ................... ...................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8))_ .. ........... ........ ... .................... .............. ................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)) ... ................................ ................................ .............................. ..... ...................... ...........4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)) .............................................. ........ .. ............. . _................. ..... _.. ....................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11)). ...- ........ .................. .............. _...... ............................. ............. .............4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12)) . ................. ........... .....-.......... ................ ................. ..... ..-... . ................ 4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13)) ..... .... .................... ............ ............ ............ ........_._ ._............... ........._.........4 Summaryof Operations.................................................--.............--...........................................................................4 LinerRunning ............ ............. ........ ........................................... -....... --............................................ ........... ............. .....5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14)).......... .... ................ ........... ................. .......................... ... .............. ............ ... ......._.,..6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20AAC 25.050(b)).-.... .......... .............. .............................._ ......._..._..... ......_..__ ..__...............6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 2E -17L1 and 2E-1712 laterals ........ --....................................................................6 Attachment 2: Current Well Schematic for 2E-17............................................................................................................6 Attachment 3: Proposed Well Schematic for 2E-171-1, and 2E-1712 laterals..................................................................6 Page 1 of 6 April 04, 2019 PTU Application: 2E -17L1 & 2E-171-2 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed laterals described in this document are 2E -17L1 and 2E-171-2. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,800 psi. Using the maximum formation pressure in the area of 3,412 psi in 1L-23 (i.e. 10.7 ppg EMW), the maximum potential surface pressure in 2E-17, assuming a gas gradient of 0.1 psi/ft, would be 2,804 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 2E-17 is expected to be around 2,532 psi (8.0 ppg EMW). The maximum downhole pressure in the 2E-17 vicinity is the 1L-23 at 3,412 psi (10.7 ppg EMW) on 04/20/2018. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 2E-17 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2E-17 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2E-17 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 April 04, 2019 PTU Avolication: 2E-171-1 & 2E-171-2 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 16" 62.5 H-40 Welded Surface 2VI 4.7#, L-80, ST -L slotted liner; 2E-171-1 8,802' 14,003' 5,922' 5,950' deployment sleeve on to 36 J-55 BTC Surface 4,481' 2%", 4.7#, L-80, ST -L slotted/blank 2E-171-2 9275' 13,749' 5,949' 5,932' liner; aluminum billet on to Existing Casing/Liner Information Category OD Weigh t Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 121' Surface 121' 1640 670 Surface 9-5/8" 36 J-55 BTC Surface 4,481' Surface 3,473' 3520 2020 Production 7" 26 L-80 BTC -MOD Surface 9,196' Surface 6,380' 7240 5410 Tubing3-1/2" 9.3 L-80 EUE 8RM Surface 8,862' Surface 6,115' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 -psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2E-17 laterals we will target a constant BHP of 11.8 EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 April 04, 2019 PTD ADDllcation: 2E -17L1 & 2E -17L2 Pressure at the 2E-17 Window (8827' MD, 6087' TVD) Usinq MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 2E-17 is equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sands to the northwest and southeast of 2E-17. The laterals will increase C -sand resource recovery and throughput. A recent rig workover installed tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge in the tandem wedge. CDR3-AC will mill a window in the tubing and casing at 8,827' MD and the 2E 1711 lateral will be dF Ued to TD at 13,300' Lip W 8 822' ne targeting the G sand te the nnrth,.AfP,;t. ItWili be Gempleted with 9 218" slatted liner TD MD . -And drill 2E -17L1 PB1 to a depth of 8874' MD A second inner wedge will be run and set on rig to facilitate a window for the 2E -17L2 lateral. CDR3-AC will mill a second window at 8,807' MD and the 2E -17L2 lateral will be drilled to a TD of 13,749' MD targeting the C -sand to the southeast. it will be completed with 2-3/8" slotted/blank liner with an aluminum billet from TD up to 9275' MD. The 2E -17L1 lateral will kick off from the L2 lateral at a depth of 9275' MD and drill to a depth of 14,003' MD. The lateral will be completed with slotted/blank liner from TD into the 3-1/2" tubing at 8,802' MD with a deployment sleeve. Pre -CTD Work 1. RU Slick -line: Drift tubing, install GLV design, and set X -lock. 2. RUE -line: Set inner wedge. Page 4 of 6 April 04, 2019 Pumps On 1.8 bpm) Pumps Off Formation Pressure 8.0 2532 Psi 2532 psi Mud Hydrostatic 8.6 2722 psi 2722 psi Annular friction i.e. ECD, 0.080psi/ft) 706 psi 0 psi Mud + ECD Combined no chokepressure) 3428 psi overbalanced -896psi) 2722 psi overbalanced -190psi) Target BHP at Window 11.8 3735 psi 3735 psi Choke Pressure Required to Maintain Target BHP 307 psi 1013 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 2E-17 is equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sands to the northwest and southeast of 2E-17. The laterals will increase C -sand resource recovery and throughput. A recent rig workover installed tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge in the tandem wedge. CDR3-AC will mill a window in the tubing and casing at 8,827' MD and the 2E 1711 lateral will be dF Ued to TD at 13,300' Lip W 8 822' ne targeting the G sand te the nnrth,.AfP,;t. ItWili be Gempleted with 9 218" slatted liner TD MD . -And drill 2E -17L1 PB1 to a depth of 8874' MD A second inner wedge will be run and set on rig to facilitate a window for the 2E -17L2 lateral. CDR3-AC will mill a second window at 8,807' MD and the 2E -17L2 lateral will be drilled to a TD of 13,749' MD targeting the C -sand to the southeast. it will be completed with 2-3/8" slotted/blank liner with an aluminum billet from TD up to 9275' MD. The 2E -17L1 lateral will kick off from the L2 lateral at a depth of 9275' MD and drill to a depth of 14,003' MD. The lateral will be completed with slotted/blank liner from TD into the 3-1/2" tubing at 8,802' MD with a deployment sleeve. Pre -CTD Work 1. RU Slick -line: Drift tubing, install GLV design, and set X -lock. 2. RUE -line: Set inner wedge. Page 4 of 6 April 04, 2019 PTD Application: 2E -17L1 & 2E -17L2 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2E -17L1 PB1 Lateral (C4 sand - Northwest) a. Mill 2.80" window at 8,827 MD. b. Drill 3" bi-center lateral to TD of 8874' MD. G. R. 234^ slotted r rh dep!Gyrnent sleeve from TID p to a aor ME) 3. 2E -17L2 Lateral (C4 sand - Southeast) a. Set X -lock and inner wedge. b. Mill 2.80" window at 8,807' MD. c. Drill 3" bi-center lateral to TD of 13,749' MD. d. Run 2%" slotted/blank liner with aluminum billet from TD up to 9275' MD. 4. 2E-1711 Lateral (C4 sand -Northwest) a. Kick off of aluminum billet at 9275' MD b. Drill 3" bi-center lateral to a TD of 14,003' MD c. Run 2-3/8" slotted/blank liner with a deployment sleeve from TD into the 3-1/2" tubing at 8802' MD 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. - Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the BHA is lowered in place via slick -line. - When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed set of ball valve and check valve isolate reservoir pressure internal to the BHA. Slips on the deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. - The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - 2E-17 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. - While running 2W slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a Page 5 of 6 April 04, 2019 PTD Application: 2E -17L1 8,2E -17L2 deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2E-171-1 11, 560' 2E-171-2 8,435' Distance to Nearest Well within Pool Lateral Name Distance Well 2E -1 7L1 1,346' 2E-061-1 2E-1712 1,573' 1L-231-1-02 16. Attachments Attachment 1: Directional Plans for 2E -17L1 and 2E -17L2 laterals. Attachment 2: Current Well Schematic for 2E-17. Attachment 3: Proposed Well Schematic for 2E -17L1, and 2E -17L2 laterals. Page 6 of 6 April 04, 2019 ] � { \/ \ k ){ § # ; ` Loepp, Victoria T (DOA) From: Sent: To: Subject: Ryan, Loepp, Victoria T (DOA) Monday, May 13, 2019 12:49 PM McLaughlin, Ryan; Boyer, David L (DOA) Re: 2E-17 CTD Update / all —07 Irl—D Please submit a revised PTD for 2E-171-1 with the new kickoff point and anything else that has changed. We will expedite the approval. Thanx, Victoria Sent from my iPhone On May 13, 2019, at 12:42 PM, McLaughlin, Ryan <Rvan.McLauehlin conocophillips.com> wrote: Victoria, Nabors CDR3-AC is currently working KRU 2E-17, a well that was recently worked over to install a tandem wedge assembly for CDR3 to kick off from. A window was milled in the lower tandem wedge at 8827' MD to drill the 2E-171-1 lateral (219-054), but unfortunately the window milling did not go as plan and we were only able to drill to 8874' MD before determining that the window was not in good enough condition to drill and complete a lateral, and was called 2E-17L1PB1. We then set a whipstock in our upper tandem wedge at 8807' MD and currently are drilling the 2E-171-2 lateral (219-055). Since these were our only two possible kickoff points available, we plan on completing the L2 with slotted liner and an aluminum billet from TD to 9271' MD and kicking off there to drill the 2E -17L1 lateral. Is any formal notification or approval required for this change? Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G 5t, ATO 670, Anchorage, AK 99501 <2E-17 Proposed CTD Schematic V2.pdf> Revised TRANSMITTAL LETTER CHECKLIST /� WELL NAME: KR (,l 2 E— 17- L.'- cRe'v (,5euJ �) PTD: V Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: K iA p arts S R r Vp !f POOL: Ku Paeu K R! V2jl O 71 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50- 0 Zq al t1-14 QQ QQ• (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- -_� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 _ PTD#:2190540 Company CONOCOPHILLIP_S.ALASKA INC Initial Classrrype _Well Name: KUPARU RjY_ ll11 Program Elm _ _ _ Well bore seg Q DEV/PEND GeoArea 890 Unit 111160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached. _ _ . . . .. . . . ......... . . . . . . . _ NA. _ _ ...... 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. _ _ _ _ _ _ _ _ _ Yes 7 Sufficient acreage. available in drilling unit . . ..... . . . . . . . . . ...... . . ....... Yes 8 If deviated, is. wellbore plat included . . . . . .......... . . . . . . _ _ _ _ Yes _ _ Directional. plan viewincludedand wellbore cross-section 9 Operator only affected party. _ - - - - - _ _ _ Yes 10 Operator has appropriate bond in force _ _ _ _ _ _ _ _ ___________ _ _ _ _ _ _ _ Yes 11 Permit. can be issued without conservation order _ _ _ .... _ _ _ _ _ Yes _ Appr Date 12 Permit can be issued without administrative approval .. . . . . . . . . ....... Yes 13 Can permit be approved before 15 -day wait.. Yes DLB 5/14/2019 14 Well located within area and strata authorized by Injection Order # (put IO# in. comments).(For- NA_ _ .......... - - 15 All wells within 1/4 mite area of review identified (For service well only) .. NA_ 16 Pre -produced injector; duration of pre production less than 3 months (For service well only) NA_ 17 18 Nonconven, gas conforms to AS31,05,03QQ.1.A),(j_2.A-D) - - - ...... _ _ _ _ _ ..NA------- Conductor stringprovided_ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ NA- - - - - - - - - - - - - - - - -------- - - - - - - - _ - Conductor set in KRU 2E-17 ........ Engineering 19 Surface casing. protects all known USDWs . _ _ _ _ _ NA - _ . _ .. Surface casing set in KRU 2E-17 20 CMT -vol adequate, to circulate, on conductor & surf. csg .. NA _ _ Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg_ _ .. NA 22 CMT will cover all known productive horizons No Productive_ interval will be completed with. uncemented slotted liner 23 Casing designs adequate for C, T, B &_permafrost _ _ _ _ - - - - - - - - - - - - - - Yes _ _ _ _ _ .... _ . _ . _ _ _ _ _ . _ _ _ _ - - - - - - ..... ........ . 24 Adequate tankage or reserve pit _ _ _ _ _ ... _ _ _ Yes . Rig has steel tanks; all waste to approved disposal wells... _ .... 25 If a_re-drill, has.a 10403 for abandonment been approved _ _ _ _ _ _ _ _ _ NA . . . . . . . . . . . . ... . . . . . . . . . . . . . . . ................ 26 Adequate wellbore separation proposed _ _ _ _ _ _ _ _ Yes _ _ Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations_ _ _ _ _ _ _ _ NA _____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ______ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _____ Appr Date 28 Drilling fluid program schematic & equip list adequate _ _ _ _ Yes _ _ Max formation. pressure is 3412 psig(10.7 ppg EMW ); will drill w/ 8.6-ppg EMW and maintain overbal w/ MPD VTL 5/15/2019 29 BOPEs, do they meet regulation - _ _ _ _ _ Yes _ _ _ 4 ram. BOP Stack has been approved to use instead of the 6 ram BOP stack .... . ... . . . . . . 30 BOPE-press rating appropriate; test to _(put prig in comments). ... - - _ _ Yes _ MPSP is 2804 pslg; will test. BOPS to 3800_psig _ _ _ _ _ _ _ _ _ _ _ _ _ _ ......... 31 Choke. manifold complies w/API. RP -53 (May 84) - - _ _ _ .... _ _ _ Yes 32 Work will occur without operation shutdown. _ _ _ _ YES 33 Is presenceof 1-12S gas probable . . . . . . . .......... . . _ _ _ ... Yes _ _ _ _ _ 1-12S measures required.. 34 Mechanical condition of wells within AOR verified (Fof.serv[ce well only) . . . . .......... NA _ _ _ _ _ .... - - - - - - - . - - - - - - - - _ _ _ ...... 35 Permit can be issued w/o, hydrogen. sulfide measures ___...... _ _ _ _ _ _ _ _ _ _ _ No... _ _ Wells on 2E Pad exceed 20. ppm limit in 20AAC 25,065(a) regulation Geology 36 Data presented on potential overpressure zones _ _ _ _ _ --------------- Yes.......... --------- - - - - - - - - - - - - - - - - - - -- - -- - - ---- - - - ApprDate 37 Seismic analysis of shallow gas zones- ............ ................. NA_ _ _ _ _ _ _ _____ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ DLB 5/14/2019 38 Seabed condition survey (if off -shore) _ _ _ _ - - - - - - NA . . ................. . . . . . . . . . . . . . . 39 Contact name/phone for weekly progress reports [exploratory only] . . ........ ... . NA Geologic Engineering Public Kickoff point modified. VTL 5/15/19 Date: to Date Commissioner: Commissi ner: / �r1 Commissioner DTS 4/25/2019 JL 4/2 /201/J THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2E -17L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-054 Surface Location: 642' FSL, 160' FWL, SEC. 36, TI IN, R9E, UM Bottomhole Location: 1767' FNL, 513' FWL, SEC. 1, T10N, R9E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc. a las ko.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 193-174, API No. 50-029-22419- 00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this _ day of April, 2019. STATE OF ALASKA Ab _e(A OIL AND GAS CONSERVATION COMMIbbION PERMIT TO DRILL 20 AAC 25.005 RECEIVED APR 0 5 2019 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Speci e p dor: Drill El ❑� Stratigraphic Test ❑ Development - Oil 21 Service - Winj El Single Zone 2Coalbed Gas Gas Hydrates ❑ Redrill ❑ Reentry ❑ I Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 2E -17L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13300' TVD: 6095" Kuparuk River Field / Kuparuk River Oil Pool z 4a. Location of Well (Governmental Section): 7.'ro Dsignation:,rSc.5 �r,� B Surface: 642' FSL, 160' FWL, Sec 36, T11 N, R9E, UM Z.a ADL 25 - Top of Productive Horizon: 8. DNR Approval Number: 7 13. Approximate Spud Date: 1251' FSL, 1701' FEL, Sec 1, TI ON, R9E, UM LONS 84-029 4/18/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1767' FNL, 513' FWL, Sec 1, TI ON, R9E, UM 2560 11560' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 146' . 15. Distance to Nearest Well Open Surface: x- 529971 y- 5944285 Zone- 4 GL / BF Elevation above MSL (ft): 105' to Same Pool: 1354', 2E -06L1 16. Deviated wells: Kickoff depth: 8827 • feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99 • degrees Downhole: 3412 Surface: 2804 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 4478' 8822' 6083' 13300' 6095' Slotted Liner 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): 9206' 6388' N/A 9108' 6311' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 200 sx CMT 121' 121' Surface 4440' 9-5/8" 800 sx AS III, 600 sx Class "G" 4481' 3473' Production 9165' 7" 275 sx Class "G" 9196' 6380' Perforation Depth MD (ft): Perforation Depth TVD (ft): N/A N/A Hydraulic Fracture planned? Yes[] No ❑� 20. Attachments: Property Plat ❑ BOP SketchR Drilling Program Time v. Depth Plot Shallow Hazard Analysis ® 8 Diverter Sketch LJ Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Dale 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: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith. E. Herrin c0 .COm Authorized Title: Staff CTD ginear Contact Phone: 907-263-4321 Authorized Signature.Date: ` Commission Use Only Permit to Drill JAPI Number: Permit Approval q See cover letter for other Number:- —. Q 50- Da 1� requirements. r-✓ Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed mel arnne, gas hydrates, or gas contained in shales: Lv� Other: gdrp 't<57' 71r, fjba � S Samples req'd: Yes Noy' Mud log req'd: Yes ❑ No[' 5 fi-vi n ril c1 r r�vl.. -to c❑A HzS measures: YesR' No❑ Directional svy req'd: Yes Y NO❑ .- fz'S 7` Zb�iO 7 s� p5 a¢figexception req'd: Yes ElNoLJNf Inclination -only svy req'd: Yes E] NoS' C h c -d) 0 -,Pp ro v�d {o,- vs= Post initial injection MIT req'd: Yes El NOE — 1�4t� APPROVED BY j Approved by: COMMISSIONER THE COMMISSION Date: �� VC, 1/7-1 9/�5//? ORIGINAL Ay4 V Form 10-01 Revised 5/2017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments Submd Form and in Duplicate r_ -t. 9, ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 04, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 2E-17 (PTD# 193-174) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in mid-April 2019. The objective will be to drill two laterals, KRU 2E- 171-1 & 2E -17L2 targeting the Kuparuk C -sand interval. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 2E-171-1 & 2E-171-2 - Detailed Summary of Operations - Directional Plans for 2E-171-1 & 2E-171-2 - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 2E -17L1 and 2E -17L2 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(6)) ........... ................. .................. ...... ........ .... ............ ........... _..... _2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))......_._............_._..._._._....._._.................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3)) ............... .--.......... .. _...... _... ............ ...2 ................. ................ . ............... . 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)). ........... ............. ............................. .......... ............. ............2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).. ......_....... ..._....................... ._...... ............ ............2 ........... ............... . 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) . ...... ................. ......... ................................. --........... ...._.................. ._.......................... ........ .3 7. Diverter System Information..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)) .. ................................... ......._.__.... ......................................... ...... ........................... .3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)).. _..... _. _.... _.............................._.............................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)) ........... ...................... _........ .............. _.... . ... ......... ... ..........4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11)). ......... ....._............... ................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12)) ....... ............................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13)).. .................... .........................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))........_....................................................................................................................-..............-6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 ....... (Requirements of 20 AAC 25.050(6)) ....... ... .......-.... _ .6 .... ......................... ......._........... ........................ 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 2E -17L1 and 2E-1712 laterals.................................................................................6 Attachment 2: Current Well Schematic for 2E-17 ............... ............................ -... .................... .............................. .......... 6 Attachment 3: Proposed Well Schematic for 2E-1711, and 2E-1712 laterals..................................................................6 Page 1 of 6 April 04, 2019 PTD ADDlication: 2E-171_1 8,2E -17L2 1. Well Name and Classification (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)) The proposed laterals described in this document are 2E-171-1 and 2E -17L2. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 8 oP eta rk SG A r h-7 gy-1,L 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) a Pro vmac/ ja v OV Please reference blowout prevention (BOP) schen file wi Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,800 psi. Using the maximum formation pressure in the area of 3,412 psi in 1 L-23 (i.e. 10.7 ppg EMW), the maximum potential surface pressure in 2E-17, assuming a gas gradient of 0.1 psi/ft, would be 2,804 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 2E-17 is expected to be around 2,532 psi (8.0 ppg EMW). The maximum downhole pressure in the 2E-17 vicinity is the 1L-23 at 3,412 psi (10.7 ppg EMW) on 04/20/2018. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 2E-17 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2E-17 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2E-17 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 April 04, 2019 PTD Application: 2E-171-1 & 2E-1712 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 2E-171-1 8,822' 13,300' 5,937' 5,949' 2W, 4.7#, L-80, ST -L slotted liner; Surface 121' 1640 670 Surface deployment sleeve on to 2E-171-2 8,802' 13,700' 5,922' 51967' 2W, 4.7#, L-80, ST -L slotted/blank 3,473' 3520 2020 Production 7" liner; deployment sleeve on to Existing Casing(Liner Information Category OD Weigh t Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 121' Surface 121' 1640 670 Surface 9-5/8" 36 J-55 BTC Surface 4,481' Surface 3,473' 3520 2020 Production 7" 26 L-80 BTC -MOD Surface 9,196' Surface 6,380' 7240 5410 Tubing 3-1/2" 9.3 L-80 EUE 8RM Surface 8,862' Surface 6,115' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. ,/ Managed Pressure Drilling Practice • Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 -psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". %/In the 2E-17 laterals we will target a constant BHP of 11.8 EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 April 04, 2019 PTD ADDlication: 2E -17L1 & 2E -17L2 Pressure at the 2E-17 Window 8827' MD, 6087' TVD Using MPD V 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 2E-17 is equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sands to the northwest and southeast of 2E-17. The laterals will increase C -sand resource recovery and throughput. A recent rig workover installed tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge in the tandem wedge. CDR3-AC will mill a window in the tubing and casing at 8,827' MD and the 2E-171_1 lateral will be drilled to TD at 13,300' MD, targeting the C -sand to the northwest. It will be completed with 2-3/8" slotted liner from TD up to 8,822' MD. A second inner wedge will be run and set on rig to facilitate a window for the 2E -17L2 lateral. CDR3-AC will mill a second window at 8,807' MD and the 2E -17L2 lateral will be drilled to a TD of 13,700' MD targeting the C -sand to the southeast. It will be completed with 2-3/8" slotted/blank liner from TD up into the 3-1/2" tubing at 8,802' MD with a deployment sleeve. Pre -CTD Work 1. RU Slick -line: Drift tubing, install GLV design, and set X -lock. 2. RU E -line: Set inner wedge. 3. Prep site for Nabors CDR3-AC. Page 4 of 6 April 04, 2019 Pumps On 1.8 bpm) Pumps Off Formation Pressure 8.0 2532 psi 2532 psi Mud Hydrostatic 8.6 2722 psi 2722 psi Annular friction i.e. ECD, 0.080psi/ft) 706 psi 0 psi Mud + ECD Combined no chokepressure) 3428 psi overbalanced -896psi) 2722 psi overbalanced -190psi) Target BHP at Window 11.8 3735 psi 3735 psi ✓ Choke Pressure Required to Maintain Target BHP 307 psi 1013 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 2E-17 is equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sands to the northwest and southeast of 2E-17. The laterals will increase C -sand resource recovery and throughput. A recent rig workover installed tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge in the tandem wedge. CDR3-AC will mill a window in the tubing and casing at 8,827' MD and the 2E-171_1 lateral will be drilled to TD at 13,300' MD, targeting the C -sand to the northwest. It will be completed with 2-3/8" slotted liner from TD up to 8,822' MD. A second inner wedge will be run and set on rig to facilitate a window for the 2E -17L2 lateral. CDR3-AC will mill a second window at 8,807' MD and the 2E -17L2 lateral will be drilled to a TD of 13,700' MD targeting the C -sand to the southeast. It will be completed with 2-3/8" slotted/blank liner from TD up into the 3-1/2" tubing at 8,802' MD with a deployment sleeve. Pre -CTD Work 1. RU Slick -line: Drift tubing, install GLV design, and set X -lock. 2. RU E -line: Set inner wedge. 3. Prep site for Nabors CDR3-AC. Page 4 of 6 April 04, 2019 PTD Application: 2E -17L1 & 2E -17L2 Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPS, test. 2. 2E-171-1 Lateral (C4 sand -Northwest) a. Mill 2.80" window at 8,827' MD. b. Drill 3" bi-center lateral to TD of 13,300' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 8,822' MD. 3. 2E-171_2 Lateral (C4 sand - Southeast) a. Set X -lock and inner wedge. b. Mill 2.80" window at 8,807' MD. c. Drill 3" bi-center lateral to TD of 13,700' MD. d. Run 2%" slotted/blank liner with deployment sleeve from TD up to 8,802' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. - Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the BHA is lowered in place via slick -line. - When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed set of ball valve and check valve isolate reservoir pressure internal to the BHA. Slips on the deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. - The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - 2E-17 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. - While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. Page 5 of 6 April 04, 2019 PTD Application: 2E-171-1 8,2E -17L2 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2E-171-1 11,560' 2E-171-2 8,435' Distance to Nearest Well within Pool Lateral Name Distance Well 2E -17L1 1,354' 2E-061-1 2E -17L2 1,573' 11--231-1-02 16. Attachments Attachment 1: Directional Plans for 2E-171-1 and 2E -17L2 laterals. Attachment 2: Current Well Schematic for 2E-17. Attachment 3: Proposed Well Schematic for 2E -17L1, and 2E -17L2 laterals. Page 6 of 6 April 04, 2019 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 2E Pad 2E-17 2E-171-1 Plan: 2E-17L1_wp03 Standard Planning Report 03 April, 2019 BT�a GHES GE company ConocoPhillips Database: OAKEDMPI Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 2E Pad Well: 2E-17 Wellbore: 2E -17L1 Design: 2E-17L1_wP03 ConocoPhillips Planning Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2E-17 Mean Sea Level 2E-17 @ 146.00usft (2E-17) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor BAF�UGHES aGEmmpany Site Kupawk 2E Pad Wellbore 2E-171-1 Site Position: Northing: 5,944,247.48 usft Latitude: 70° 15'31.481 N From: Map Easting: 529,971.75 usft Longitude: 149' 45'27.897 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.23 ° Well 2E-17 Well Position -NI-S +E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: 5,944,284.83 usft Latitude: 70° 15'31.841g N 529,971.26 usft Longitude: 149° 45'27.90W W usft Ground Level: 0.00 Usti Declination Dip Angle (') n 16.49 80.81 Version: Phase: PLAN Vertical Sector: Depth From (TVD) +N/ -S (usft) (usft) 0.00 0.00 Tie On Depth: +E/ -W (usft) 0,00 Field Strength (nT) 57,405 J 8,806.20 Direction 9 J 300.00 4/32019 12: 06: 19PM Page 2 COMPASS 5000.14 Build 85D Wellbore 2E-171-1 Magnetics Model Name Sample Date BGGM2018 7/1/2019 Design 2E-17L1_wp03 Audit Notes: 5,944,284.83 usft Latitude: 70° 15'31.841g N 529,971.26 usft Longitude: 149° 45'27.90W W usft Ground Level: 0.00 Usti Declination Dip Angle (') n 16.49 80.81 Version: Phase: PLAN Vertical Sector: Depth From (TVD) +N/ -S (usft) (usft) 0.00 0.00 Tie On Depth: +E/ -W (usft) 0,00 Field Strength (nT) 57,405 J 8,806.20 Direction 9 J 300.00 4/32019 12: 06: 19PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Planning Report BAF�UGHES aGEmmpany Database: OAKEDMP1 Local Co-ordinate Reference: Well 2E-17 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-17 @ 146.00usft (2E-17) Site: Kuparuk 2E Pad North Reference: True Well: 2E-17 Survey Calculation Method: Minimum Curvature Wellborn: 2E-1711 Azimuth System Design: 2E-17L1_wp03 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System -NIS +E1 -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100usft) (°/100usft) (°/100usft) (°) Target 8,806.20 37.38 143.32 5,924.72 .4,659.89 3,414.62 0.00 0.00 0.00 0.00 8,827.00 37.40 143.10 5,941.24 .4,670.01 3,422.19 0.65 0.10 -1.06 -81.57 8,852.00 41.76 144.85 5,960.51 -4,682.89 3,431.54 18.00 17.44 6.99 15.00 8,961.39 90.00 156.15 6,004.02 -4,768.00 3,477.49 45.00 44.10 10.33 15.00 9,120.00 99.47 227.26 5,988.97 -4,912.86 3,448.22 45.00 5.97 44.83 80.00 9,220.00 89.73 271.40 5,980.54 -4,946.88 3,357.29 45.00 -9.74 44.14 100.00 9,295.00 89.77 305.15 5,980.88 -4,923.71 3,287.10 45.00 0.06 45.00 90.00 9,525.00 95.22 320.32 5,970.79 4,768.35 3,118.83 7.00 2.37 6.60 70.00 9,615.00 98.35 325.83 5,960.16 4,696.96 3,065.15 7.00 3.47 6.12 60.00 9,715.00 97.67 332.86 5,946.20 -4,611.82 3,014.70 7.00 -0.67 7.04 95.00 9,900.00 91.09 344.06 5,932.02 -4,440.59 2,947.20 7.00 -3.56 6.05 120.00 10,050.00 91.08 333.55 5,929.17 -4,300.95 2,893.05 7.00 -0.01 -7.00 270.00 10,175.00 89.55 324.94 5,928.49 4,193.64 2,829.20 7.00 -1.22 -6.89 260.00 10,350.00 84.61 313.71 5,937.43 4,061.32 2,715.53 7.00 -2.82 -6.42 245.00 10,635.00 89.98 332.95 5,951.02 -3,834.06 2,546.48 7.00 1.88 6.75 75.00 11,045.00 69.98 304.25 5,951.18 -3,529.70 2,278.19 7.00 0.00 -7.00 270.00 11,295.00 91.48 321.69 5,947.97 -3,359.97 2,095.99 7.00 0.60 6.97 85.00 11,595.00 88.88 300.85 5,947.00 -3,163.19 1,871.77 7.00 -0.87 -6.95 263.00 11,845.00 87.43 283.40 5,955.11 -3,069.43 1,641.21 7.00 -0.58 -6.98 265.00 12,195.00 88.49 307.90 5,967.75 -2,919.16 1,328.32 7.00 0.30 7.00 88.00 12,495.00 91.45 287.10 5,967.90 -2,781.42 1,063.70 7.00 0.99 -6.93 278.00 12,795.00 91.35 308.11 5,960.49 -2,643.22 799.42 7.00 -0.03 7.00 90.00 13,070.00 91.28 288.85 5,954.12 -2,512.74 558.90 7.00 -0.03 -7.00 270.00 13,300.00 91.23 304.96 5,949.06 -2,409.02 354.52 7.00 -0.02 7.00 90.00 4/32019 12:06.19PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips R ConocoPhillips Planning Report B F UGHES aGEcompany Database: OAKEDMPI Local Co-ordinate Reference: Well 2E-17 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-17 @ 146.00usft (2E-17) Site: Kuparuk 2E Pad North Reference: True Well: 2E-17 Survey Calculation Method: Minimum Curvature Wellborn: 2E-171-1 Design: 2E-17L1_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth inclination Azimuth System +N/ -S +E! -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 8,806.20 37.38 143.32 5,924.72 -4,659.89 3,414.62 -5287.10 0.00 0.00 5,939.639.02 533404.06 TIP 8,827.00 37.40 143.10 5,941.24 -4,670.01 3,422.19 -5,298.71 0.65 -81.57 5,939,628.94 533,411.66 KOP 8,852.00 41.76 144.85 5,960.51 -4,682.89 3,431.54 -5,313.25 18.00 15.00 5,939,616.09 533,421.07 End 18 dis, Start 45 dis 8,900.00 62.82 151.00 5,989.72 -4,715.02 3,451.34 -5,346.45 45.00 15.00 5,939,584.05 533,440.99 8,961.39 90.00 156.15 6,004.02 4,768.00 3,477.49 -5,395.60 45.00 11.17 5,939,531.18 533,467.36 4 9,000.00 92.97 173.28 6,003.01 4,805.09 3,487.64 5,422.93 45.00 80.00 5,939,494.13 533,477.64 9,100.00 98.85 218.16 5,992.16 4,898.37 3,461.60 -5,447.02 45.00 80.45 5,939,400.76 533,451.98 9,120.00 99.47 227.26 5,988.97 4,912.86 3,448.22 -5,442.68 45.00 85.33 5,939,386.22 533,438.66 5 9,200.00 91.86 262.65 5,980.82 4,945.85 3,377.25 -5,397.70 45.00 100.00 5,939,352.95 533,367.82 9,220.00 89.73 271.40 5,980.54 4,946.88 3,357.29 -5,380.94 45.00 103.62 5,939,351.84 533,347.88 6 9,295.00 89.77 305A5 5,980.88 4,923.71 3,287.10 -5,308.57 45.00 90.00 5,939,374.73 533,277.60 End 46 dis, Start 7 dis 9,300.00 89.89 305.47 5,980.89 4,920.82 3,283.02 -5,303.59 7.00 70.00 5,939,377.60 533,273.51 9,400.00 92.28 312.06 5,978.99 4,858.26 3,205.11 -5,204.84 7.00 70.00 5,939,439.85 533,195.36 9,500.00 94.64 318.66 5,972.94 4,787.29 3,135.01 -5,108.64 7.00 70.12 5,939,510.53 533,124.98 9,525.00 95.22 320.32 5,970.79 4,768.35 3,118.83 -5,085.16 7.00 70.52 5,939,529.40 533,108.73 8 9,600.00 97.83 324.90 5,962.27 4,709.17 3,073.59 -5,016.40 7.00 60.00 5,939,588.39 533,063.26 9,615.00 98.35 325.83 5,960.16 4,696.96 3,065.15 -5,002.98 7.00 60.52 5,939,600.57 533,054.77 9 9,700.00 97.78 331.81 5,948.22 4,624.99 3,021.60 4,929.28 7.00 95.00 5,939,672.36 533,010.94 9,715.00 97.67 332.86 5,946.20 4,611.82 3,014.70 4,916.72 7.00 95.84 5,939,685.50 533,003.99 10 9,800.00 94.67 338.03 5,937.06 4,534.99 2,979.61 4,847.91 7.00 120.00 5,939,762.18 532,968.60 9,900.00 91.09 344.06 5,932.02 4,440.59 2,947.20 4,772.64 7.00 120.56 5,939,856.45 532,935.81 11 10,000.00 91.09 337.06 5,930.12 4,346.37 2,913.94 4,696.72 7.00 -90.00 5,939,950.52 532,902.18 10,050.00 91.08 333.55 5,929.17 4,300.95 2,893.05 4,655.93 7.00 -90.13 5,939,995.85 532,881.12 12 10,100.00 90.47 330.11 5,928.50 4,256.89 2,869.45 4,613.46 7.00 -100.00 5,940,039.82 532,857.35 10,175.00 89.55 324.94 5,928.49 4,193.64 2,829.20 4,546.98 7.00 -100.05 5,940,102.90 532,816.84 13 10,200.00 88.84 323.34 5,928.84 4,173,38 2,814.55 4,524.16 7.00 -114.00 5,940,123.10 532,802.12 10,300.00 86.01 316.93 5,933.34 4,096.75 2,750.57 4,430.43 7.00 -113.98 5,940,199.47 532,737.83 10,350.00 84.61 313.71 5,937.43 4,061.32 2,715.53 4,382.38 7.00 -113.69 5,940,234.75 532,702.66 14 10,400.00 85.52 317.10 5,941.73 4,025.85 2,680.57 4,334.36 7.00 75.00 5,940,270.08 532,667.56 10,500.00 87.40 323.86 5,947.92 -3,948.90 2,617.10 4,240.92 7.00 74.71 5,940,346.77 532,603.79 10,600.00 89.30 330.60 5,950.80 -3,864.90 2,563.03 4,152.10 7.00 74.29 5,940,430.54 532,549.39 10,635.00 89.98 332.95 5,951.02 -3,834.06 2,546.48 4,122.35 7.00 74.10 5,940,461.31 532,532.72 15 10,700.00 89.98 328.40 5,951.05 -3,777.41 2,514.66 4,066.46 7.00 -90.00 5,940,517.83 532,500.68 10,800 o 89.98 321.40 5,951.09 -3,695.64 2,457.20 -3,975.82 7.00 -90.00 5,940,599.37 532,442.90 10,900.00 89.98 314.40 5,951.13 -3,621.48 2,390.20 -3,880.72 7.00 -90.00 5,940,673.25 532,375.62 11,000.00 89.98 307.40 5,951.16 -3,556.04 2,314.67 -3,782.58 7.00 -89.99 5,940,738.38 532,299.83 11045.00 89.98 304.25 5,951.18 -3,529.70 2,278.19 -3,737.82 7.00 -89.99 5,940,764.57 532263.25 4/32019 12:06:19PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Planning Report �F�UGHES aGEcompany Database: OAKEDMPI 2,092.88 Company: _ConocoPhillips Export Company Project: Kuparuk River Unit 315.0E Site: Kupamk 2E Pad 321.69 Well: 2E-17 -97.01 Wellbore: 2E-171-1 321.34 Design: 2E-17L1_wp03 314.40 11,500.00 89.71 307.4' Planned Survey 88.88 300.85 Measured -3,163.19 TVD Below Depth Inclination Azimuth System (usft) (e) (e) (usft) 16 -3,356.06 2,092.88 11,100.00 90.31 308.09 11,200.00 90.92 315.0E 11,295.00 91.48 321.69 17 7.00 -97.01 11,300.00 91.44 321.34 11,400.00 90.58 314.40 11,500.00 89.71 307.4' 11,595.00 88.88 300.85 18 -3,163.19 1,871.77 11,600.00 88.85 300.50 11,700.00 88.25 293.53 11,800.00 87.68 286.55 11,845.00 87.43 283.40 19 5,941,131.96 531,851.11 11,900.00 87.57 287.25 12,000.00 87.85 294.25 12,100.00 88.17 301.25 12,195.00 88.49 307.90 20 7.00 -94.82 12,200.00 88.54 307.55 12,300.00 89.52 300.62 12,400.00 90.51 293.69 12,495.00 91.45 287.10 21 -3,054.91 1,588.23 12,500.00 91.45 287.45 12,600.00 91.44 294.45 12,700.00 91.40 301.46 12,795.00 91.35 308.11 22 5,941,271.58 531,477.97 12,800.00 91.35 307.76 12,900.00 91.34 300.76 13,000.00 91.31 293.75 13,070.00 91.28 288.85 23 7.00 87.31 13,100.00 91.28 290.95 13,200.00 91.26 297.96 13,300.00 91.23 304.96 Planned TD at 13300.00 531,307.08 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2E-17 Mean Sea Level 2E-17 @ 146.00usft (2E-1 7) True Minimum Curvature Vertical Dogleg Toolface Map Map -NIS +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°1100usft) 11) (usft) (usft) 5951.04 -3,497.25 2,233.80 -3,683.15 7.00 85.00 5,940,796.85 532,218.74 5,949.96 -3,430.93 2,159.04 -3,585.25 7.00 85.01 5,940,862.86 532,143.73 5,947.97 -3,359.97 2,095.99 -3,495.17 7.00 85.09 5,940,933.56 532,080.40 5,947.84 -3,356.06 2,092.88 -3,490.52 7.00 -97.00 5,941,648.13 5,940,937.46 532,077.27 5,946.08 -3,281.95 2,025.85 -3,395.42 7.00 -97.01 530,694.36 5,941,011.29 532,009.96 5,945.83 -3,216.49 1,950.34 -3,297.29 7.00 -97.13 5,954.12 5,941,076.45 531,934.19 5,947.00 -3,163.19 1,871.77 -3,202.60 7.00 -97.15 -2,502.53 5,941,129.43 531,855.42 5,947.10 -3,160.64 1,867.47 -3,197.60 7.00 -95.00 439.75 5,941,131.96 531,851.11 5,949.63 -3,115.26 1,778.47 -3,097.83 7.00 -94.99 -1,511.53 5,941,176.98 531,761.94 5,953.19 -3,081.04 1,684.64 -2,999.46 7.00 -94.82 5,941,210.82 531,667.98 5,955.11 -3,069.43 1,641.21 -2,956.05 7.00 -94.57 5,941,222.26 531,624.51 5,957.50 -3,054.91 1,588.23 -2,902.90 7.00 88.00 5,941,236.57 531,571.48 5,961.50 -3,019.52 1,494.85 -2,804.34 7.00 87.83 5,941,271.58 531,477.97 5,964.98 -2,973.01 1,406.46 -2,704.54 7.00 87.55 5,941,317.73 531,389.40 5,967.75 -2,919.16 1,328.32 -2,609.94 7.00 87.31 5,941,371.27 531,311.05 5,967.88 -2,916.10 1,324.36 -2,604.98 7.00 -82.00 5,941,374.31 531,307.08 5,969.57 -2,860.11 1,241.60 -2,505.31 7.00 -81.99 5,941,429.97 531,224.11 5,969.53 -2,814.50 1,152.68 -2,405.50 7.00 -81.87 5,941,475.22 531,135.01 5,967.90 -2,781.42 1,063.70 -2,311.90 7.00 -81.88 5,941,507.94 531,045.91 5,967.78 -2,779.93 1,058.92 -2,307.02 7.00 90.00 5,941,509.41 531,041.13 5,965.26 -2,744.20 965.62 -2,208.36 7.00 90.01 5,941,544.76 530,947.70 5,962.77 -2,697.37 877.37 -2,108.51 7.00 90.19 5,941,591.24 530,859.27 5,960.49 -2,643.22 799.42 -2,013.92 7.00 90.36 5,941,645.07 530,781.11 5,960.37 -2,640.15 795.47 -2,008.97 7.00 -90.00 5,941,648.13 530,777.15 5,958.01 -2,583.91 712.90 -1,909.34 7.00 -90.01 5,941,704.03 530,694.36 5,955.70 -2,538.15 624.08 -1,809.54 7.00 -90.17 5,941,749.43 530,605.37 5,954.12 -2,512.74 558.90 -1,740.39 7.00 -90.34 5,941,774.59 530,540.10 5,953.45 -2,502.53 530.70 -1,710.86 7.00 90.00 5,941,784.68 530,511.86 5,951.23 -2,461.16 439.75 -1,611.41 7.00 90.05 5,941,825.68 530,420.75 5,949.06 -2,409.02 354.52 -1,511.53 7.00 90.20 5,941,877.47 530,335.32 rasing Points Measured Vertical Cuing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (In) 13,300.00 5,949.06 2318" 2.375 3.000 4/3/2019 12:06: 19PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Bgl(ER 0) ConocoPhillips Planning Report UGHES a GE.rnpany Database: OAKEDMPI Local Co-ordinate Reference: Well 2E-17 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-17 @ 146.00usft(2E-17) Site: Kuparuk 2E Pad North Reference: True Well: 2E-17 Survey Calculation Method: Minimum Curvature Wellbore: 2E-1711 3,448.22 5,980.54 Design: 2E-17L1_wp03 5,980.88 -4,923.71 Formations Measured Vertical Depth Depth (usft) (usft) Name 8,945.16 6,003.00 Formation 2 Plan Annotations Measured Depth (usft) 8,806.20 8,827.00 8,852.00 8,961.39 9,120.00 9,220.00 9,295.00 9,525.00 9,615.00 9,715.00 9,900.00 10,050.00 10,175.00 10,350.00 10,635.00 11,045.00 11,295.00 11,595.00 11,845.00 12,195.00 12,495.00 12,795.00 13,070.00 13,300.00 Vertical Local Coordinates Depth -NI-S +EI -W (usft) (usft) (usft) 5,924.72 -4,659.89 3,414.62 5,941.24 -4,670.01 3,422.19 5,960.51 -4,682.89 3,431.54 6,004.02 4,768.00 3,477.49 5,988.97 4,912.86 3,448.22 5,980.54 -4,946.88 3,357.29 5,980.88 -4,923.71 3,287.10 5,970.79 -4,768.35 3,118.83 5,960.16 -4,696.96 3,065.15 5,946.20 -4,611.82 3,014.70 5,932.02 4,440.59 2,947.20 5,929.17 4,300.95 2,893.05 5,928.49 -4,193.64 2,829.20 5,937.43 4,061.32 2,715.53 5,951.02 -3,834.06 2,546.48 5,951.18 -3,529.70 2,278.19 5,947.97 -3,359.97 2,095.99 5,947.00 -3,163.19 1,871.77 5,955.11 -3,069.43 1,641.21 5,967.75 -2,919.16 1,328.32 5,967.90 -2,781.42 1,063.70 5,960.49 -2,643.22 799.42 5,954.12 -2,512.74 558.90 5,949.06 -2,409.02 354.52 Dip Dip Direction Lithology 0.00 Comment TIP KOP End 18 dls, Start 45 dls 4 5 6 End 45 dls, Start 7 dls 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 Planned TO at 13300.00 413/2019 12:06.19PM Page 6 COMPASS 5000. 14 Build 85D �. ConocoPhillips BAT ConocoPhillips Anticollision Report �j IGHES a GEcompany Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 2E Pad Site Error: 0.00 usft Reference Well: 2E-17 Well Error: 0.00 usft Reference Wellbore 2E-171-1 Reference Design: 2E-17L1_wp03 Reference 2E -17L7 wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Filter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: Depth Range: 8,806.20 to 13,300.00usft Scan Method: Results Limited by: Maximum center -center distance of 1,515.40 usft Error Surface: Warning Levels Evaluated at: 2.79 Sigma Casing Mention Well 2E-17 2E-17 @ 146.00usft(2E-17) 2E-17 @ 146.00usft (2E-17) True Minimum Curvature 2.00 sigma OAKEDMPI Offset Datum ISCWSA Tray. Cylinder North Combined Pedal Curve Added to Error Values Survey Tool Program Date 4/2/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 150.00 8,806.20 2E-17 (2E-17) GCT -MS Schlumberger GCT multishot 8,806.20 13,300.00 2E-17L1_wp03(2E-171-1) MWD MWD - Standard Summary Site Name Offset Well - Wellbore - Design Kupamk 2E Pad 2E-02 - 2E-02 - 2E-02 2E-02 - 2E-02 - 2E-02 2E-03 - 2E-03 - 2E-03 2E-03 - 2E-03 - 2E-03 2E-03 - 2E-03 - 2E-03 2E-04 - 2E-04 - 2E-04 2E-04 - 2E-04 - 2E-04 2E-04 - 2E-04 - 2E-04 2E-05 - 2E-05 - 2E-05 2E-05 - 2E-05 - 2E-05 2E-05 - 2E-05 - 2E-05 2E -06.2E-06 - 2E-06 2E-06 - 2E-06 - 2E-06 2E-06 - 2E-0611 - 2E-061.1 2E-06 - 2E-061-1-01 - 2E-0611-01 2E-06 - 2E-0611-01 - 2E-061.1-01 2E-06 - 2E -06L1 PB1 - 2E -06L1 PB1 2E -06-2E-0611 P81 -2E-061.1 PB1 2E-07 - 2E-07 - 2E-07 2E-07 - 2E-07 - 2E-07 2E-08 - 2E-08 - 2E-08 2E-08 - 2E-08 - 2E-08 2E-08 - 2E-08 - 2E-08 2E-11 -2E-11 -2E-11 2E-11 - 2E-11 - 2E-11 2E-11 - 2E-11 - 2E-11 2E-17 - 2E-17 - 2E-17 2E-17-2E-171-2-2E-17L2_wp02 Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) (usft) (usft) (usft) 10, 568.74 13, 417.00 1,354.33 1,128.86 9,840.85 8,350.00 449.27 447.72 9,106.20 9,450.00 415.28 410.90 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 6.007 CC, ES, SF Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 290.048 CC, ES, SF 94.805 CC, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4//2019 1:5&45PM Page 2 COMPASS 5000.14 Build 85D MOX 8 r Q Q r_ 25 S o a o $ o $ & 4 (m/)Jsn OOS) (+)9uoty(-)y[lios N 8000 )500 )000 5500 SLP)• i500 G i00( 150( O 00C 50C A' 50( rN'' 00( G N 50( 3 000 500 000 00 500 �ACd 'm�QHYW@mfpW---r-----r-r-- J N 0 - O O'C a O�NMQmmAmOIO�NM A NNNND. v U O m O m@ AfO m N@ M m m m N A O IM@ O N O M NN ANtO tG m1!)r-OAmCP CIMMm�IOO Ca C�TMm hAmty Y][V �O >mgg..g fAAV [mMV NN�MIA�Nm@NoNmua�]Oo(Oa mNmI@mG M��-M.O-@OA��m '47"17 '17`V7V V'YY4Y? 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LLI 4950 -5100 ..4 -5250 .N` -54W W ZO L711L -3Z ;' I 1]L1 3[ -5550 -5700C c J -5850 W -6000 6150 -6300 (ui/)Jsn OS[) 43da4 [Bo[pap an{y g I i PXE ys'= m �a. 8 0 c 0 - - - 8 x - _ 3 Ea l a � o 4 0 0 i (u!/Ssn OOL) (+)44joN/(-)91nog tLw k ( ( ( \ Well KRU XX -XX Quick Test Sub to Oti Top of 7" Otis Distances from top of Excluding quick -test •, Top of Annular CL Annular Bottom Annular Flang CL Blind/Shears CL 2" Combrs CL 2-3/8" Combrs CL 2" Combfs CL of Top Su Top of Swab CL Swab 1 Flow Tee CL SSV CL Master LDS Ground L Nabors CDR3-AC: 4 -Ram BOP Configuration 2" Date April 24, 2019 Coiled Tubing and 2-3/8" BHA Tree Size F a 118 re Loepp, Victoria T (DOA) From: Starck, Kai <Kai.Starck@conocophillips.com> Sent: Thursday, April 25, 2019 9:57 AM To: Loepp, Victoria T (DOA) Subject: Re: [EXTERNAL]4 Ram BOP Stack Configuration for Nabors CDR3-AC Thank you. Kai Starck CTD Director ConocoPhillips Alaska 907-240-0691 On Apr 25, 2019, at 9:37 AM, Loepp, Victoria T (DOA) <victoria.loeppgalaska.aov> wrote: Gary, Kai, We have reviewed the 4 ram BOP configuration proposed for Nabors CDR3-AC during pressure deployment and undeployment of the BHA and approve the use of this configuration. For wells proposed to be drilled with this 4 ram BOP configuration, include a BOP schematic with the submitted PTDs until further notice. Additional BOP test reporting details may be required and will be covered in a separate email. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppi Loepp, Victoria T (DOA) From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Wednesday, April 24, 2019 2:40 PM To: Loepp, Victoria T (DOA) Subject: KRU 2E-17 4 -Ram BOP Configuration Follow Up Flag: Follow up Flag Status: Flagged Good afternoon Victoria, As per Kai's requested I hand delivered 2 -each Nabors CDR3-AC: 4 -Ram BOP Configuration schematics to the AOGCC this afternoon to be included in the 2E-17 PTD package for the 2E -17L1 lateral and 2E -17L2 lateral. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E. Herri n ei Loepp, Victoria T (DOA) From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Monday, April 22, 2019 3:11 PM To: Loepp, Victoria T (DOA) Subject: KRU 2E-17 (PTD #193-174) Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, We could be moving to KRU 2E-17 as early as Thursday, April 25. The 2E-17 PTD package was submitted back on April 05, 2019 and ConocoPhillips would like to move forward on getting the permits to drill the dual lateral out of KRU 2E-17. Could you let us know the progress on your review of the reconfiguration of the BOP stack to be used on CDR3. We would like to make the stack changes during the rig move to 2E-17. If you have any further question or concerns on this reconfiguration please let us know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO -664 Keith.E. f lerring(&conoco0hil I ips.com ConocoPhillips Alaska Loepp, Victoria T (DOA) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Monday, March 18, 2019 4:29 PM To: Regg, James B (DOA); Loepp, Victoria T (DOA) Cc: Starck, Kai; Hobbs, Greg S Subject: RE: [EXTERNAL]RE: Meeting to Discuss BOPE Configuration on Nabors CDR3-AC Attachments: BOP Config CDR3 4 -ram PROPOSED.pdf; BOP Config CDR -3 6-ram.pdf; CDR3 4 -ram mud line drawing.pdf; Proposal to Switch CDR3 to 4 -Ram Stack.docx Follow Up Flag: Follow up Flag Status: Flagged Categories: Technical Review Jim, Victoria — Attached are the drawings that we had intended to bring: • Current 6 -ram configuration for both 2 and 2 and larger coiled tubing • Proposed 4 -ram configuration for both 2 and 2 and larger coiled tubing • Proposed mud -line drawing for a 4 -ram BOP stack Ive also included a write-up that gives some more detail about the proposal. III look forward to speaking with you next Wednesday. -Gary From: Regg, James B (DOA) <jim.regg@alaska.gov> Sent: Monday, March 18, 2019 3:48 PM To: Eller, J Gary <J.Gary.Eller@conocophi Ili ps.com>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Starck, Kai <Kai.Starck@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]RE: Meeting to Discuss BOPE Configuration on Nabors CDR3-AC It would be a more productive if you could provide the information so we could review it before the meeting. Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W.711 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.regIzPalaska.eov. From: Eller, J Gary <J.Gary.EllerCnlconocophillips.com> Sent: Monday, March 18, 2019 3:01 PM To: Regg, James B (DOA) <lim.re¢Q@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Starck, Kai <Kai.StarckCdconocophillips.com>; Hobbs, Greg S<Greg.S.Hobbst@conocophill ips.com> Subject: RE: [EXTERNAL]RE: Meeting to Discuss BOPE Configuration on Nabors CDR3-AC Jim, Victoria — III set up a meeting for Wednesday, 3/27 at 3 p.m. We have time to change if that turns out to be bad for Victoria. Thanks much! -Gary From: Regg, James B (DOA) <iim.reee@alaska.eov> Sent: Monday, March 18, 2019 2:45 PM To: Eller, J Gary <J.Garv.Eller@conocophillips.com>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Hobbs, Greg S <Gree.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]RE: Meeting to Discuss BOPE Configuration on Nabors CDR3-AC My schedule is wide open (as of right now) during those dates. Jim Regg Supervisor, Inspections AOGCC 333 W.7^ 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.reeg analaska.eov. From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Monday, March 18, 2019 2:26 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov>; Regg, James B (DOA) <iim.reee@alaska.eov> Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Hobbs, Greg S <Gree.S.Hobbs@conocophillips.com> Subject: Meeting to Discuss BOPE Configuration on Nabors CDR3-AC Victoria, Jim — Greetings! ConocoPhillips would like to meet with the AOGCC to propose a change to the standard BOPE configuration at Nabors CDR3-AC, going from a 6 -ram to a 4 -ram stack. The 6 -ram stack originated in 2009 as a way to improve deployment and undeployment of coiled tubing drilling BHAs under wellhead pressure, but ConocoPhillips believes that these operations can be safely conducted using just four rams. The proposed 4 -ram stack satisfies all secondary well control requirements of 20 AAC 25.036 without exception. Is there sometime March 26-28 that youd be available to meet? Kai Starck and I intend to bring schematic diagrams of both the existing 6 -ram and the proposed 4 -ram configuration to better explain the proposal. I would anticipate it being a 30 -minute discussion. J. Gary Eller Wells Advisor ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 ConocoPhillips Evaluation of Changing Nabors CDR3-AC from a 6 -Ram to a 4 - Ram BOP Stack 1. Slimhole CTD Ops (i.e. 2" a -coil, 2W OD BHA, 2'/2' slotted liner) a. The 4 -ram BOP stack satisfies Alaska regulation and COP policy requirements (top down) i. 1 — annular preventer ii. 1 — blind/shears iii. 1 — 2" pipe/slip ram to fit the coiled tubing iv. Mud cross with double kill -line valves and choke -line valves v. 1 - 2W pipe/slip ram to fit both the drilling BHA and the completion liner. AUTO -LOCK RAMS. vi. 1 — 2" pipe/slip ram to fit the coiled tubing. AUTO -LOCK RAMS. b. Eliminates one blind/shear ram c. Eliminates one 2W pipe/slip ram i. Purpose of this ram has been to facilitate BHA pressure deployment & undeployment ii. The annular preventer will serve as a secondary barrier during BHA pressure deployment 2. Bighole CTD Ops (i.e. 2%"e -coil, 3" OD BHA, 3'/i' & 2'/" completion liner) a. The 4 -ram BOP stack satisfies Alaska regulation and COP policy requirements (top down) i. 1 —annular preventer ii. 1 — blind/shears iii. 1 — 2'/2' pipe/slip ram to fit the coiled tubing iv. Mud cross with double kill -line valves and choke -line valves v. 1 - 3" pipe/slip ram to fit the drilling BHA AUTO -LOCK RAMS vi. 1 — VBR (2%%3'/2') AUTO -LOCK RAMS 1. Fits all sizes of completion liners plus the drilling BHA and coiled tubing 2. Does not have slips b. Eliminates one blind/shear ram c. Eliminates one 2%" pipe/slip ram i. Annular preventer and VBRs serve as redundant CT pressure barriers, but there is no slip redundancy ii. Annular preventer and VBRs serve as redundant BHA pressure deployment barriers, but there is no slip redundancy d. Notes i. Even with the 6 -ram stack, we've always had just the single BHA deployment slip -ram with this size. This proposal does not change BHA deployment processes for this coil/completion size. ii. If larger coil than 2'/" OD is used, only difference is pipe/slip rams to match the coil OD 3. Other Notes a. The CTD team has reviewed this proposal thoroughly and we're confident that it satisfies industry, regulatory, and corporate standards for BOP configuration during all phases of Kuparuk MPD -CTD ops. b. Even though we're eliminating rams from the BOP stack, the analysis shows we're eliminating redundancy that is not now nor never has been truly necessary. c. Deployment of the slimhole BHA will now be done the same way the bighole BHA deployment has always been done: with a single slip -ram gripping the BHA. d. Testing of the slip rams performed without personnel in the line of fire i. BHA undeployment —After closing the BHA deployment rams, CT does a 5000 IV push/pull test to confirm the slips are holding. The push/pull test is Page 1 of 2 March 18, 2019 performed with the riser fully intact after confirming the ram locks are engaged. ii. BHA deployment — After closing the BHA deployment rams, slickline does a pull test above PU weight to confirm the slips are holding. The slickline pull test is performed inside the lubricator after confirming the ram locks are engaged. iii. Coiled tubing pipe recovery —Coil is pulled only slightly in tension (±5000 lbs) at surface when the slip -rams are engaged. Procedure then calls for a 5000 lbs push/pull test to confirm the slips are holding prior to cutting pipe at surface. Procedure also calls for confirming ram locks are engaged and confirming all pressures are bled prior to stripping off and installing dog collar, false bowl, and slips. Nabors CDR3-AC Kuparuk Managed Pressure, Coiled Tubing Drilling Standard BOP Configuration for 2" Coiled Tubing & `Slimhole' BHA Pump into Lubricator above BHA rams Kill Lubricator Riser I Blind / Shear I 2" Pipe / Slip (Coil) 2'/." Pipe / Slip (Deploy) 2'/." Pipe/ Slip (Deploy) I Blind / Shear I 1 2" Pipe / Slip (Coil) Wing Valves Swab Valves Tree Flow Cross Equalize Surface Safety Valve Master Valve I Choke Manifold K BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union Nabors CDR3-AC Kuparuk Managed Pressure, Coiled Tubing Drilling Standard BOP Configuration for 2%" Coiled Tubing & 'Bighole' BHA Pump into Lubricator above BHA rams Kill Lubricator Riser I Blind / Shear I 2/." Pipe/ Slip (Coil) 3" Pipe / Slip (Deploy) Variable rams (2%"-3%") I Blind / Shear I 1 2'/i" Pipe/ Slip (Coil) I Wing Valves Swab Valves Tree Flow Cross Equalize Surface Safety Valve Master Valve 1 Choke Manifold 2 BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union ( -- — — — —— — — — —--- ; ~ E m G!! + / 2 \I § i !; /)° �[.!}( m E I m »H� co | . m I ! -}_� } mE §m 2 e )kMRBEssP k } ! || k ! | H� 2 2 ! !0 _� ■ � � °�! ! �! !! z d EE g/ $` & ' - �( E «E|§!K §/ § ©®u 2 §»■m @ /§(/)() 2 2 k�n((( KE(kk ! \ §;2;2aat;s 10 § From: Davies, Stephen F (DOA) To: Boyer, David L (DOA) Cc: Loepo Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 2E-171-1 & L2 Date: Tuesday, April 9, 2019 10:45:36 AM Attachments: imaae001.Dna imaoe002.ona David, The latest H2S surveys for 2E -Pad wells are: Hz5 5u F o r -4l P) a+a- The values shown in red are the H2S measured values for those wells. (Source table stored on our server at: \\DoaAncOgcFDs02.soa.alaska.gov\shared\AOGCC\Wells\H2S\Kuparuk\GKA H2S State Report 20192019- 41.xI x_). Regulation 20 AAC 25.065(a) requires operators notify the AOGCC if 1-12S is encountered in amounts exceeding 20 ppm. Since H2S is known to occur in amounts greater than 20 ppm within Kuparuk reservoirs in the vicinity of 2E -Pad, I would require 112S measures for the well. Note that paragraph (c) of 20 AAC 25.065 requires H2S measures if the history of drilling in an area is insufficient to know whether or not H2S gas is present. Thanks, Steve D. From: Boyer, David L (DOA) Sent: Tuesday, April 9, 2019 10:31 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: FW: [EXTERNAL]KRU 2E-1711 & L2 Hi Steve, This pad is not on your list, probably because it is drilled less frequently. The 2E-02 well is the anomaly and is 2 miles away from the2E-17 candidate motherbore. Thanks, 2E-01 12/5/2018 75 2E-04 12/5/2018 35 2E-06 12/5/2018 20 2E-08 12/5/2018 s0 2E-11 12/5/2018 55 2E-15 12/5/2018 s0 2E-16 12/5/2018 50 Hz5 5u F o r -4l P) a+a- The values shown in red are the H2S measured values for those wells. (Source table stored on our server at: \\DoaAncOgcFDs02.soa.alaska.gov\shared\AOGCC\Wells\H2S\Kuparuk\GKA H2S State Report 20192019- 41.xI x_). Regulation 20 AAC 25.065(a) requires operators notify the AOGCC if 1-12S is encountered in amounts exceeding 20 ppm. Since H2S is known to occur in amounts greater than 20 ppm within Kuparuk reservoirs in the vicinity of 2E -Pad, I would require 112S measures for the well. Note that paragraph (c) of 20 AAC 25.065 requires H2S measures if the history of drilling in an area is insufficient to know whether or not H2S gas is present. Thanks, Steve D. From: Boyer, David L (DOA) Sent: Tuesday, April 9, 2019 10:31 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: FW: [EXTERNAL]KRU 2E-1711 & L2 Hi Steve, This pad is not on your list, probably because it is drilled less frequently. The 2E-02 well is the anomaly and is 2 miles away from the2E-17 candidate motherbore. Thanks, Dave From: Loepp, Victoria T (DOA) Sent: Tuesday, April 9, 2019 10:20 AM To: Boyer, David L (DOA) <david.boyer2(@alaska.eov> Subject: RE: [EXTERNAL]KRU 2E-1711 & L2 I believe so. You might check with Steve on what he suggests. From: Boyer, David L (DOA) Sent: Tuesday, April 9, 2019 10:13 AM To: Loepp, Victoria T (DOA) <victoria.loeopPalaska.eov> Subject: FW: [EXTERNAL]KRU 2E-1711 & L2 Hi Victoria, I assume that you will be reviewing this well. These 1-12S values are generally less than I am used to seeing in Kuparuk. Should we require 1-12S measures for this 2E Pad well? Thanks, Dave From: Herring, Keith E <Keith.E Herring(@conoco hiIIips.com> Sent: Tuesday, April 9, 2019 10:03 AM To: Boyer, David L (DOA) <david.boyer2 analaska aov> Cc: Ohlinger, James J <James.J.Ohlinger aPconocoohilli s� com> Subject: RE: [EXTERNAL]KRU 2E -17L1 & L2 Hi Dave, Please see the attached files and below is H2S data from 2E Pad. Well Date 1-125 2E-01 5 -Dec -18 75 2E-02 25 -Dec -14 120 2E-04 5 -Dec -18 35 2E-06 5 -Dec -18 20 2E-07 1 -Aug -94 45 2E-08 5 -Dec -18 50 2E-09 30 -Dec -00 10 2E-10 29 -Oct -14 80 2E-11 5 -Dec -18 55 2E-15 5 -Dec -18 50 2E-16 5 -Dec -18 50 ' #NIA #NIA Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keah. r.11erri n ¢GFconoconh i l l i ns.cnm ConocoPhiliips From: Boyer, David L (DOA) <david.boyer2 analaska.gov> Sent: Tuesday, April 9, 2019 9:44 AM To: Herring, Keith E <Keith E Herriny@conocophillips.com> Subject: [EXTERNAL]KRU 2E-171-1 & L2 Hi Keith, I just begin reviewing the PTD applications for KRU 2E17111 & L2 coil laterals. Do you have digital files of the surveys in ASCII or Excel format for loading into our Geogrphix database? Also, is there any 112S data available for 2E Pad? Due to the maturity of the waterflood, nearly all Kuparuk wells require H2S measures, but this pad was not on the list that Steve maintains. Thank you, Dave Boyer AOGCC TRANSMITTAL LETTER CHECKLIST WELL NAME: K Ry, 2., E- 1-:7-L 1 / PTD: � 19 - a _q!, f" ✓Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: KQ a V ,,t IC R l Velma POOL: K up a r u lc 1R i V o- 0 1 I Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. 19 3 — l �' API No. 50- OZ - aa!t! J 9 - 00 -_ao. V, (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50— from from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, V composite curves for well logs run must be submitted to the AOGCC within 90 da s after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST yield & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 _ PTD#: 2190540 Company CQNOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 2E-171-1 Program DEV Well bore seg DEV/PEND GeoArea 890 Unit 11160 On/Off Shore Qn Annular Disposal ❑ Administration 1 Permit fee attached_ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .... NA. Date Commissioner Date 2 Lease number appropriate- - - _ ..... _ _ _ _ _ _ Yes I 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 Jocated proper distance from other wells.. Yes 7 Sufficient acreage available in drilling unit. _ _ _ _ _ _ _ Yes 8 If deviated, is wellbore plat. included _ _ _ _ _ _ _ Yes _ _ _ Directional_ plan view included and wellbore cross-section _ 9 Operator only affected party.. _ _ _ _ _ Yes 10 Operator hasappropriate bond in force _ _ _ _ _ _ _ _ _ _ _ _ Yes ... 11 Permit, can be issued without conservation order_ _ _ _ _ Yes Appr Date 12 Permitcan be issued without administrative.approval _ _ _ _ _ _ Yes DLB 4/9/2019 13 Can permit be approved before 15 -day wail _ _ _ .. _ _ _ Yes . . 14 Well located within area andstrata authorized by Injection Order # (put 10# in comments) (For_ NA 15 All wells within 1/4 mile area of review identified (For service well only) _ _ _ _ . NA. 16 Pre -produced injector: duration of pre production less. than 3 months. (For service well only) . _ NA 17 Nonconven, gas conforms to AS31,05,03o(i.1.A),0.2.A-D) _ .. _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _________ 18 Conductor string_ provided .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA..... _ _ _ Conductor set in KRU 2E-17 ... Engineering 19 Surface casing_ protects all. known. USDWs _ _ _ _ _ _ _ _ _ . _ NA... _ Surface easing set in KRU 2E-17 _ 20 CMT. vol adequate to circulate on conductor & surf csg _ _ _ _ _ ..... NA. _ _ _ _ _ Surface casing set and fully. cemented 21 CMT vol adequate to tie-in Jong string to surf ceg. _ _ _ .. _ _ _ _ NA _ _ .... 22 CMT will cover all known productive horizons _ _ .. _ _ _ _ _ No _ .. _ _ _ _ Productive. interval will be completed with uncemented slotted liner 23 Casing designs adequate for C, T, B & permafrost _ .. _ Yes _ 24 Adequate tankage of reserve pit _ _ _ _ .. ...Yes _ _ _ _ _ . Rig has steel tanks; allwaste.lo approved disposal wells. 25 Jf a.re-drill, has.a 10403 for abandonment been approved . . . . . ........ NA _ . _ . - . 26 Adequate wellbore separation proposed.... _ _ _ _ .... _ _ _ _ _ Yes ..... _ _ Anti -collision analysis complete; no major risk failures 27 If diverter required, does It meet regulations _ _ _ _ _ _ _ _ .. NA Appr Date 28 Drilling fluid. program schematic & equip list adequate.. .... _ _ _ _ _ _ _ Yes _ _ Max formation pressure is. 3412 psig(10.7 ppg EMW ); will drill w/ 8.6_ppg EMW and. maintain overbal w/ MPD VTL 4/25/2019 29 BQPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ .. Yes _ _ _ 4 ram BOP stack has been approved to use instead of the 6 ram BOP stack 30 BOPE_press rating appropriate: test W(put psig in comments)____ _ _ _ _ _ _ _ _ _ _ _ _ Yes .... _ MPSP is 2804 psig; will test BOPS to 3800 psig 31 Choke.manifold complies WAR RP -53 (May 84). _ _ .. _ _ _ Yes 32 Work will occur without operation shutdown..... _ _ _ _ _ ... . . . . . ..... Yes 33 Is presence of H2S gas. probable _ _ _ _ _ _ _ _ _ _ _ _ _ .. Yes 1-12S measures required_ 34 Mechanical condition of wells within AOR verified (For service well only) _ _ ..... _ NA 85 Permitcan be issued w/o hydrogen. sulfide measures ........ _ _ _ _ _ _ _ _ No... _ _ Wells on 2E Pad exceed 20 ppm. limit.in 20AAC.25,055(a)_ regulation Geology 36 Data. presented on potential overpressure zones _ _ _ _ Yes Appr Date 37 Seismic analysis of shallow gas zones _ _ _ _ _ _ _ _ _ _ ..... NA DLB 4/9/2019 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ .... NA_ _ _ _ ___ _ _ _ __ X39 Contact name/phone for weekly. progress reports [exploratory only] .. _ _ _ ....... NA_ _ _ _ _ _ _ _ _ _ _ _ _______ Geologic Engineering Public Commissioner: Date: Commissioner:y/ Date Commissioner Date I
